Device for lining or obturating a wellbore or a pipe

Abstract

A device for lining or obturating a wellbore or a pipe. The device includes a tubular radially-expandable lining and at least one ring seal carried by the lining. The seal includes at least one first part formed by a filament or a braid mounted spirally about the external surface of the lining.

Claims

1. A device for lining or obturating a wellbore or a pipe, said device comprising: a tubular radially expandable lining made of metal; and at least one ring seal carried by said lining, wherein the seal comprises at least one first part and second part each formed by a filament or a braid carried by said lining, the first and second parts being mounted spirally about the external surface of said lining on a single level, and being axially adjacent to one another along a longitudinal axis of the lining.

2. The device according to claim 1, wherein the first part is connected to the second part by a link.

3. The device according to claim 2, wherein the link comprises a linking element positioned about the lining and formed by aramid fibers encapsulated in a rubber sheath.

4. The device according to claim 2, wherein said link comprises a linking ring disposed about the lining between the first part and the second part, and overlapping an end portion of each of the first and second parts.

5. The device according to claim 1, wherein the second part has a coefficient of thermal expansion greater than that of the first part.

6. The device according to claim 1, wherein the first part comprises a filament or a braid made of graphite.

7. The device according to claim 1, wherein the second part consists of polymer.

8. The device according to claim 7, wherein said polymer is Polytetrafluoroethylene (PTFE).

9. The device according to claim 1, wherein the second part is made of Polytetrafluoroethylene (PTFE) impregnated with graphite.

10. The device according to claim 1, wherein at least one of the first part or the second part comprises a stiffener element made of carbon, glass fiber, aramid, stainless steel, or a nickel/chromium alloy.

11. The device according to claim 1, wherein a periphery of said seal is covered, at each of two ends of said seal, by a holding ring for holding said seal to the lining.

12. The device according to claim 11, wherein at least one of said holding rings is mounted so as to exert a compressive force along the longitudinal axis of the lining on said seal.

13. The device according to claim 12, wherein each of said holding rings is fixed to said lining.

14. The device according to claim 1, wherein said lining carries several seals spaced out along the longitudinal axis of the lining.

15. The device according to claim 1, wherein the lining is mounted on and surrounds a tubular part intended to form a part of a conduit of a wellbore/drill hole.

16. The device according to claim 1, wherein said lining forms part of a tubular sleeve that is to be placed in a conduit of a wellbore/drill hole.

Description

5. LIST OF FIGURES

(1) Other features and advantages of the technique described shall appear more clearly from the following description of two preferred embodiments, given by way of a simple, illustratory and non-exhaustive example and from the appended figures, of which:

(2) FIG. 1A is a view in perspective of the lining device of the invention bearing a packer or packer unit according to a first embodiment;

(3) FIG. 1B is a detailed view of the device of FIG. 1A;

(4) FIG. 2A illustrates a variant of the mounting of the packer unit according to the first embodiment;

(5) FIG. 2B is a detailed view in section of the device of FIG. 2A;

(6) FIGS. 3A to 3C provide a schematic illustration of the thermal expansion of the braids forming the packer unit according to the first embodiment;

(7) FIG. 4 is a view in perspective of the device of the invention provided with several spaced out packer units;

(8) FIGS. 5A to 5F are different views of the device of the invention bearing a packer unit according to a second embodiment;

(9) FIGS. 6A and 6B are views in perspective and in section of the device for obturating according to the invention carrying a packer unit according to the first embodiment;

(10) FIG. 7A is a view in perspective of an alternative lining device described with reference to FIGS. 1A and 1B;

(11) FIG. 7B is a view in longitudinal section of the sleeve of FIG. 7A, FIGS. 7C and 7D being detailed views of FIG. 7B.

6. DESCRIPTION

(12) Here below, we present two embodiments of the sealing means of the device of the invention.

(13) It must be noted that these two embodiments are not limited to a device that is to be expanded in the casing of a so as to seal or lined this wellbore (the device in this case serves as a sealing patch).

