GB2482078A

GB2482078A - Swellable downhole sealing arrangement

Info

Publication number: GB2482078A
Application number: GB201117557A
Authority: GB
Inventors: Glen Robitaille; Kim Nutley; Brian Nutley
Original assignee: Swelltec Ltd
Current assignee: Swelltec Ltd
Priority date: 2008-02-27
Filing date: 2008-02-27
Publication date: 2012-01-18
Anticipated expiration: 2028-02-27
Also published as: GB201117557D0; GB2482078B

Abstract

A downhole apparatus 100 is described comprising a body 12 and a sealing arrangement 15 located on the body. The body has a longitudinal axis L and the sealing arrangement comprises at least one elongated sealing member with an axis of elongation extending around the longitudinal axis. The sealing member comprises a material selected to expand or swell on exposure to at least one predetermined fluid, such as a hydrocarbon or aqueous fluid encountered in a wellbore. The sealing member comprises one or more expanding components coupled to an elongate component. The elongated sealing member may be a strip band or ribbon and comprise a plurality of turns, such that it is wound around the body. Embodiments of the invention relate to wellbore packers.

Description

1 Downhole apparatus and method 3 The present invention relates to apparatus for use in downhole or in pipelines, in particular 4 in the field of oil and gas exploration and production. The invention also relates to components for and methods of forming downhole apparatus.

7 In the field of oil and gas exploration and production, various tools are used to provide a 8 fluid seal between two components in a wellbore. Isolation tools have been designed for 9 sealing an annulus between two downhole components to prevent undesirable flow of wellbore fluids in the annulus. For example, a packer may be formed on the outer surface 11 of a completion string which is run into an outer casing or an uncased hole. The packer is 12 run with the string to a downhole location, and is inflated or expanded into contact with the 13 inner surface of the outer casing or openhole to create a seal in the annulus. To provide 14 an effective seal, fluid must be prevented from passing through the space or micro-annulus between the packer and the completion, as well as between the packer and the 16 outer casing or openhole.

18 Isolation tools are not exclusively run on completion strings. For example, in some 19 applications they form a seal between a mandrel which forms part of a specialised tool and 1 an outer surface. In other applications they may be run on coiled tubing, wireline and 2 slickline tools.

4 Conventional packers are actuated by mechanical or hydraulic systems. More recently, packers have been developed which include a mantle of swellable elastomeric material 6 formed around a tubular body. The swellable elastomer is selected to expand on 7 exposure to at least one predetermined fluid, which may be a hydrocarbon fluid or an 8 aqueous fluid. The packer may be run to a downhole location in its unexpanded state, 9 where it is exposed to a wellbore fluid and caused to expand. The design, dimensions, and swelling characteristics are selected such that the swellable mantle expands to create 11 a fluid seal in the annulus, thereby isolating one wellbore section from another. Swellable 12 packers have several advantages over conventional packers, including passive actuation, 13 simplicity of construction, and robustness in long term isolation applications. Examples of 14 swellable packers are described in GB 2411918.

16 Figure 1 of the drawings shows a swellable packer according to the prior art, generally 17 depicted at 10, formed on a tubular body 12 having a longitudinal axis L. The packer 10 18 comprises an expanding mantle 14 of cylindrical form located around the body 12. The 19 expanding mantle 14 is formed from a material selected to expand on exposure to at least one predetermined fluid. Such materials are known in the art, for example from 21 GB2411918.

23 As illustrated in Figures 2A and 2B, the dimensions of the packer 10 and the 24 characteristics of the swellable material of the expanding portion 14 are selected such that the expanding portion forms a seal in use, which substantially prevents the flow of fluids 26 past the body 12. Figure 2A is a cross section through the packer 10 located in a wellbore 27 20 in a formation 22. On exposure to a wellbore fluid in the annulus 24, in this case a 28 hydrocarbon fluid, the expanding portion 14 expands and its outer diameter increases until 29 it contacts the surface 26 of the wellbore to create a seal in the annulus 24. The seal prevents flow of fluid in the wellbore annulus between a volume above the packer 10 and a 31 volume below the packer 10. Although shown here in use in an uncased hole, the packer 32 10 could of course be used in a cased hole, in which case the mantle would form a seal 33 against the interior surface of the outer casing.

1 Typically a packer will be constructed for a specific application and incorporated into a 2 casing string or other tool string by means of threaded couplings. Swellable packers are 3 typically constructed from multiple layers of uncured elastomeric material, such as EPDM.

4 Multiple layers are overlaid on a mandrel or tubular in an uncured form to build up a mantle of the required dimensions. The mantle is subsequently cured, e.g. by heat curing or air 6 curing. The outer surface of the swellable mantle is then machined using a lathe to create 7 a smooth cylindrical surface. This method produces a fully cured, unitary swellable mantle 8 capable of sealing large differential pressures. However, the process is generally labour- 9 intensive and time consuming, and the uncured material can be difficult to handle.

Moreover, the resulting expanding portion, although robust and capable of withstanding 11 high pressures, may be ill-suited to some downhole applications.

13 In wellbore construction cement is used to seal an annulus between a casing section and 14 an openhole, or an annulus between two concentric tubulars, to prevent undesirable fluid flow to surface. Large volumes of cement are required to seal an annulus from a casing 16 point back to surface, and when the casing is cemented into place, the cement forms a 17 structural component of the wellbore.

19 There is generally a need to provide sealing mechanisms and isolation tools and systems which may be manufactured and assembled more efficiently than in the case of the prior 21 art, and which are flexible in their application to a variety of wellbore scenarios.

23 It is amongst the aims and objects of the invention to overcome or mitigate the drawbacks 24 and disadvantages of prior art apparatus and sealing systems.

26 According to a first aspect of the invention there is provided a downhole apparatus 27 comprising: 28 a body having a longitudinal axis and a sealing arrangement located on the body; 29 wherein the sealing arrangement comprises at least one elongated sealing member with an axis of elongation extending around the longitudinal axis of the body, and the sealing 31 member comprises a material selected to expand on exposure to at least one 32 predetermined fluid.

34 The sealing arrangement may have an expanded condition in which an annular seal is formed. The annular seal may be formed between the body and a surface external to the 1 body, which may be substantially concentric with the body. In this instance, the sealing 2 arrangement may be formed on an outer surface of the body, and the seal may be in an 3 annulus formed between the body and the surface external to the body. The surface may 4 be the internal surface of a casing or an uncased borehole. The downhole apparatus may therefore form an annular seal, which may substantially prevent fluid flow past the body.

7 The downhole apparatus preferably forms a part of an isolation tool or an isolation system 8 for sealing one region of the annulus above the apparatus from another region of the 9 ann ulus below the apparatus.

11 The terms "upper", "lower", "above", "below", "up" and "down" are used herein to indicate 12 relative positions in the wellbore. The invention also has applications in wells that are 13 deviated or horizontal, and when these terms are applied to such wells they may indicate 14 "left", "right" or other relative positions in the context of the orientation of the well.

16 The body may be a substantially cylindrical body, and may be a tubular or a mandrel. The 17 sealing member may extend circumferentially around the body. The sealing member may 18 extend around the outer surface of the body, or may extend around an inner surface of the 19 body.

21 The sealing member may form an expanding portion, which may be substantially 22 cylindrical in form and may extend over a length of the body. The expanding portion may 23 extend over a length of the body which is greater than the width of the elongated sealing 24 member.

26 By creating a sealing arrangement from an elongated sealing member, it may be easier to 27 assemble the apparatus when compared with conventional slip-on apparatus. For 28 example, the expanding portion could be formed by securing a first end and a second end 29 of the elongated member to the body at a part of the body which is axially displaced from an end of the body. For example, the apparatus could be formed on a central 2 metre 31 portion of a 12 metre casing section.

33 An annular seal may be formed between the body and a surface internal to the body, 34 which may be substantially concentric with the body. In this instance, the sealing arrangement may be formed on an inner surface of the body, and the seal may be in an 1 annulus formed between the body and the surface external to the body. The surface may 2 be the outer surface of a second body, which may be a casing or an uncased borehole.

4 The elongated sealing member may be a strip, band, ribbon, bead, tape, rod, cable, conduit or another elongated form.

7 The sealing arrangement may consist of a single turn of the elongated member, but 8 preferably comprises a plurality of turns. Preferably, the elongated member is coiled on 9 the body.

11 The plurality of turns may be formed such that a lower edge of a turn is adjacent to an 12 upper edge of a successive turn. The lower edge of a turn may abut an upper edge of a 13 successive turn, and may create a seal with the upper edge of the successive turn.

14 Alternatively, successive turns may be spaced from one another.

16 The elongated sealing member may comprise a material selected to expand on exposure 17 to a hydrocarbon fluid, which may be an EPDM rubber. Alternatively, or in addition, the 18 elongated sealing member may comprise a material selected to expand on exposure to an 19 aqueous fluid, which may be a super-absorbent polymer.

21 The sealing member may be formed by an extrusion process, which may be a co-extrusion 22 of two or more materials. The two materials may both be selected to expand on exposure 23 to at least one predetermined fluid, but may be selected to differ in one or more of the 24 following characteristics: fluid penetration, fluid absorption, swelling coefficient, swelling rate, elongation coefficient, hardness, resilience, elasticity, and density. At least one 26 material may comprise a foam. The material may be foamed through the addition of 27 blowing agents. In some applications this will aid fluid absorption leading to faster swell 28 rates and higher maximum swell volumes.

Alternatively, or in addition, the sealing member may be formed from an extrusion around 31 a substrate.

33 In an embodiment the sealing member comprises one or more expanding components 34 coupled to a core, a layer or another elongate component, which may have different physical properties to the expanding component. Advantageously the expanding 1 component or components will at least partially encapsulate the elongate component to 2 facilitate the provision of a seal.

