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WO2010065597A2 - Systèmes d'installation tubulaire expansibles, procédés et appareils - Google Patents

Systèmes d'installation tubulaire expansibles, procédés et appareils Download PDF

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Publication number
WO2010065597A2
WO2010065597A2 PCT/US2009/066349 US2009066349W WO2010065597A2 WO 2010065597 A2 WO2010065597 A2 WO 2010065597A2 US 2009066349 W US2009066349 W US 2009066349W WO 2010065597 A2 WO2010065597 A2 WO 2010065597A2
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WO
WIPO (PCT)
Prior art keywords
expandable tubular
expansion
support member
tubular
drive unit
Prior art date
Application number
PCT/US2009/066349
Other languages
English (en)
Other versions
WO2010065597A3 (fr
Inventor
Richard A. Ortiz
Robert Odenthal
Andrei G. Filippov
Alessandro Oscar Caccialupi
Original Assignee
Bp Corporation North America Inc.
Mohawk Energy
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Bp Corporation North America Inc., Mohawk Energy filed Critical Bp Corporation North America Inc.
Publication of WO2010065597A2 publication Critical patent/WO2010065597A2/fr
Publication of WO2010065597A3 publication Critical patent/WO2010065597A3/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/02—Subsoil filtering
    • E21B43/10—Setting of casings, screens, liners or the like in wells
    • E21B43/103—Setting of casings, screens, liners or the like in wells of expandable casings, screens, liners, or the like
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B29/00—Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
    • E21B29/10—Reconditioning of well casings, e.g. straightening