(14) The sealing means can also be implemented when the device of the invention serves as an annular barrier that is to be expanded in an annular space to provide a barrier that is to be expanded in an annular space to provide a barrier on either side of this annular space between a casing and a drill hole (i.e. a rough drill hole) or between two concentric casings of a wellbore.

6.1 First Embodiment

(15) Referring to FIGS. 1A and 1B, we present a first embodiment in which the device or patch 1 comprises a radially expandable lining or sleeve 11 that is a cylindrical tube made of metal, especially steel, on which a packer unit 12 is mounted.

(16) The metal must be both resistant (mechanically and to corrosion) and sufficiently ductile to be able to be appropriately expanded.

(17) The packer unit 12 is formed by a winding of two braids 121, 122 surrounding the lining 11 and carried by this lining. The ends of the braids 121, 122 are gripped within annular rings 125 which are fixed to the lining 11.

(18) In one alternative, the packer unit 12 is formed by a winding of two filaments that surround the lining 11 and are carried by this lining.

(19) Another alternative is described here below with reference to FIGS. 7A to 7D.

(20) Classically, the lining 11 is expanded by means of an expansion tool (cone, hydroforming tool or inflatable packer) until the packer unit comes into contact with the wall of the wellbore and provides sealing (it plugs a leak for example and enables the wellbore to be repaired).

(21) The two sealing braids 121, 122 are mounted longitudinally (i.e. along the longitudinal axis A of the lining 11) and spirally around the external surface of the metal lining 11, as illustrated in FIG. 1A, each braid winding being in contact with the previous one. The radial winding of each braid 121, 122 is implemented at only one level.

(22) It can be noted that the two braids 121, 122 are juxtaposed and in contact with each other (FIG. 1B). The link between the first braid 121 and the second braid 122 is provided in this example by a braid 123 made of aramid fiber encapsulated in a rubber sheath. This linking braid 123 provides for continuity between the first braid 121 and the second braid 122.

(23) The link between the first braid 121 and the second braid 122 can be provided by another type of fiber or by a mechanical linking element.

(24) FIG. 2A is a view in perspective of the expandable sleeve carrying a double braid 121, 122 and a linking ring 124 for the braids 121, 122. FIG. 2B is a detailed view showing the linking ring 124 which covers one end of each of the first and second braids 121, 122, these braids not being in contact with each other.

(25) In this example, the first braid 121 is constituted by carbon filaments and graphite filaments that are intermingled (here below the term used is carbon/graphite braid), the second braid 122 being formed by filaments made of polytetrafluorethylene (abbreviated as PTFE) impregnated with graphite (here below called PTFE/graphite braid).

(26) It is noted that the first braid can be formed by graphite filaments intermingled with carbon, stainless steel, INCONEL (registered mark) alloy or PTFE filaments, and that the second braid can be formed by polymer filaments only, or polymer filaments intermingled with graphite-impregnated, aramid, fiber-glass or nickel-chrome alloy filaments.

(27) It must be noted that polymers other than PTFE can be used in the packer unit 12.

(28) In other words, the packer unit 12 is a deformed hybrid braid formed by two axially juxtaposed (adjacent) and linked braids 121, 122 that form only one winding.

(29) The second braid 122 made of PTFE/graphite has optimal sealing properties because PTFE softens at the service temperature of the patch 1 (i.e. the prevailing temperature in the vicinity of the patch 1 when it is in a wellbore).

(30) In order to avoid any risk of creep (i.e. the irreversible deformation) of this second braid 122, the first braid 121 made of carbon/graphite which is more temperature stable and ensures the stability of the unit (i.e. packer unit 12) is associated with it.

(31) This first braid 121 made of carbon/graphite thus fulfils an anti-extrusion function to eliminate or at least limit the creep of the second braid 122 made of PTFE/graphite.