4 The core may be a coated or uncoated cable or control line, and/or may comprise an expanding material. This embodiment has the advantage that a sealing member can be 6 created with different properties by the combination of sheaths and cores of different 7 designs. For example, the sheath may be used to encapsulate a core of expanding 8 material having a different swelling characteristic to create a hybrid sealing member. The 9 core may function as the substrate, or may be arranged to convey a fluid or a signal through the sealing member.

12 Alternatively, or in addition, the sealing member may comprise a substrate and means for 13 attaching an expanding component to the substrate. The expanding component may 14 comprise formations configured for attachment to a substrate and/or a recess for receiving a substrate. The expanding component may comprise a formation configured to receive 16 an elongate component. The formation may be resilient and may retain the elongate 17 component, for example by partially or fully surrounding the elongate component. The 18 expanding component may comprise a substantially u-shaped or c-shaped profile which 19 defines a longitudinal groove. The expanding component may comprise a clip-on member that clips around a elongate component, and may be bonded in position through the use of 21 an adhesive or other bonding agent.

23 The sealing member may comprise a substrate which extends longitudinally to the 24 member. The substrate may comprise a core, or may comprise a strip, band, ribbon, bead, tape, rod, cable, conduit or another elongated form. The substrate may comprise 26 plastic, metal, fibrous, woven, or composite material. The substrate may function to 27 provide structural strength to the sealing member, allow more tension to be imparted 28 during application to a body, bind to the swellable material, resist expansion of the sealing 29 member in a longitudinal direction, and/or resist swaging of the sealing member on the body.

32 The sealing member may comprise a conduit, which may be longitudinally oriented. The 33 conduit may be formed by the substrate, or may be an open conduit. The conduit may be 34 used to convey fluid, a cable, a control line, or a signal internally of the sealing member.

The conduit may allow fluid access to the material of the sealing member from the interior 1 of the conduit. In this way, the expansion of the sealing member may be triggered, at least 2 in part, by fluid delivered through the sealing member.

4 The sealing member may couple control equipment on one side of a seal created by the apparatus to an apparatus on an opposing side of the seal. For example, the sealing 6 member may comprise a power cable, a control line, a hydraulic line, or a data cable which 7 runs from surface to an apparatus located below a seal created by the apparatus.

9 The elongated sealing member may comprise a substantially rectangular cross sectional profile. Alternatively, or in addition, the elongated sealing member may comprise an 11 interlocking profile, which may be configured such that a first side of the sealing member 12 has a shape corresponding to the shape of the second, opposing side of the sealing 13 member. The interlocking profile may be configured such that a first side of a turn of the 14 sealing member on the body interlocks with a second, opposing side of an adjacent turn of a sealing member on the body. The interlocking profile may resist lateral separation of 16 adjacent turns, and/or may resist relative slipping of adjacent turns. A bonding agent may 17 be used to secure a first side of the sealing member to the shape of the second, opposing 18 side of the sealing member. Where an interlocking profile is provided, the sealing member 19 may be further secured through the use of an adhesive or other bonding agent.

21 The sealing member may have a profile configured for interlocking multiple layers of a 22 sealing member on the body. The sealing member may have a stepped profile, a T- 23 shaped profile or a triangular profile. The sealing member according to one embodiment 24 comprises a flat first surface and a longitudinal spine protruding from an opposing surface.

The sealing member may comprise stepped side surfaces.

27 The apparatus may further comprise means for securing the sealing member to the body, 28 which may comprise a bonding agent. Alternatively, or in addition, the apparatus may 29 comprise a mechanical attachment means for securing the sealing member to the body, which is preferably an end ring. The mechanical attachment means may be clamped onto 31 the body, and may comprise a plurality of hinged clamping members. Alternatively, 32 mechanical attachment means is configured to be slipped onto the body.

34 The mechanical attachment means may comprise a formation for receiving an end of the sealing arrangement, which may be an enlarged bore. The mechanical attachment means 1 may comprise an engaging formation for engaging a part of the sealing member, which 2 may be a longitudinal formation. The engaging formation may comprise teeth for engaging 3 the sealing member. Alternatively or in addition, the engaging formation may comprise 4 crimp portions.

6 In one embodiment, the engaging formation comprises threads configured to cooperate 7 with the sealing member.

9 In a further embodiment, the mechanical attachment means comprises means for imparting tension into the elongated sealing member. The mechanical attachment means 11 may comprise a ratchet mechanism. The mechanical attachment means may comprise an 12 engaging portion, for engaging the elongated member, and a retaining portion, for 13 retaining the mechanical attachment means with respect to the body. The engaging 14 portion may be rotatable with respect to the retaining portion, and a ratchet mechanism may be disposed between the engaging and retaining portions.

17 The mechanical attachment means may comprise a release mechanism, which may be 18 actuable from surface and/or by a downhole intervention. The release mechanism may be 19 actuable to release tension in the elongated member. In one embodiment, the release mechanism is actuable to release a ratchet. The release mechanism may comprise at 21 least one frangible member, such as a shear pin.

23 In one embodiment, the mechanical attachment means is configured to be disposed on a 24 coupling of a tubular, and may be referred to as a cross-coupling mechanical attachment means. Such a mechanical attachment means comprises an internal profile configured to 26 correspond to the outer profile of the coupling, which may be raised with respect to the 27 outer diameter of the tubular. This embodiment may be particularly advantageous where 28 an expanding portion is required over the entire length of a tubular between couplings.

29 The cross-coupling mechanical attachment means may comprise hinged clamps, swing bolt locking mechanisms, strap fasteners or other attachment means. The cross-coupling 31 mechanical attachment may be wholly or partially cast from a metal (such as steel) or a 32 plastic material.

34 The elongated member may comprise an attachment portion configured to be secured to the body. The attachment portion may comprise a formation configured to engage with 1 mechanical attachment means of the apparatus. The attachment portion preferably 2 comprises a termination, which may be a socket termination. The attachment portion may 3 be crimped, bonded, screwed, or otherwise attached to the elongated member. In 4 embodiments where the elongated member comprises a substrate, the attachment portion may be attached direct to the substrate.

7 The apparatus may be configured as a packer, a liner hanger, or an overshot tool.

9 The apparatus may be configured as a cable encapsulation assembly, and may comprise a support element disposed between the body and the sealing arrangement. The support 11 element may be provided with a profile configured to receive a cable, conduit or other line.

12 The support element may comprise a curved outer profile, and the assembly may define 13 an elliptic outer profile. Alternatively the support element may comprise a substantially 14 circular profile such that the assembly defines a circular outer profile.

16 According to a second aspect of the invention, there is provided a sealing member for a 17 downhole apparatus, the sealing member comprising a material selected to expand on 18 contact with at least one predetermined fluid, wherein the sealing member is elongated 19 and is configured to be located on a body of a downhole apparatus such that its axis of elongation extends around the longitudinal axis of the body.

22 The sealing member is preferably configured to form an annular seal between a body and 23 a surface external to the body, in use which may be substantially concentric with the body.

24 In this instance, the sealing member may be configured for disposal on an outer surface of a body, and the seal may be in an annulus formed between the body and the surface 26 external to the body. The surface may be the internal surface of a casing or an uncased 27 borehole. The sealing member is therefore configured to form an annular seal, which may 28 substantially prevent fluid flow past the body.

The sealing member may be configurable to form an expanding portion, which may be 31 substantially cylindrical in form and may extend over a length of a body. The expanding 32 portion may extend over a length of the body, which may be greater than the width of the 33 sealing member.

1 The sealing member may be configured for disposal between a body and a surface 2 internal to the body, which may be substantially concentric with the body. In this instance, 3 the sealing member may be configured for disposal on an inner surface of the body, and 4 the seal may be in an annulus formed between the body and the surface external to the body. The surface may be the outer surface of a second body, which may be a casing or 6 an uncased borehole.

8 The sealing member may be a strip, band, ribbon, bead, tape, rod, cable, conduit or 9 another elongated form.

11 The sealing member of the second aspect of the invention may include one or more of the 12 optional or preferred features of the sealing member/elongated sealing member of the first 13 aspect of the invention.

According to a third aspect of the invention there is provided a method of forming a 16 downhole apparatus, the method comprising the steps of: 17 (a) Providing a body having a longitudinal axis; 18 (b) Providing at least one elongated sealing member comprising a material selected to 19 expand on exposure to at least one predetermined fluid; (c) Forming a sealing arrangement on the body by locating the at least one elongated 21 sealing member on the body, with its axis of elongation extending around the 22 longitudinal axis of the body.

24 The method may comprise the step of forming multiple turns of the elongated sealing member on the body.

27 The elongated sealing member may comprise a power cable for a downhole apparatus.

29 According to a fourth aspect of the invention, there is a provided a method of forming a seal in a downhole environment, the method comprising the steps of: 31 (a) Configuring a sealing apparatus from a body and at least one elongated sealing 32 member arranged on the body and comprising a material selected to expand on 33 exposure to at least one predetermined fluid; 34 (b) Running the sealing apparatus to a downhole location such that the sealing apparatus is disposed adjacent a surface; 1 (c) Exposing the elongated sealing member to at least one fluid to expand it to an 2 expanded condition, in which a seal is created between the body and the surface.

4 According to a fifth aspect of the invention, there is provided method of constructing a wellbore, the method comprising the steps of: 6 (a) Assembling a first casing string from a plurality of casing sections; 7 (b) Forming at least one sealing arrangement on the casing from at least one 8 elongated sealing member comprising a material selected to expand on exposure 9 to at least one predetermined fluid; (c) Running the first casing string to a downhole location; 11 (d) Exposing the sealing arrangement to at least one welibore fluid, thereby expanding 12 the sealing arrangement into contact with a downhole surface.

14 The method may comprise the step of forming sealing arrangements over a majority of the length of the casing string. The downhole surface may be the surface of an openhole, or 16 may be the surface of a downhole casing.

18 The method may comprise the step of running a second casing string inside the first 19 casing string. The method may comprise the step of forming at least one sealing arrangement on the second casing from at least one elongated sealing member 21 comprising a material selected to expand on exposure to at least one predetermined fluid.

23 The method may further comprise the step of exposing the sealing arrangement of the 24 second casing to at least one welibore fluid, thereby expanding the sealing arrangement into contact with the first casing string. The method may be repeated with third, fourth and 26 other casing strings.

28 Thus the invention provides a method of wellbore construction in which a sealing 29 arrangement formed from an elongated sealing member is located between concentric casings. Such an arrangement may be used as an alternative to cemented completions, 31 or in conjunction with cement to provide an enhanced sealing capability.

33 According to a sixth aspect of the invention, there is provided a well bore packer 34 comprising an expanding portion formed from an elongated sealing member coiled around 1 a body, the elongated sealing member comprising a material selected to expand on 2 exposure to at least one predetermined fluid.

4 In one aspect of the invention, the sealing member is a power cable, which may be a power cable for an Electrical Submersible Pump (ESP).

7 According to a seventh aspect of the invention, there is provided an elongated member for 8 forming a wellbore packer, the elongated member comprising a material selected to 9 expand on exposure to at least one predetermined fluid.

11 According to an eighth aspect of the invention, there is provided a storage reel comprising 12 a length of elongated member in accordance with any of the above aspects of the 13 invention.

According to a ninth aspect of the invention, there is provide an overshot tool comprising a 16 tubular body and an opening configured to be disposed over a body to be coupled in use, 17 and a sealing arrangement arranged on the inner surface of the tubular body, wherein the 18 sealing arrangement comprises at least one elongated sealing member with an axis of 19 elongation extending around the longitudinal axis of the body, and the sealing member comprises a material selected to expand on exposure to at least one predetermined fluid.

22 The overshot tool may be configured to form part of an expansion joint. The body may be 23 a mandrel, which may have a low friction surface. Alternatively or in addition, the body 24 may be an end of a tubular in a downhole or subsea location.

26 The sixth to the ninth aspects of the invention may include one or more of the optional or 27 preferred features of the sealing member/elongated sealing member of the first aspect of 28 the invention.

There will now be described, by way of example only, various embodiments of the 31 invention with reference to the drawings, of which: 33 Figure 1 is a side view of a prior art wellbore packer; 34 Figures 2A and 2B are schematic cross sectional views of a prior art wellbore packer in use in unexpanded and expanded conditions respectively; 1 Figure 3 is a side view of a packer in accordance with an embodiment of the 2 invention; 3 Figure 4 is a perspective view of a part of a sealing member in accordance with the 4 first embodiment of the invention; Figures 5A to 50 are schematic views of the apparatus of Figure 3 in various 6 stages of construction; 7 Figure 6 is a longitudinal section through the apparatus of Figure 3; 8 Figure 7A is a side view showing some internal details, and Figure 7B is a 9 longitudinal sectional view through an apparatus in accordance with an alternative embodiment of the invention; 11 Figure 8 is a longitudinal section through an apparatus in accordance with a further 12 alternative embodiment of the invention; 13 Figure 9 is a longitudinal section through an apparatus in accordance with a further 14 alternative embodiment of the invention; Figure 10 is a longitudinal section through an apparatus in accordance with a 16 further alternative embodiment of the invention; 17 Figure 11 is a longitudinal section through an apparatus in accordance with a 18 further alternative embodiment of the invention; 19 Figures 12A and 12B are schematic longitudinal views showing a construction method according to an embodiment of the invention; 21 Figures 13A and 13B are schematic longitudinal views showing a construction 22 method according to an alternative embodiment of the invention; 23 Figure 14 is a schematic longitudinal view of a terminated sealing member 24 according to an alternative embodiment of the invention; Figure 15 is a schematic longitudinal view of a terminated sealing member 26 according to a further alternative embodiment of the invention; 27 Figure 16 is a perspective view of a part of a sealing member in accordance with 28 an embodiment of the invention; 29 Figures 1 7A and I 7B are cross sectional views of sealing members in accordance with alternative embodiments of the invention; 31 Figure 18 is a longitudinal section through the sealing member of Figure 17A and a 32 termination according to one embodiment; 33 Figure 19 is a longitudinal section through the sealing member of Figure 17B and a 34 termination according to another embodiment; 1 Figures 20 to 26 are cross sectional views of sealing members in accordance with 2 further alternative embodiments of the invention; 3 Figure 27 is a longitudinal section through a sealing member in accordance with 4 one embodiment of the invention; Figures 28A and 28B are cross sectional views of a sealing member according to a 6 further alternative embodiment of the invention; 7 Figures 29A and 29B are schematic longitudinal views of a packer constructed 8 from the sealing member of Figure 24; 9 Figures 30 to 32 are cross sectional views of sealing members in accordance with further alternative embodiments of the invention; 11 Figures 33A and 33B are alternative cross sectional views of a sealing member in 12 accordance with a further embodiment of the invention; 13 Figures 34A and 34B schematically show the application of the sealing member of 14 Figure 32 to a body; Figures 35A and 35B schematically show the application of the sealing member of 16 Figure 33 and another sealing member to a body according to one embodiment; 17 Figures 36A to 36B schematically show the application of the sealing member of 18 Figure 33 and another sealing member to a body according to an alternative 19 embodiment; Figures 37 and 38 schematically show expanding portions formed from sealing 21 members according to alternative embodiments of the invention; 22 Figures 39 and 40 are cross sectional views of sealing members in accordance 23 with further alternative embodiments of the invention; 24 Figure 41 is a perspective view of a sealing member in accordance with a further alternative embodiment of the invention; 26 Figure 42 is a cross sectional view of a sealing member in accordance with a 27 further alternative embodiment of the invention; 28 Figure 43 is a cross sectional view of a cable encapsulation assembly in 29 accordance with an embodiment of the invention; Figure 44 is a perspective view of a support element used in the assembly of 31 Figure 43; 32 Figure 45 is a cross sectional view of a cable encapsulation assembly in 33 accordance with a further embodiment of the invention; 34 Figure 46 is a schematic view of a part of an overshot tool in accordance with an embodiment of the invention; 1 Figures 47A and 47B schematically show an application of the tool of Figure 46 in 2 accordance with an embodiment of the invention.

4 Referring to Figure 3 of the drawings, there is shown schematically an aspect of the invention embodied as a wellbore packer, generally depicted at 100, formed on a tubular 6 body 12 having a longitudinal axis L. The packer 100 comprises an expanding portion 15 7 of cylindrical form located around the body 12 and a pair of end rings 16, 18 located 8 respectively at opposing ends of the expanding portion 15. The expanding portion 15 is 9 formed from a material selected to expand on exposure to at least one predetermined fluid. In this embodiment, the swellable material is EPDM, selected to expand on 11 exposure to a hydrocarbon fluid. The functions of the end rings 16, 18 include: providing 12 stand-off and protection to the packer 100 and the tubular 12, axially retaining the 13 expanding portion 15, and mitigating extrusion of the expanding portion 15 in use. The 14 operation of the packer 100 can be understood from Figures 2A and 2B and the accompanying text.

17 Figure 4 of the drawings shows a sealing member 30 used to form packer 100. The 18 sealing member 30 consists of an elongated band of the swellable material which is used 19 to form the expanding portion 15. In this example, the sealing member 30 is extruded EPDM with a substantially rectangular cross sectional profile, and is fully cured. The 21 sealing member 30 comprises a first end 32, and top, bottom and side surfaces 34, 36, 38 22 and 40 respectively. Figure 4 shows a short sample of the sealing member 30, which will 23 typically be formed in a continuous length of several tens or hundreds of metres.

Figures 5A to 5C illustrate how the sealing member 30 is applied to body 12 to form the 26 expanding portion 15 of the packer 100. The sealing member 30 is deployed from a 27 storage reel 42, on which several tens or hundreds of metres of the sealing member is 28 stored. The bottom surface 36 at first end 32 is located on and attached to the outer 29 surface of the tubular body 12 by a bonding agent, and a length of the sealing member proximal the first end is coiled around the longitudinal axis L of the body 12. In this 31 embodiment, the bonding agent used is a cyanoacrylate-based adhesive, but other 32 bonding agents are suitable, including polyurethane-based adhesives, acrylic-based 33 adhesives, epoxy-based adhesives or silicone-based adhesives or sealants. The sealing 34 member 30 is further deployed and is coiled around the tubular body 12 and bonded to its outer surface, as shown in Figure 5B, and is applied such that the side surfaces of 1 successive turns abut one another. Tension is applied to the sealing member 30 during 2 winding. Tension allows a seal to be created between the sealing member and the body 3 even when the sealing member is in its unexpanded condition. To facilitate the application 4 of the sealing member 30 to the body and maintaining tension, the sealing member may be temporarily secured to the body at its first end by a clamp (not shown). The sealing 6 member 30 is applied to the body 12 over a length corresponding to the desired length of 7 the packer 100, shown in Figure 5C, which is selected according to the application and 8 pressure conditions it is required to withstand. The sealing member 30 is cut to define 9 second end 44, and the bottom surface 36 near to the second end is bonded to the body 12.

12 The sealing member is thus coiled around the body 12 to create an expanding portion 15 13 which is substantially cylindrical in form and extends over a length of the tool. First and 14 second rings 16, 18 are subsequently located over the first and second ends of the expanding portion and secured to the body 12 by means of threaded bolts (not shown).

16 The resulting tool is shown in section in Figure 6. The end rings have an internal profile to 17 accommodate the raised (with respect to the tubular body 12) profile of the expanding 18 portion 15 and the discontinuities in the ends of the expanding portion due to the cut ends 19 32,44 of the sealing member. In this embodiment, the end rings 16 and 18 are formed in two hinged parts (not shown), which are placed around the expanding portion 15 and the 21 tubular 12 from a position adjacent to the apparatus, and fixed together using locking bolts 22 (not shown). In alternative embodiments, the end rings are unitary structures slipped onto 23 the tubular 12 from one end. In a further embodiment, the end rings may clamp over a 24 fixed upset profile on the body 12, such as a tubing or casing coupling. Such an embodiment may be particularly advantageous where an expanding portion is required 26 over the entire length of a tubular between couplings, and may provide an improved 27 anchoring force for the end ring and the sealing member. In a further alternative 28 embodiment, end rings may not be required.