(32) Contrary to PTFE, carbon/graphite has a low thermal expansion coefficient and practically does not get inflated at high temperatures (the first braid 121 therefore does not help in the sealing at high temperatures, this function being fulfilled by the second braid 122 made of PTFE/graphite).

(33) In other words, to use the patch 1 at high temperature (beyond 330 C.), a stable material (in the form of an adjacent braid 121 made of carbon/graphite) must be associated with the PTFE/graphite braid 122 (which provides the tight sealing), to ensure the temperature stability of the packer unit 12.

(34) It can be noted that PTFE has a high thermal expansion coefficient as compared with carbon/graphite. As a consequence, when the temperature of use of the patch 1 drops, the contraction of the second braid 122 is greater than that of the first braid 121, the latter then having sealing properties superior to those of the second braid 122.

(35) Indeed, this thermal expansion of the braids 121, 122 is illustrated schematically in FIGS. 3A to 3C.

(36) FIG. 3A shows the braids 121, 122 when they are applied in a tightly sealed manner against the internal face or wall F of the casing C at the zone to be sealed, when the lining 11 is expanded.

(37) As illustrated in FIG. 3B, the braids 121, 122 expand when the temperature increases and get placed flat to a greater extent against the wall F, the second braid 122 furthermore compressing the first braid 121 along the longitudinal axis of the lining 11 against the ring 125. When the temperature drops (FIG. 3C), the contraction of the second braid 122 is greater than that of the first braid 121, the first braid 121 then having greater sealing properties than those of the second braid 122.

(38) The packing unit 12 therefore combines the advantage of offering improved sealing quality (thus reducing the rate of leakage) and that of being stable in thermal cycling (high T C. repeated several times).

(39) FIG. 4 is a view in perspective showing a patch 1 that carries several packer units 12A to 12D, these packer units being possibly disposed at regular intervals (or non-regular intervals) longitudinally (along the axis A). Each packer unit 12A, 12B, 12C, 12D is formed for example by a first carbon/graphite braid and a second PTFE/graphite braid, each of these braids being capable of withstanding high temperatures and pressures.

(40) It can be noted that the first braid 121 of carbon/graphite filaments can withstand high temperatures (of up to 550 C. or 1000 F.), the second braid 122 made of PTFE/graphite can withstand temperatures higher than 300 C. Such braids can withstand pressures of over 210 bars.

(41) In other words, the tight-sealing means of the patch 1 can withstand high temperatures and pressures because of the use of appropriate materials.

(42) These materials furthermore have high mechanical worthiness over time and have low sensitivity or no sensitivity to the temperature cycles (thermal cycling), which makes them particularly suited to the sealing of wellbores in which steam injection (CSS method for example) is used for the extraction of petroleum.

6.2 Second Embodiment

(43) Referring to FIGS. 5A to 5F, we present a second embodiment of the sealing means of the device of the invention in which the device or patch 2 comprises a radially expandable lining 21 which is a cylindrical tube made of metal, especially steel, on which a packer unit 22 is mounted.

(44) The packer unit 22 is formed by a braid 224 surrounding the lining 21 and carried by this lining (FIG. 5D). In one alternative, the packer unit 22 is a filament.

(45) The sealing braid 224 is mounted longitudinally in a spiral about the external surface of the metal lining 21, the radial winding of the braid 24 being implemented on a single level as illustrated in FIGS. 5E and 5F.

(46) In the second embodiment, the braid 224 is mounted on the lining 21 of the patch 2 in such a way as to obtain a rate of elongation of the braid 24 and therefore of the packer unit 22 of the patch 2 which is far greater than the rates of elongation, ranging from 2% to 10%, of the packer units (made of graphite/carbon especially) of the prior-art patches.

(47) FIGS. 5A to 5F provide a schematic illustration of the particular method of installing/mounting the braid 224 on the metal lining 21 of the patch 2 which optimizes the rate of elongation of the braid 224 and provides for improved sealing.

(48) In this example, the braid 224 is made of reinforced graphite.