The dimensions of the packer 100 and the characteristics of the swellable material of the 31 sealing member 30 are selected such that the expanding portion forms a seal in use, 32 which substantially prevents the flow of fluids past the body 12. The packer operates in 33 the manner described with reference to Figures 2A and 2B.

1 The expanding portion 15 thus resembles a swellable mantle as used in conventional 2 swelling packers, but offers several advantages and benefits when compared with 3 conventional packer designs. For example, the sealing member 30 is economical to 4 manufacture, compact to store, and easy to handle when compared with the materials used in conventional swellable packers.

7 The process of forming the packer offers several advantages. Firstly, the process does 8 not require specialised equipment requiring large amounts of space or capital expenditure.

9 The process can be carried out from a central portion of the tubular body, by attaching a first end of the sealing member and coiling it around the tubular, reducing the difficulties 11 associated with slipping tool elements on at an end of the tubular and sliding them to the 12 required location. This facilitates application of the sealing member to significantly longer 13 tubulars, and opens up the possibility of constructed packer on strings of tubing on the rig 14 floor immediately prior to or during assembly. The construction process allows for a high degree of flexibility in tool design. For example, a packer of any desired length can be 16 created from the same set of components, simply by adjusting the length over which the 17 sealing member is coiled on the tubular body. Packers and seals can be created on 18 bodies and tubulars of a range of diameters. The principles of the invention also inherently 19 allow for engineering tolerances in the dimensions of bodies on which the seal is created.

21 The resulting packer has increased surface area with respect to an equivalent packer with 22 an annular mantle, by virtue of the increased penetration of the fluids into the expanding 23 portion via the small spaces between adjacent turns. This allows for faster expansion to 24 the sealing condition. The elongated sealing member also lends itself well to post-processing, for example perforating, coating or performing analysis on a sample.

27 Figures 7A and 7B show a packer 110 in accordance with an alternative embodiment of 28 the invention. Figure 7A is a side view of a first end and corresponding end ring 46 with 29 some internal details shown, whereas Figure 7B is a section of the of the same apparatus through line B-B'. The packer 110 is similar to the packer 100, formed on a tubular 12, 31 having an expanding portion 15 formed from an elongated sealing member 30. However, 32 the end ring 46 is provided with a machined, longitudinal formation 48 configured to 33 receive the first end 32 of the sealing member. In this example, the first end 32 is located 34 on the tubular 12, and the end ring 46 is clamped over the sealing member 30, with the end 32 located in the formation 48. An upper surface 50 of the recess 48 is provided with 1 engaging teeth 51 which function to impress against the top surface 34 of the sealing 2 member and assist in securing it against the body. A portion of the sealing member which 3 is clear of the formation 48 is redirected in a circumferential direction and the sealing 4 member is coiled around the tubular in the manner described with reference to Figure 5A to 50. The end ring 48 assists in securing the sealing member and may allow greater 6 tension to be imparted during application. In this embodiment, the sealing member 30 is 7 bonded to the tubular, but alternative embodiments may rely on the end rings and the 8 applied tension to retain the expanding portion in place. An identical end ring (not shown) 9 is provided at the opposing end of the packer 110.

11 Figures 8 to 11 show further alternative embodiments of packer including variant end 12 rings. In Figure 8, the packer 120 includes an end ring 58 includes an enlarged bore 13 portion 60 shaped to fit over a part of the expanding portion 15. The inner surface 62 of 14 the enlarged bore portion 60 is provided with engaging means in the form of a reverse thread 64. The thread 64 is shaped to correspond with the helix defined by the sealing 16 member 30, and in this embodiment is received in spaces between adjacent turns of the 17 sealing member. The packer 120 is constructed by locating the sealing member 30 on the 18 body 12, and wrapping the sealing member to a length greater than the depth of the 19 enlarged bore 60. The end 66 of the expanding portion is cut such that it defines a flat annular surface on a plane perpendicular to the longitudinal axis L of the body. In other 21 words, the end 66 is squared-off. The end ring 58 is slipped onto the body 12 and 22 threaded over the end 66 of the expanding portion. An identical end ring (not shown) is 23 provided at the opposing end of the packer 120.

In Figure 9, a further alternative end ring 68 is shown on a packer 130. The end ring 68 is 26 similar to end ring 58, but differs in that it is constructed from inner ring 70 and outer ring 27 72. The inner ring 70 has an internal bore shaped to fit over the tubular body 12, and has 28 a low profile compared with the radial extent of the expanding portion 15. The inner ring 29 70 and the outer ring 72 are threaded together by threaded section 74 and together define an annular recess 75 for the sealing member. Surfaces of the recess 75 are provided with 31 reverse threads 76, 77, shaped to correspond with the helix defined by the sealing 32 member 30. During construction, the inner ring 70 is located on the body 12, and the 33 sealing member is wrapped around the inner ring 70 and along the length of the body 12.

34 The outer ring 72 is later threaded into engagement with the inner ring 70 and over the end of the expanding portion.

2 Figure 10 illustrates a further end ring design 78 as part of a packer 140. The end ring 78 3 has an enlarged bore 80 to receive the end of the expanding portion 15. The end ring 78 4 is crimped into engagement with the end of the expanding portion 15. To facilitate crimping, the end ring 78 has crimp portions 82, which are relatively malleable with respect 6 to the main body of the ring, distributed around the outer circumferential surface of the 7 ring. In this embodiment, two axially separated groups of crimp portions 84 and 86 are 8 provided. The Figure shows the crimp portions in a depressed state into engagement with 9 the expanding portion.

11 Figure 11 shows a further alternative end ring 88 on a packer 150. In this embodiment, 12 the end ring 88 includes a ratchet mechanism 89, and is formed from retaining ring 90 and 13 an engaging ring 92. The engaging ring 92 is axially keyed with the retaining ring 90, 14 which in turn is secured to the body 12. The engaging ring has an enlarged bore portion 94 for receiving the expanding portion 15. The ratchet mechanism 89 is disposed between 16 the engaging ring 92 and the retaining ring 90, and allows one-way relative rotation.

17 Formations 96 are located in the outer surface of the engaging ring to assist with the 18 engagement of a tool to rotate the ring. In this embodiment, the end of the sealing 19 member 30 is secured to the engaging ring, and as the sealing member 30 is coiled the ratchet prevents rotation of the engaging ring. When the expanding portion is formed and 21 the second end is secured, the engaging ring may be rotated to impart tension into the 22 sealing member. The tension is retained by virtue of the ratchet mechanism 89.

24 The second, opposing end of the packer 150 is provided with a similar ratcheted end ring (not shown), configured to impart tension into the sealing member from its other end.

26 However, in some embodiments the ratcheted end ring may only be used at one end, and 27 may be sufficient to impart tension through the length of the sealing member. In another 28 embodiment, not illustrated, a ratcheted ring is located between two expanding portions, 29 and may have an engaging ring which receives an end of a sealing portion from each expanding portion. The engaging ring can be rotated to impart tension into both sealing 31 members, with the tension retained by the ratchet. In this embodiment, the expanding 32 portions would be formed from sealing members coiled on the tubular in opposite senses.

34 Further alternative embodiments of the invention include an end ring which is operable to be released, thereby releasing tension in the sealing member and breaking the seal. For 1 example, the ratcheted end ring of Figure 11 may be adapted to include a set of shear 2 pins, such that an actuation from surface, for example by the application of an axial force 3 on the end ring, shears the pins and allows the engaging ring to rotate with respect to the 4 retaining ring. This releases tension in the sealing member, and introduces a failure mode between the body and the sealing member which ultimately breaks the seal and allows the 6 packer to be retrieved.

8 In an alternative construction technique (not illustrated) a length of elongated sealing 9 member is preformed around a formation mandrel into a helical coil to a predetermined length. The sealing member is treated such that the helical shape remains when it is 11 removed from the mandrel. The helical coil is then slipped onto a tubular body to a 12 required location, and secured using end rings as described above. Ratcheted end rings 13 may be used to impart tension into the sealing member.

Figures 12A and 12B show an alternative embodiment of packer 160 and construction 16 method in schematic form. An expanding portion 15 is formed on a tubular 12 by the 17 method described with reference to Figure 5A to 50. A tubular sheath 98 of flexible 18 material is slipped onto the tubular 12, and moved towards the expanding portion 15. The 19 sheath 98 is resilient and elastic, and stretched over the expanding portion 15 into the position shown in Figure 12B. The sheath 98 has a containing and protective function to 21 the expanding portion 15 in use, and is sufficiently elastic to accommodate the expansion 22 of the expanding portion 15. The sheath also allows control of the expansion rates of the 23 expanding portion, by providing a layer between wellbore fluids and the swellable material, 24 and effectively reducing the surface area by covering the spaces between adjacent turns.

The material of the sheath can be selected to impervious to one or wellbore fluids, or can 26 allow diffusion of wellbore fluids to the surface of the expanding portion. The sheath may 27 also be perforated to increase access of wellbore fluids to the swellable material of the 28 expanding portion. In other embodiments, the sheath is dissolved or otherwise 29 disintegrated on exposure to wellbore fluids.

31 The curing state of an elastomer can be conveniently indicated using a scale, where a 32 P100 curing state represents fully cured and cross-linked elastomer and has a 33 corresponding curing time for a known temperature and pressure. An elastomer in its P90 34 state or above may be referred to as substantially fully cured, whereas an elastomer in its P30 to P90 state may be considered to be partially cured or in a semi-cured state. A 1 substantially cured elastomer is one that exhibits similar mechanical properties and 2 handling characteristics to a fully cured elastomer.

4 Figures 1 3A and 1 3B are schematic views of an alternative construction method in accordance with the invention. In this embodiment, the sealing member 31 is applied to a 6 tubular 12 in a semi-cured state, which in this example is a P50 state, but in other 7 embodiments could be a P30 state or lower. However, a semi-cured state in the range of 8 P30 to P70 is preferred. Heat is then applied to the apparatus by passing hot air through 9 the tubular in the direction of the arrows 101 in Figure 1 3A. Figure 1 3B is a detailed schematic view showing heat conducted through the wall of the tubular 12, and the effect 11 of completing the curing to a substantially cured state (P90 or above) at the interfaces 102 12 between adjacent turns of the sealing member 31. This increases the integrity of the 13 expanding portion 15. In other embodiments, the heat may be applied using alternative 14 means.

16 Figure 14 shows an alternative embodiment of sealing member, shown generally at 170.

17 The sealing member 170 comprises a crimp-on terminal 104 on the end 106 of the sealing 18 member. The terminal 104 has crimp portions which are relatively malleable with respect 19 to the main body of the terminal, distributed around the outer circumferential surface. In this embodiment, two axially separated groups of crimp portions 108 and 112 are 21 provided. The Figure shows the crimp portions in a depressed state in engagement with 22 the sealing member. The terminal also comprises an end flange 114 which defines a 23 shoulder 116. The flange 114 and shoulder 116 provide an engagement mechanism for a 24 corresponding surface secured to the body 12, for example the ratcheted end ring of Figure 11, allowing improved retention of the sealing member.

27 Figure 15 shows an alternative embodiment of sealing member, shown generally at 180, 28 comprising a socket termination 118 on the end of the sealing member. The termination 29 comprises a male portion 120 configured to be received in a corresponding recess secured to the body 12, for example a recess provided in an end ring. The termination 31 118 is secured to the sealing member in this case by threaded screws 122.

33 Figure 16 shows in cross section a sealing member 190 in accordance with an alternative 34 embodiment of the invention. Sealing member 190 is similar to the sealing member 30 of Figure 4, but differs in that it is co-extruded from two different materials to create an 1 elongated member having different material components. The member 190 has an outer 2 layer 124 of a first material and a core 126 of a second material. Suitable manufacturing 3 techniques would be known to one skilled in the art of extrusion and co extrusion of 4 polymers and elastomers.

6 The outer layer 124 is of an EPDM rubber selected to expand on exposure to a 7 hydrocarbon fluid, and having specified hardness, fluid penetration, and swelling 8 characteristics suitable for downhole applications. The core 126 is an EPDM rubber which 9 has a greater degree of cross-linking between molecules, compared with the material of the outer layer, and correspondingly has greater hardness, lower fluid penetration, and 11 lower swelling characteristics than the outer layer. The core 126 also has a greater 12 mechanical strength, and functions to increase the strength of the member as a whole 13 when compared with sealing member 30. This allows more tension to be applied and 14 retained in the sealing member during the construction process, and reduces any tendency of the sealing member to swage.

17 In another embodiment, the density of the sealing member is changed over its cross- 18 section to create an increased porosity-permeability structure which leads to more rapid 19 swell rates and higher swell volumes. This may be achieved by foaming the extruded member through the addition of blowing agents. Foaming can be effected over a part of 21 the cross section of the swellable member, to allow a greater porosity-permeability 22 structure to be setup inside the sealing member. Co-extrusions of a foamed core with an 23 overlying solid elastomer, or vice versa, can allow hybrid sealing members to be created 24 having, for example with a high water swelling core and an oil swelling outer mantle.

26 Figure 1 7A shows in cross section a sealing member 200 in accordance with a further 27 alternative embodiment of the invention. Sealing member 200 is similar to the sealing 28 member 30 of Figure 4, but differs in that it is extruded with a substrate 128. The 29 substrate is in this example a ribbon, formed from a suitably malleable metal or metal alloy such as aluminium. In this example, the substrate is co-extruded with the sealing member.

31 In alternative embodiments the substrate is selected from a plastic material, a fibrous 32 material or a composite material, and which may be formed using an appropriate 33 manufacturing technique, and may be extruded, moulded, cast or woven.

1 The substrate 128 extends along the entire length of the sealing member 200, and across 2 the majority of its width. The substrate is asymmetrically placed with respect to the height 3 of the sealing member 200; it is located closer to the bottom surface 132 than the top 4 surface 134 such that there is a greater volume of swellable material located above the substrate 128 compared with the volume located between the substrate 128 and the 6 tubular 12 in use. A thin layer 136 of the swellable material is located beneath the 7 substrate, and thin walls 138 of swellable material are located between the sides of the 8 substrate and the outer surface of the sealing member 200.

Figure 17B shows in cross section a sealing member 201 in accordance with a further 11 alternative embodiment of the invention. Sealing member 201 is similar to the sealing 12 member 200, but differs in that it is extruded with two reinforcing substrates 129. The 13 substrates in this example are ribbons, formed from a suitable plastic material. The 14 substrates 129 are vertically oriented and extend along the entire length of the sealing member20l, and along the majority of the height of the sidewall. Thin walls 139 of 16 swellable material are located between the substrate and the outer surface of the sealing 17 member 201. One advantage of this embodiment is that a greater proportion of the 18 swelling of the sealing member will be directed radially of the body in use; lateral swelling 19 is better restrained by the substrates.

21 Figure 18 is a side view of the sealing member 200 used with a termination 142. The 22 termination 142 resembles the termination of Figure 15, although in this embodiment of the 23 termination is attached to the substrate by means of threaded bolts 144. To facilitate this, 24 the sealing member 200 has been stripped back at an end of 146 to expose the substrate 128. The termination 142 is configured to engage with a corresponding mechanism which 26 is attached to the tubular body 12. Tensile forces imparted along the sealing member 200 27 will be directed through the substrate 128, allowing more tension to be imparted during 28 application to a tubular body, and thus a more effective internal seal to be created. The 29 substrate 128 also functions to bind to the swellable material and resist expansion of the sealing member in a longitudinal direction. Expansion of the sealing member instead 31 tends to be directed in a radial direction of the tubular. The substrate 128 also resists 32 swaging of the sealing member on the tubular body.

1 An alternative termination 148 is shown in Figure 19. In this embodiment, the termination 2 is similar to that of Figure 14, but is secured to the substrate 128 of the sealing member 3 200 by threaded screws 152 which extend from the outer surface of the termination 148.

Figures 20 and 21 are cross-sectional views of sealing members in accordance with 6 further alternative embodiments of the invention. Figure 20 shows a sealing member 210 7 which is similar to that of Figure 17, having a ribbon-like substrate 154 extending through 8 the sealing member. However, in this embodiment, the substrate 154 comprises a "C- 9 shaped" cross sectional profile, with side walls 156 extending downwardly from the main body 158 of the substrate 154. The side walls 156 define edges 162 which are flush with 11 the bottom surface 164 of the sealing member. Between the side walls 156 is defined a 12 band 166 of swellable material. Fluid access to the band 166 is provided by means of 13 laser cut apertures 168 in the substrate. The side walls 156 provide additional vertical 14 support to the sealing member.

16 Figure 21 shows a sealing member 220, similar to the sealing member 190 of Figure 16, 17 but having an outer layer 172 of EPDM rubber and a central core 174 consisting of a 18 suitably malleable metal.

Figures 22 to 26 show further alternative sealing members in cross-section, all of which 21 have an outer layer of swellable material. In Figure 22, the sealing member 230 22 comprises an inner core 176 of a solid porous material. The material may be, for example, 23 a three dimensional metallic mesh, a sintered material with the pores which permit the 24 passage of fluid, or a braided wire, about which the sealing member is extruded. Like the substrate 128, the core provides structural strength to the sealing member, allows more 26 tension to be imparted during application to a tubular body, binds to the swellable material, 27 resists expansion of the sealing member in a longitudinal direction, and resists swaging of 28 the sealing member on the tubular body. The core 176 allows fluid penetration across the 29 core, and also in the longitudinal direction of the sealing member 230. This allows fluid to be directed through the core 176 by a exposing an open end of the sealing member to a 31 fluid.

33 Figure 23 shows a sealing member 240, similar to the sealing member 230, and with a 34 core 178 comprising a woven fibrous wick which is capable of absorbing fluid across the core and in the longitudinal direction of the sealing member 240.

2 Figure 24 shows the sealing member 250, in which a conduit 182, in this case is in the 3 form of a hydraulic control line, forms the core of a sealing member 250. The conduit 4 comprises a metallic wall 183 which is capable of resisting high impacts and large radial forces without collapse. Fluid may be pumped through the conduit 182.

7 Figure 25 shows a sealing member 260, which is similar to the sealing member 250, in 8 that a conduit 184 forms the core of the sealing member. In this case the conduit 184 9 contains a bundle of smaller conduits 186, 188, which may for example be fibre optics or electrical control lines.

12 Figure 26 shows a sealing member 270, in which an outer layer 192 has a hollow core and 13 therefore defines an open conduit 194. The conduit 194 can be used for the supply of 14 fluids or to receive a core or conduit of another of the embodiments of the invention.

16 Referring now to Figure 27, there is shown schematically in a longitudinal section a sealing 17 member 280 of a further alternative embodiment of the invention in use. The sealing 18 member 280 is similar to sealing member 250 of Figure 24. A conduit 196 forms the core 19 of the sealing member 280, and comprises a metallic tubular wall 197 which is capable of resisting high impacts and large radial forces without collapse, and is similar in properties 21 to a hydraulic control line. The conduit 196 is provided with a distribution of apertures 198 22 longitudinally and circumferentially separated along the length of the conduit wall 197. The 23 apertures 198 allow a fluid passing through the conduit to be exposed to the swellable 24 material that forms the outer layer 195 of the sealing member. Thus a triggering fluid used to expand the expanding portion can be delivered to the sealing member internally, via the 26 conduit 196. This may be used to supplement the exposure of the sealing member 280 to 27 fluid from the exterior surface. In some applications, all of the fluid required to expand the 28 expanding portion may be provided via the conduit 196.