(49) Once the braid 224 is mounted spirally on the external surface of the metal lining 21 of the patch 2, as illustrated in FIG. 5A, rings 225 are threaded into the lining 21 and attached to each end of the braid 234 to encapsulate the end portions of this braid as shown in FIG. 5B.

(50) FIG. 5E is a view in section showing the rings 225 mounted on the lining 21 and partially covering the braid 224 in its end portions.

(51) As illustrated by the arrows of FIG. 5C, an axial compressive force (along the longitudinal axis A of the lining 21) towards the braid 224 is applied on the two rings 225 so as to compress the braid 224 axially. It can be noted that this axial compression slightly increases the diameter of the packer unit 22 formed by the braids 224.

(52) In one alternative, the axial compressive force is applied only to one of the two rings 225.

(53) The rings 225 are then soldered to the lining 21 and the axial compressive force is relaxed. The braid 224 is thus maintained on the lining 21 by means of the rings 225 which are fixed to the lining 21 (FIG. 5F).

(54) The fact of compressing the spirally mounted braid 224 laterally (along the longitudinal axis of the lining 21) causes compression tangentially (in the sense of the fiber). When the lining 21, and therefore the patch 2, are expanded, the braid 224 is subjected to a tangential tensile force in the reverse direction.

(55) This method of installation enables a rate of elongation of the braid 224 of over 10%, or even about 20%, which increases the rate of expansion of the patch 2 and the possibilities of installing this patch 2.

(56) Just as in the case of the first embodiment illustrated, this second embodiment also makes it possible in a simple way to provide a compact patch, ensuring high sealing quality at high temperatures and pressures (400 C. for example) and showing efficient mechanical behavior over time.

(57) In one particular embodiment (not shown) the lining of the patch carries several braid windings each spaced out and mounted according to the method that has just been described.

(58) The braid 224 can be a braid made of reinforced graphite, stainless steel or INCONEL (registered mark) alloy, the braid being in this case constituted by graphite wires interlaced with stainless steel or INCONEL alloy wires.

(59) In variants, the braid can be a graphite/carbon braid or a graphite/PTFE braid (the PTFE filaments being impregnated with graphite).

6.3 Other Aspects/Variants

(60) It must be noted that the first embodiment and the second embodiment can be implemented independently of each other or in combination.

(61) Thus, the packer element 22 of the second embodiment can be formed by a braid made of two juxtaposed parts and connected by bonding means according to the first embodiment.

(62) In each of the embodiments described here above, the packer unit of the lining can be constituted by several braid windings (called blocks or packings) which are mounted on the external surface of the lining of the patch at regular (or non-regular) intervals.

(63) By way of an example, the lining can carry a series of three windings, 30 cm wide, spaced out at a predetermined distance or else 30 windings, with a width equal to 2 cm and spaced out at a predetermined distance. Each winding comprises a single braid or two braids, connected by bonding means, that are pre-compressed or not pre-compressed by compression rings at their ends.

(64) The braids implemented are preferably square-sectioned.

(65) Each of them can include one or more strands made of rubber which enables the elasticity of the corresponding braid to be increased.

(66) Each part of the packing element can be formed by a filament rather than a braid.

(67) The device of the invention can be implemented in petroleum wellbores or geothermal wellbores. These wellbores can be vertical or inclined.

(68) The device of the invention, the lifetime of which is at least 15 to 20 years, is particularly but not exclusively adapted to CSS wellbores.

(69) FIG. 7A is a view in perspective of an alternative of the lining device described with reference to FIGS. 1A and 1B. The device or patch 1 comprises an expandable sleeve 11. The sleeve 11 carries a single braid 121 forming the first part of the packer unit 12 (it could be a filament in one variant) and an expansion block 126 forming the second part of the packer unit 12.

(70) FIG. 7B is a view in longitudinal section of the sleeve of FIG. 7A, the FIGS. 7C and 7D being detailed views of FIG. 7B.