Figures 28A and 28B show in cross section a sealing member according to a further 31 alternative embodiment of the invention, shown generally at 291. The sealing member 32 291 is formed from a core in the form of an encapsulated cable 293, and a sheath 295 33 formed from an expanding material such as EPDM. Figures 28A and 28B show the 34 components in unassembled and assembled form respectively.

1 The encapsulated cable 293 comprises a pair of control lines 297 encapsulated in a plastic 2 insulating body 299. The sheath 295 has a substantially c-shaped profile which defines a 3 formation 301 for receiving the core. Base layer 303 of the sheath 295 is formed in two 4 parts with a split 305 that allows the base layer to be parted and the formation to be accessed. The core is inserted into the sheath 295 and the resilient nature of the sheath 6 tends to close the two part of the base layer and retain the core in the sheath. The core 7 may be adhered or bonded to the sheath using a suitable bonding agent if required.

9 The assembled sealing member 291 shown in Figure 28B may then be used in the manner described above, for example to create a downhole packer. This embodiment has 11 the advantage that a sealing member can be created with different properties by the 12 combination of sheaths and cores of different designs. For example, the sheath may be 13 used to encapsulate a core of expanding material having a different swelling characteristic 14 to create a hybrid sealing member. The core may function as the substrate, or may be arranged to convey a fluid or a signal through the sealing member.

17 It will be appreciated that the although the sealing member 291 is configured as a sheath 18 and insert, it may instead be configured as one or more expanding components coupled to 19 a core, a layer or another elongate component, which may have different physical properties to the expanding component. Advantageously the expanding component or 21 components will at least partially encapsulate the core to facilitate the provision of a seal.

23 Figures 29A and 29B show schematically an alternative packer configuration, generally 24 depicted at 290 in-situ in a wellbore 202 in unexpanded and expanded conditions. In this embodiment, the packer 290 is formed from a sealing member 250 (as described with 26 reference to Figure 24) applied to a tubular 12. An end ring 204 is provided over the end 27 of the expanding portion 206, and a similar end ring is provided at the opposing end of the 28 expanding portion (not shown). The end ring 204 is similar to the end ring described with 29 reference to Figures 6A and 6B, although in this case a longitudinal recess 203 extends through the end ring 204 to allow the sealing member 250 to pass beneath it.

32 In this embodiment, the packer is constructed by a method similar to that described with 33 reference to Figures 5A to 50. However, the method differs in that the expanding portion 34 206 is not started at an end of the sealing member 250. In contrast, the expanding portion 206 is formed by beginning to wrap the sealing member at a location distal from its end. In 1 fact, there may be many tens or hundreds of metres of sealing member 250 provided 2 above the point to which the sealing member is wrapped around a tubular 12. At the 3 desired location for forming the packer, the sealing member is redirected from a 4 longitudinal direction to a circumferential direction and is wrapped around the tubular 12.

This redirection may be accomplished with the assistance of a temporary clamp. The end 6 ring 204, which in this case is in two-part, hinged form, is clamped around the sealing 7 member, with the longitudinal recess 203 located over the sealing member. The sealing 8 member is wrapped around the tubular to create the expanding portion 206. It may be 9 necessary to adjust the position of the end ring to ensure that it is tightly placed against the end of the expanding portion 206. The portion 207 of the sealing member 250 located 11 above the packer may be secured to the tubular body 12, for example by cable clamps, 12 and may be coupled to control equipment, such as a source of hydraulic fluid. The cable 13 clamps may be configured to be clamped over an upset on the tubular body 12 such as a 14 tubing or casing coupling.

16 Figure 29B shows the packer in-situ and the wellbore after expansion. The expanding 17 portion has expanded against the formation to create a seal in the annulus 205. In 18 addition, the portion 207 of the sealing member located above the packer 290 has 19 expanded due to its exposure to wellbore fluid. However, the portion 207 above the packer is substantially longitudinally oriented, and therefore does not create a seal with the 21 annulus 205. In addition, this portion 207 of the sealing member is not restrained laterally.

22 This means that it is liable to expand proportionally less in the radial direction of the tubular 23 12, when compared with the coiled portion of the sealing member, which is laterally bound.

Although the packer creates a seal in the annulus, there is continuous path from the region 26 above the packer to a region below the packer, via the conduit provided in the sealing 27 member 250. In this example, the path is a hydraulic line for the supply of hydraulic fluids.

28 In other embodiments, this conduit can be used for the deployment of fluids, cables, fibre 29 optics, hydraulic lines, or other control or data lines across the seal.

31 One specific application of the invention is to artificial lift systems using electric 32 submersible pumps (ESP5). In ESP systems it will typically be necessary to deploy a 33 power cable from surface to the ESP, through a packer which creates an annular seal.

1 In the above-described embodiments, the sealing members have substantially rectangular 2 cross sectional profiles. In the examples shown, the sealing member has a width in the 3 range of 5 mm to 100 mm, and a height in the range of 5 mm to 80 mm, in its 4 unexpanded condition. Other cross sectional profiles may also be used, and there will now be described a number of alternative examples, with reference to Figures 31 to 42.

7 Figure 30 shows in cross-section a sealing member 300 having a flat bottom surface 302 8 and a continuously curved upper surface 304 which defines the sides and the top of the 9 sealing member 300. Figure 31 shows a sealing member 310, similar to a sealing member 300, parts comprising a core 306 of a high strength material, such as a metallic 11 mesh, which allows fluid flow through the sealing member.

13 Figure 32 shows in cross sectional a sealing member 320 having a triangular profile. The 14 sealing member 320 defines a flat bottom surface 308, and flat side surfaces 312.

16 Figure 33A shows in cross-section a sealing member 330, having a "T-shaped" profile.

17 The sealing member 330 defines a flat bottom surface 314 and stepped side surfaces 316 18 defining a protruding spine 315. The sealing member is symmetrical about a central axis 19 C. Figure 33B shows the same sealing member 330 in an inverted position, in which the sealing member may also be applied to a body.

22 Figures 34A and 34B schematically show the application of the sealing member 320 to the 23 surface of a tubular body 12. The sealing member 320 is wrapped onto the tubular body 24 12 according to the methods described above. This creates a layer 317 with a ridged profile 318, shown in Figure 34A. Subsequently, a second layer 319 of sealing member 26 320 is wrapped over the first layer 317, with successive turns of the sealing member 27 located in grooves created by the first layer 317. The resulting structure is an expanding 28 portion 322 with a cylindrical outer surface.

The second layer 319 of the sealing member could be wrapped in the same direction as 31 the first layer, or alternatively could be wrapped in the opposite direction. In some 32 embodiments, the second layer 319 of the sealing member could be formed from the same 33 length of sealing member, without cutting between layers. In other embodiments, the 34 second layer 319 may be formed from a sealing member having a different profile, or indeed different material characteristics. For example, the second layer 319 of sealing 1 member may be selected to swell in hydrocarbon fluid at a different rate from the first layer 2 317.

4 Figures 35A and 35B schematically show the application of the sealing member 330 to a tubular body 12. The process is similar to that described with reference to Figures 34A 6 and 34B. A first layer 324 of the sealing member is formed on the tubular body by the 7 rapid process as described above. The second layer 326 of a different sealing member 8 328 is wrapped into formations defined by the profile of the sealing member 330. In this 9 embodiment, the sealing member 328 comprises an outer layer 332 surrounding an electrical conducting core 334.

12 Figures 36A to 360 schematically show the application of the sealing members 330 and 13 328 in an alternative configuration. Sealing member 328 is wrapped in a first layer 336 on 14 the tubular 12. The sealing member is wrapped adjacent a spacing member 338, which may be wrapped simultaneously with the sealing member 328, or in a consecutive 16 application step. When the positioning and tension of the sealing member 328 is 17 satisfactory, the spacing member 338 is removed to leave a spaced layer 342 of the 18 sealing member 328 on the tubular body, as shown in Figure 36B. In a subsequent step, a 19 second layer 344 of the sealing member 330 is applied to the space layer 342 in an inverted configuration, such that the protrusion of the T shaped profile is received in the 21 spaces left by the spacing member.

23 Figure 37 schematically shows an expanding portion 345 formed from a sealing member 24 346 in accordance with an alternative embodiment of the invention. The sealing member has a stepped profile. One side of the sealing member 346 has a recess 348, which 26 corresponds to the shape of a protrusion 352 on the opposing side of the sealing member 27 346. Thus the opposing sides of the sealing member 346 are shaped to fit together with 28 one another in an interlocking fashion, such that consecutive turns of the sealing member 29 self locate with one another.

31 Figure 38 schematically shows an expanding portion 354 formed from a sealing member 32 356. The sealing member 356 is similar to the sealing member 346, having a stepped 33 profiled such that the opposing sides are shaped to fit together. However, in this 34 embodiment, the sealing member 356 includes a ridge 358 which corresponds with a 1 groove 362 to create an interlocking profile which self locates and resists lateral 2 separation.

4 Figure 39 shows a sealing member 340 in cross sectional profile. The sealing member 340 is substantially rectangular profile, but includes on one side wall 364 a pair of 6 longitudinally extending grooves 366 which corresponds with a pair of longitudinally 7 extending ridges 368 on the opposing side wall 365. In use, the ridges 368 are located in 8 the grooves 366 of an adjacent turn on a tubular body 12.

Figure 40 shows a cross-section a further sealing member 350 comprising a triangular 11 profile and pairs of corresponding ridges 372 and grooves 374, which function in a similar 12 manner to the ridges and grooves of sealing member 340, but in the layered configuration 13 shown in Figure 33B.

Figure 41 shows in perspective view of a sealing member 360 in accordance with a further 16 alternative embodiment of the invention. The sealing member 360 has a substantially 17 rectangular cross sectional profile, but one which varies in dimensions over the length of 18 the sealing member 360. The side walls 376 are formed into a series of angular ridges 19 375 and grooves 377 with corresponding profiles on the opposing walls. In use, the grooves formed in the side wall of one turn of the sealing member on the body receive 21 ridges of the side wall of an adjacent turn. This arrangement increases the surface area of 22 the interface between adjacent turns, and assists in the retention of tension in the turns 23 forming the expanding portion.

A further alternative embodiment of the invention shown in Figure 42, which is a cross 26 sectional view of a sealing member 370 comprising a substantially rectangular profile and 27 a supporting substrate 378. In this embodiment, the supporting substrate provides 28 interlocking formations 382, 384 such that adjacent turns of the sealing member 370 self 29 locate and resist lateral separation in use.

31 The foregoing description relates primarily to the construction of wellbore packers on 32 tubulars. It will be appreciated by one skilled in the art that the invention is equally 33 applicable to packers formed on other apparatus, for example mandrels or packing tools 34 which are run on a wireline. In addition, the present invention has application to which extends beyond conventional packers. The invention may be particularly valuable when 1 applied to couplings and joints on tubulars and mandrels. The invention can also be 2 applied to coiled tubing, for use in coiled tubing drilling or intervention operations.

3 Furthermore, the body need not be cylindrical, and need not have a smooth surface. In 4 some embodiments, the body may be provided with upstanding formations or inward recesses with which a sealing member cooperates on the body.

7 The sealing member could also be used on components such as sliding sleeves, or 8 components which are not longitudinally oriented in a pipeline or wellbore.

The sealing member could be applied over many consecutive lengths of coupled tubulars, 11 continuously over pipe couplings, or in discrete sections. The sealing member could be 12 used to secure and seal casings during wellbore construction. The present invention 13 provides a system which is sufficiently flexible and cost effective over long seal lengths to 14 replace the use of cement in many applications.

16 The invention also has applications in the encapsulations of tools, cables and downhole 17 probes and sensors. Figure 43 schematically shows such an application in cross section.

18 In this assembly, generally shown at 380, comprises a sealing member 30 wrapped 19 around a tubular 12 to form an expanding portion 382. The assembly comprises a support element 390, also shown in perspective view in Figure 44. The support element 390, 21 which could be made from swellable elastomer, plastic or metal, comprises a part-circular 22 inner profile 384, and a curved outer surface 386. A longitudinal groove 388 is formed in 23 the outer surface and accommodates a cable 392 when the support element is located 24 longitudinally on the tubular 12. The sealing member 30 is wrapped around the tubular 12 and the support element 390, with the cable extending through the groove 388.

27 In the arrangement of Figure 43, the expanding portion 382 is of elliptical cross section.

28 This may be acceptable in some applications. For example, where the radial extent of the 29 support member is small in comparison to the tubular outer diameter and/or outer diameter of the expanding portion in its expanded condition such that the eccentricity is small, the 31 expanding portion may readily form a seal in the annulus. Figure 45 shows in cross 32 section an alternative embodiment of the invention, generally depicted at 400, in which the 33 support member 394 as a circular outer profile which supports the sealing member in use.

34 The arrangements of Figures 43 to 45 could be used as an alternative to cable clamps.

1 Although the foregoing description relates to the use of the invention for creating a seal 2 between the body and a surface exterior to the body, the principles of the invention can 3 equally be used to create an annular seal between a body and a surface internal to the 4 body. An example of such application is illustrated with reference to Figures 46 to 48.

6 Figure 46 shows a lower part of an overshot tool 410, comprising a tubular 412. An upper 7 part (not shown) of the tool is configured for connection to a toolstring. The tubular 412 8 has an open end 414, and an internal surface having a recessed thread 416 dimensioned 9 to accommodate a sealing member 330, shown in detail at Figure 33A. The protruding spine 315 of sealing member 330 is fed into the thread 416. The sealing member is 11 selected to be resilient, such that feeding it into the thread and coiling it internally to the 12 tubular 412 tends to cause a resultant straightening force which biases the sealing 13 member against the internal surface and retains it in the thread. The sealing member 330 14 is fed to create multiple turns of the around the longitudinal axis of the tubular, with side walls of successive turns in abutment. In this embodiment, the sealing member creates a 16 cylindrical protrusion to the inner surface of the tubular, but in alternative embodiments the 17 sealing member is flush with the inner surface or recessed in the thread.

19 The open end of the tubular is sized to be placed over (or to overshoot) a body 418 in a wellbore, which may be a cut casing, as shown in Figure 47A. The overshot tool 410 21 comprises additional mechanisms (not shown) for engaging the body 418. With the body 22 surrounded, exposure of the sealing member to wellbore fluid causes expansion of the 23 sealing member to form an annular seal between the tool and the body, as shown in 24 Figure 47B.

26 The present invention also has application to expansion joints. The sealing member may 27 be used to create a seal between a polished mandrel and an outer tubular of a telescopic 28 overshot tool that can accommodate axial expansion and contraction of the tubular or 29 mandrel through changes in ambient temperature. Typically travel for expansion joints can be up to 6m to 9m (20-30 feet), and the invention provides a suitable means for creating a 31 seal over this range of distances.

33 The present invention relates to sealing apparatus for use downhole, a sealing member, a 34 method of forming a downhole apparatus, and methods of use. The sealing member of the invention may be conveniently used in isolation tools and systems, in cased and 1 uncased holes. The invention provides sealing mechanisms and isolation tools and 2 systems which may be manufactured and assembled more efficiently than in the case of 3 the prior art, and which are flexible in their application to a variety of welibore scenarios.

By creating a sealing arrangement from an elongated member, it may be easier to 6 assemble the apparatus when compared with conventional slip-on apparatus. For 7 example, the apparatus could be formed on a central 2 metre portion of a 12 metre casing 8 section. The sealing member is economical to manufacture, compact to store, and easy to 9 handle when compared with the materials used in conventional swellable packers.

11 The process of forming the packer offers several advantages. Firstly, the process does 12 not require specialised equipment requiring large amounts of space or capital expenditure.

13 The process can be carried out from a central portion of the tubular body, by attaching a 14 first end of the sealing member and coiling it around the tubular, reducing the difficulties associated with slipping tool elements on at an end of the tubular and sliding them to the 16 required location. This facilitates application of the sealing member to significantly longer 17 tubulars, and opens up the possibility of constructed packer on strings of tubing on the rig 18 floor immediately prior to or during assembly. The construction process allows for a high 19 degree of flexibility in tool design. For example, a packer of any desired length can be created from the same set of components, simply by adjusting the length over which the 21 sealing member is coiled on the tubular body. Packers and seals can be created on 22 bodies and tubulars of a range of diameters. The principles of the invention also inherently 23 allow for engineering tolerances in the dimensions of bodies on which the seal is created.

The resulting packers may have increased surface area with respect to an equivalent 26 packer with an annular mantle, allowing for faster expansion to the sealing condition. The 27 elongated sealing member also lends itself well to post-processing, for example 28 perforating, coating or performing analysis on a sample.

The use of a substrate or a material with different mechanical characteristics in the sealing 31 member allows more tension to be applied and retained in the sealing member during the 32 construction process, and reduces any tendency of the sealing member to swage. It also 33 binds to the swellable material, and resists expansion of the sealing member in a 34 longitudinal direction.

1 The invention can be used to create a seal in the annulus with a continuous path from 2 region to above the seal to a region below the seal, via the conduit provided in the sealing 3 member. For example, the path is a hydraulic line for the supply of hydraulic fluids. In 4 other embodiments, this conduit can be used for the deployment of fluids, cables, fibre optics, hydraulic lines, or other control or data lines across the seal. One specific 6 application of the invention is to artificial lift systems using electric submersible pumps 7 (ESPs). A sealing member in one aspect of the invention comprises a power cable for an 8 ESP.

It will be appreciated by one skilled in the art that the invention is applicable to packers 11 formed tubulars, mandrels, or packing tools which are run on a wireline. In addition, the 12 present invention has application to which extends beyond conventional packers. The 13 invention may be particularly valuable when applied to couplings and joints on tubulars 14 and mandrels. The invention can also be applied to coiled tubing, for use in coiled tubing drilling or intervention operations.

17 The sealing member could be applied over many consecutive lengths of coupled tubulars, 18 continuously over pipe couplings, or in discrete sections. The sealing member could be 19 used to secure casings during wellbore construction. The present invention provides a system which is sufficiently flexible to replace the use of cement in many applications. The 21 principles of the invention can equally be used to create an annular seal between a body 22 and a surface internal to the body.

24 Variations to the above described embodiments are within the scope of the invention, and combinations of features other than those expressly clauseed form part of the invention.

26 Unless the context requires otherwise, the physical dimensions, shapes, internal profiles, 27 end rings, and principles of construction described herein are interchangeable and may be 28 combined within the scope of the invention. For example, any of the described internal 29 profiles of sealing member may be used with the described external profiles. The principles of construction described above may apply to any of the described profiles, for 31 example, the described bonding method or the heat curing method may be used with any 32 of the sealing members described. Additionally, although the invention is particularly 33 suited to downhole use it may also be used in topside and subsea applications such as in 34 pipeline systems. It may also be used in river crossing applications.

1 The present application is a divisional application relating to earlier filed United Kingdom 2 patent application number GB080351 7.2. The following clauses correspond to the claims 3 of said earlier international patent application as filed and, whether explicitly recited in the 4 claims or not, describe further aspects of the invention.

6 Clauses: 8 A. A downhole apparatus comprising: 9 a body having a longitudinal axis and a sealing arrangement located on the body; wherein the sealing arrangement comprises at least one elongated sealing member 11 with an axis of elongation extending around the longitudinal axis of the body, and the 12 sealing member comprises a material selected to expand on exposure to at least 13 one predetermined fluid.

B. The downhole apparatus according to clause A, wherein the sealing arrangement 16 forms an annular seal in use.

18 C. The down hole apparatus according to clause B, wherein the sealing arrangement 19 provides isolation between one region of a wellbore annulus above the apparatus and another region of the wellbore annulus below the apparatus.