(71) The expansion block 126 covers an end portion of the braid 121 (FIG. 7C) and is held at the other end by a ring 125 (FIG. 7D) that is permanently fixed to the sleeve 11 (by soldering or any other technique).

(72) The expansion block 126, which is a hollow cylindrical block made of PTFE in this example (with an internal diameter that is slightly greater than the external diameter of the sleeve 11), has a high coefficient of thermal expansion and expands to compress the juxtaposed graphite braid winding 121 (along the longitudinal axis of the sleeve 11) during the rise in temperature (according to the principle described in detailed with reference to FIGS. 3A to 3C).

6.4 Annular Barrier

(73) The sealing means described with reference to the first and second embodiments (when they are implemented in a patch) can be implemented in an isolating/obturating device, or annular barrier).

(74) An isolating device 3 of this kind is shown in FIGS. 6A and 6B in perspective and in section respectively.

(75) In a known way, such an isolating device is supposed to get magnified in an annular space and to form a barrier on either side of this annular space between a tubing (or tubular structure) and an inner wall of a drill hole or between a first tubing and a second tubing which surrounds the first tubing.

(76) In the example shown, the isolating device 3 is mounted on a tubular part 4 (partially shown) which forms part of a tubing of a wellbore.

(77) The isolating device 3 is represented in a non-expanded form in FIGS. 6A and 6B.

(78) When it is expanded, the isolating device 3 isolates for example an annular part of the wellbore in which there prevails a high pressure from anther annular part situated downstream/upstream where a low pressure prevails.

(79) The tubular part 4 is therefore provided along its external face with a metal lining 31 bearing the braid or braids and having ends which are fixedly joined to the external face of the tubular part 4.

(80) More specifically, the ends of the lining 31 are gripped within the annular rings 325.

(81) In the example illustrated in FIGS. 6A and 6B, the lining 31 is provided on its external face with a packer unit 32 formed by two braids 321, 322 juxtaposed along the longitudinal axis A of the lining 31 (in compliance with the first embodiment) and connected by a connecting ring 324, the braids 321, 322 being capable of tightly sealing the lining 31 when it is deformed and placed flat against the wall of a wellbore or of a tubing (not shown).

(82) In one alternative, the lining 31 is provided on its external face with a pre-compressed braid (in compliance with the second embodiment described here above) capable of ensuring the tight sealing of the lining when it is deformed and placed flat against the wall of a wellbore or a tubing.

(83) The lining 31 is deformed when a fluid (not shown) is injected into the internal space of the tubular part 4 under a predetermined pressure, the fluid passing through an aperture (not shown) which makes the interior of the tubular part 4 communicate with the expandable space E, demarcated by the wall of the tubular part of the tubing, the lining 31 and its ends held by the rings 325.

(84) An exemplary embodiment of the present invention is aimed especially at overcoming all or part of the drawbacks of the prior art.

(85) More specifically, the invention is aimed, in at least one embodiment, at providing a radially deformable device intended to ensure the sealing or obturating of a wellbore or a pipe which:

(86) is simple to implement;

(87) can withstand high temperatures and pressures, and ensure efficient sealing at these temperatures and pressures;

(88) preserves its sealing qualities over a wide range of temperatures and pressures;

(89) has high resistance over time;

(90) is compact and does not greatly reduce the section of the wellbore.

(91) It is another goal of the invention, in at least one embodiment, to provide a device that can be easily deformed and has a high elongation rate, at least greater than 10%.

(92) It is yet another goal of the invention, in at least one embodiment, to provide a device that is particularly suited to the ambient conditions of a CSS wellbore (temperature of 20 C. to at least 325 C., and pressures of 210 to 140 bars respectively), and can withstand several temperature cycles (corresponding to the operating cycles of such a CSS wellbore).

(93) Although the present disclosure has been described with reference to one or more examples, workers skilled in the art will recognize that changes may be made in form and detail without departing from the scope of the disclosure and/or the appended claims.