22 D. The downhole apparatus according to any preceding clause, wherein the body is 23 substantially cylindrical and the sealing member extends circumferentially around the 24 body.

26 E. The downhole apparatus according to any preceding clause, wherein the sealing 27 member extends around an outer surface of the body.

29 F. The downhole apparatus according to any preceding clause, wherein the sealing member extends around an inner surface of the body.

32 G. The downhole apparatus according to any preceding clause, wherein the sealing 33 member forms an expanding portion, which is substantially cylindrical in form and 34 which extends over a length of the body.

1 H. The downhole apparatus according to any preceding clause, wherein the sealing 2 member is coiled on the body.

4 I. The downhole apparatus according to clause H, wherein the sealing arrangement comprises a plurality of turns formed on the body such that a lower edge of a turn 6 abuts an upper edge of a successive turn and creates a seal with the upper edge of 7 the successive turn.

9 J. The downhole apparatus according to any of clauses A to H, wherein the sealing arrangement comprises a plurality of turns formed on the body such that a lower 11 edge of a turn is spaced from an upper edge of a successive turn.

13 K. The downhole apparatus according to any preceding clause, wherein the sealing 14 member is formed by co-extrusion of two materials selected to differ in one or more of the following characteristics: fluid penetration, fluid absorption, swelling coefficient, 16 swelling rate, elongation coefficient, hardness, resilience, elasticity, and density.

18 L. The down hole apparatus according to any preceding clause, wherein the sealing 19 member comprises one or more expanding components coupled to an elongate component.

22 M. The downhole apparatus according to clause L, wherein the expanding component 23 at least partially encapsulates the elongate component.

N. The downhole apparatus according to clause L or clause M, wherein the expanding 26 component comprises at least one formation configured to attach the expanding 27 component to an elongate component.

29 0. The downhole apparatus according to clause N, wherein the formation is configured to receive a cable or control line.

32 P. The downhole apparatus according to any preceding clause, wherein the sealing 33 member comprises a substrate which extends longitudinally to the sealing member.

1 Q. The downhole apparatus according to clause F, wherein the sealing member is 2 formed from an extrusion around the substrate.

4 R. The downhole apparatus according to any preceding clause, wherein the sealing member comprises a conduit, longitudinally oriented in the sealing member.

7 S. The downhole apparatus according to clause R, wherein the conduit allows fluid 8 access to the material of the sealing member from the interior of the conduit.

T. The downhole apparatus according to any preceding clause, wherein the sealing 11 member couples equipment on one side of a seal created by the apparatus to 12 equipment on an opposing side of the seal.

14 U. The downhole apparatus according to any preceding clause, wherein the sealing member comprises an interlocking profile, configured such that a first side of the 16 sealing member has a shape corresponding to the shape of the second, opposing 17 side of the sealing member.

19 V. The downhole apparatus according to any preceding clause, wherein the sealing member has a profile configured for interlocking multiple layers of a sealing member 21 on the body.

23 W. The downhole apparatus according to any preceding clause, further comprising 24 mechanical attachment means for securing the sealing member to the body.

26 X. The downhole apparatus according to clause W, wherein the mechanical attachment 27 means comprises a formation for receiving an end of the sealing arrangement.

29 Y. The downhole apparatus according to clause W or clause X, wherein the mechanical attachment means comprises an engaging formation for engaging a part of the 31 sealing member.

33 Z. The downhole apparatus according to any of clauses W to Y, wherein the 34 mechanical attachment means comprises means for imparting tension into the elongated sealing member.

2 AA. The downhole apparatus according to any of clauses W to Z, wherein the 3 mechanical attachment means comprises a ratchet mechanism.

BB. The downhole apparatus according to any of clauses W to AA, wherein the 6 mechanical attachment means comprises a release mechanism, actuable from 7 surface and/or by a down hole intervention.

9 CC. The downhole apparatus according to any of clauses W to BB, wherein the mechanical attachment means is configured to be disposed on a coupling of a 11 tubular.

13 DD. The downhole apparatus according to any preceding clause, wherein the elongated 14 sealing member comprises an attachment portion configured to be secured to the body.

17 EE. The downhole apparatus according to clause DD, wherein the attachment portion 18 comprises a formation configured to engage with mechanical attachment means of 19 the apparatus.

21 FF. The downhole apparatus according to any preceding clause, wherein the apparatus 22 is configured as a packer, a liner hanger, or an overshot tool.

24 GG. The downhole apparatus according to any preceding clause, wherein the apparatus is configured as a cable encapsulation assembly, and comprises a support element 26 disposed between the body and the sealing arrangement.

28 HH. The downhole apparatus according to clause GG, wherein the support element is 29 provided with longitudinal groove configured to receive a cable, conduit or other line.

31 II. A sealing member for a downhole apparatus, the sealing member comprising a 32 material selected to expand on contact with at least one predetermined fluid, wherein 33 the sealing member is elongated and is configured to be located on a body of a 34 downhole apparatus such that its axis of elongation extends around the longitudinal axis of the body.

2 JJ. The sealing member according to clause II, configured to form an annular seal 3 between a body and a surface external to the body, in use.

KK. The sealing member according to clause II or clause JJ, configurable to form a 6 substantially cylindrical expanding portion extending over a length of a body.

8 LL. The sealing member according to any of clauses II to KK, wherein the sealing 9 member is formed by co-extrusion of two materials selected to differ in one or more of the following characteristics: fluid penetration, fluid absorption, swelling coefficient, 11 swelling rate, elongation coefficient, hardness, resilience, elasticity, and density.

13 MM. The sealing member according to any of clauses II to MM, comprising one or more 14 expanding components configured to be coupled to an elongate component.

16 NN. The sealing member according to clause NN, wherein the expanding component is 17 configured to at least partially encapsulate the elongate component.

19 00. The sealing member according to clause MM or clause NN, wherein the expanding component comprises at least one formation configured to attach the expanding 21 component to an elongate component.

23 PP. The sealing member according to clause 00, wherein the formation is configured to 24 receive a cable or control line.

26 QQ. The sealing member according to any of clauses II to PP, comprising a substrate 27 which extends longitudinally to the sealing member.

29 RR. The sealing member according to any of clauses II to QQ, comprising a conduit, longitudinally oriented in the sealing member.

32 SS. The sealing member according to clause RR, wherein the conduit allows fluid access 33 to the material of the sealing member from the interior of the conduit.

1 TT. The sealing member according to any of clauses II to SS, comprising an interlocking 2 profile, configured such that a first side of the sealing member has a shape 3 corresponding to the shape of the second, opposing side of the sealing member.

UU. The sealing member according to any of clauses II to TT, comprising a profile 6 configured for interlocking multiple layers of the sealing member on a body.

8 VV. A method of forming a downhole apparatus, the method comprising the steps of: 9 a) Providing a body having a longitudinal axis; b) Providing at least one elongated sealing member comprising a material 11 selected to expand on exposure to at least one predetermined fluid; 12 c) Forming a sealing arrangement on the body by locating the at least one 13 elongated sealing member on the body, with its axis of elongation extending 14 around the longitudinal axis of the body.

16 WW. The method according to clause VV, comprising the step of forming multiple turns of 17 the elongated sealing member on the body.

19 XX. The method according to clause VV or clause WW, wherein the elongated sealing member comprises a power cable for a downhole apparatus.

22 YY. A method of forming a seal in a downhole environment, the method comprising the 23 steps of: 24 a) Configuring a sealing apparatus from a body and at least one elongated sealing member arranged on the body and comprising a material selected to expand on 26 exposure to at least one predetermined fluid; 27 b) Running the sealing apparatus to a downhole location such that the sealing 28 apparatus is disposed adjacent a surface; 29 c) Exposing the elongated sealing member to at least one fluid to expand it to an expanded condition, in which a seal is created between the body and the 31 surface.

33 ZZ. A method of constructing a wellbore, the method comprising the steps of: 34 a) Assembling a first casing string from a plurality of casing sections; 1 b) Forming at least one sealing arrangement on the casing from at least one 2 elongated sealing member comprising a material selected to expand on 3 exposure to at least one predetermined fluid; 4 c) Running the first casing string to a downhole location; d) Exposing the sealing arrangement to at least one welibore fluid, thereby 6 expanding the sealing arrangement into contact with a downhole surface.

8 AAA. The method according to clause ZZ, comprising the step of forming sealing 9 arrangements over a majority of the length of the casing string.

11 BBB. The method according to clause ZZ or clause AAA, wherein the downhole surface is 12 the surface of an uncased hole.

14 000. The method according to any of clauses ZZ to BBB, comprising the step of running a second casing string inside the first casing string.

17 DDD.The method according to clause CCC, comprising the step of forming at least one 18 sealing arrangement on the second casing from at least one elongated sealing 19 member comprising a material selected to expand on exposure to at least one predetermined fluid.

22 EEE. The method according to clause DOD, comprising the step of exposing the sealing 23 arrangement of the second casing to at least one welibore fluid, thereby expanding 24 the sealing arrangement into contact with the first casing string. The method may be repeated with third, fourth and other casing strings.

27 FFF. A well bore packer comprising an expanding portion formed from an elongated 28 sealing member coiled around a body, the elongated sealing member comprising a 29 material selected to expand on exposure to at least one predetermined fluid.

31 GGG. An elongated member for forming a wellbore packer, the elongated member 32 comprising a material selected to expand on exposure to at least one predetermined 33 fluid.

HHH.An overshot tool comprising a tubular body and an opening configured to be 36 disposed over a body to be coupled in use, and a sealing arrangement arranged on 1 the inner surface of the tubular body, wherein the sealing arrangement comprises at 2 least one elongated sealing member with an axis of elongation extending around the 3 longitudinal axis of the body, and the sealing member comprises a material selected 4 to expand on exposure to at least one predetermined fluid.