Definitions

  • the present disclosure relates in general to well construction, completion, remediation, and intervention methods and systems. More particularly, the present disclosure relates to well intervention methods, systems and apparatus such as open-hole clads, sidetracking, cased-hole patches, and the like, especially those applications in which the pre-expanded launchers of standard, bottom-up hydraulic systems cannot pass through wellbore restrictions.
  • each system includes a hydraulically assisted backup expansion system, which provides an operational contingency.
  • the systems use a positive seal with a circulation valve for more-reliable pressure containment than conventional dart seals.
  • These systems are advertised to provide single-trip efficiency, and four distinct solutions have been developed: openhole-clad, openhole-liner, cased-hole-liner system, and monobore system.
  • the monobore system is advertised as an openhole liner system that can extend casing and maintain drift of the expanded casing, where "drift" is assumed to mean the drift diameter, which is the inside diameter that the pipe manufacturer guarantees per specifications.
  • U.S. Pat. Nos. 7,363,984 and 7,172,025 disclose similar bottom-up expandable tubulars, systems, and methods. Published U.S. patent applications 2007/0151360 and 2008/0257542 disclose metallurgical and other properties of expandable metal tubulars.
  • a first aspect of the disclosure is an apparatus for radially expanding a tubular member, the apparatus comprising: a) a support member having a forward end and a rearward end; b) a drive unit and an expansion member disposed on the support member providing force for propelling an expansion member through and radially expanding an expandable tubular, the drive unit disposed rearward of the expansion member; c) front and rear anchors disposed on the support member for engaging the expandable tubular' s ID to provide reaction forces to propagate the expansion member through the expandable tubular, the rear anchor positioned behind the drive unit and providing its reaction force after the front anchor has exited the expandable tubular; d) a casing lock disposed on the support member and positioned between the expansion member and the front anchor, releasably securing the expandable tubular to the support member during running-in-hole (RIH); and e) a valve attached to the forward end of the expandable tubular.
  • RHIH running-in-hole
  • apparatus of this disclosure comprise a flow valve fluidly connected to the forward end of the support member, providing the ability for circulation during RIH. After deploying to a desired location in the wellbore, the flow rate may be increased to a level higher than circulation flow rate and then reduced to zero for permanent valve closure thus sealing the tool. If circulation is not possible or undesirable, the valve may be replaced with an end cap.
  • the apparatus further comprises a fluid filter fluidly connected to the support member and positioned at the forward end of the support member, preventing large mud particles from reaching the tool seals and inner mechanisms.
  • the valve attached to the forward end of the expandable tubular assists tool run-in and prevents packing of the expandable tubular with debris. It may also be used to divert flow of drilling fluid around the borehole, thus cleaning and carrying debris through the annulus to surface.
  • FIG. 1 Another aspect of this disclosure are systems for radially expanding tubular members, the systems comprising an apparatus of this disclosure secured to a deployment component such as a coiled tubing (CT) or jointed drill pipe (DP).
  • CT coiled tubing
  • DP jointed drill pipe
  • the invention is directed to a tubular member radial expansion system comprising: a) a deployment component; and b) a tubular member radial expansion apparatus comprising: i) a support member having a forward end and a rearward end; ii) a drive unit and an expansion member disposed on the support member providing force for propelling the expansion member through and radially expanding an expandable tubular, the drive unit disposed rearward of the expansion member; iii) front and rear anchors disposed on the support member for engaging the expandable tubular's ID to provide reaction forces to propagate the expansion member through the expandable tubular, the rear anchor positioned behind the drive unit and providing its reaction force after the front anchor has exited the expandable tubular
  • FIG. 1 Another aspect of the disclosure are methods of radially expanding tubular members, the method comprising: a) deploying an expandable tubular and expansion tool into a wellbore, the expandable tubular secured to a support member of the expansion tool, the support member having a forward end and a rearward end, the rearward end attached to a deployment component communicating with the surface; and b) performing an intervention operation on the wellbore comprising using the expansion tool to expand the expandable tubular and so complete the wellbore, wherein the expansion tool further comprises a drive unit and an expansion member disposed on the support member providing force for propelling the expansion member through the expandable tubular axially from rear to forward and radially expanding the expandable tubular, the drive unit disposed rearward of the expansion member; front and rear anchors disposed on the support member for engaging the expandable tubular' s ID to provide reaction forces to propagate the expansion member through the expandable tubular, the rear anchor positioned behind the drive unit and providing its reaction force after the front anchor has exited the expandable tub
  • Well intervention operations may proceed via coiled tubing or drill pipe, provided the surface arrangement includes a hydraulic workover unit.
  • the method may be used for interventions such as, but not limited to, open-hole clads, sidetracking, and cased-hole patches.
  • expandable tubular refers to metallic tubulars having the metallurgical compositions and physical properties described more fully herein.
  • FIG. 1 is a schematic side elevation view of one system embodiment within the present disclosure
  • FIG. 2 is a cross-sectional view of a cased vertical wellbore, and a non- cased lateral wellbore branching off the cased wellbore, illustrating certain features of apparatus, systems, and methods of this disclosure;
  • FIG. 3 is a side elevation schematic similar to FIG. 1 illustrating a specific system within the present disclosure
  • FIG. 4 is a cross-sectional view of one embodiment of a fishing tool that may be used in conjunction with an embodiment of the present disclosure
  • FIGS. 5 and 6 illustrate logic diagrams of certain aspects of a method within this disclosure
  • FIGS. 7 A, 7B, and 7C illustrate schematic longitudinal cross sectional views of a valve with a piston in the outer body of the valve in a first position, a second position, and a third position, respectively;
  • FIG. 8 is a photographic representation of an improved upper anchor subsystem used in a trial test.
  • FIG. 1-8 The primary features of the systems, methods and apparatus of the present disclosure will now be described with reference to FIGS. 1-8, in conjunction with some of the operational details.
  • the same reference numerals are used throughout to denote the same items in the figures.
  • FIG. 1-8 In accordance with the present disclosure, as illustrated in FIG.
  • a first embodiment 100 of a system for radially expanding a tubular member is illustrated in side elevation view, and includes an expandable tubular 2 (illustrated in pre-expanded state) having a rearward end 2 A, a forward end 2B, and defining an internal diameter (ID) 3; a support member 4, which may be a tubular member, and defines one or more internal fluid passages (not shown in this view); a conveyance member 6, which may be coiled tubing or drill pipe; a filter 8, a rear anchor 10 having one or more engagement means 24 for engaging the ID of expandable tubular 2; a drive unit 12; an expansion member 14, which may be conical as illustrated or another functional shape, such as spherical; a casing lock 16 having a plurality of engagement means 28 thereon for engaging the ID of expandable tubular 2; a front anchor 18 having a plurality of engagement means 26 for engaging the ID of expandable tubular 2; an optional flow valve 20 having a plurality of flow ports 21, which in certain embodiments may be replaced
  • expandable tubular means metallic tubulars having the metallurgy such as detailed in Table 1, from United States published patent application number 2008/0257542, published October 23, 2008, and incorporated herein by reference in its entirety. Note that the term “liner” is sometimes used herein, and those of skill in this art will understand this term is shorthand for "expandable tubular.” As reported in the '542 application, in one embodiment, a sample of an expandable tubular member composed of steel Alloy A exhibited a yield point before radial expansion and plastic deformation YP BE , of about 16%, and a yield point after radial expansion and plastic deformation, YP AE , of about 24%.
  • the ductility of the sample of the expandable tubular member composed of Alloy A also exhibited a higher ductility prior to radial expansion and plastic deformation than after radial expansion and plastic deformation.
  • Many other physical properties of steel Alloys A, B, C, and D such as tensile strength before and after expansion, anisotropy, strain hardening exponent, carbon equivalent value, and the like, are disclosed in great detail in the '542 published application.
  • drive unit 12 provides the necessary force for propelling expansion member 14 through expandable tubular 2 and expanding it.
  • Front anchor 18 engages expandable tubular 2 ID to provide the necessary reaction force to propagate expansion member 14 through expandable tubular 2.
  • Rear anchor 10 provides a reaction force during the last few strokes after front anchor 18 has exited expandable tubular 2 and can no longer provide reaction force.
  • Casing lock 16 secures expandable tubular 2 to support member 4 during Running-In-Hole (RIH).
  • Flow valve 20 at the forward end of support member 4 provides the ability for circulation during RIH. After deploying to a desired location, the flow rate may be increased to a level higher than circulation flow rate and then reduced to zero for permanent valve closure thus sealing the support member.
  • flow valve 20 may be replaced with an end cap.
  • Flow valve 22 at the forward end of expandable tubular 2 helps tool run-in and prevents packing of expandable tubular 2 with debris. It also diverts the flow of drilling fluid around the borehole thus cleaning and carrying debris through the annulus to surface.
  • Fluid filter 8 at the rearward end (top) of the tool prevents large mud particles from reaching the tool seals and inner mechanisms.
  • FIG. 7A illustrates a schematic longitudinal cross-sectional view of one embodiment of flow valve 22 in an open position (first position).
  • valve 22 includes an outer body 41 having an upper portion 45 and a lower portion 44.
  • Upper and lower portions 45, 44 are joined together by a threaded joint (not shown), and a piston 51 slidably disposed in an inner cavity 43 formed inside the outer body 41.
  • Upper portion 45 includes one end 58 with threads 46 to mate with the corresponding forward end 2B of expandable tubular 2.
  • Lower portion 44 includes a support flange 62 with flange fluid passage 50, which allows fluid flow in and out from inner cavity 43.
  • Outer body 41 also includes one or more fluid passage exits 49 to allow fluid flow out from inner cavity 43.
  • piston 51 is a cylindrical member having a piston inner cavity 52 and one or more piston fluid passages 54 to allow fluid flow from piston inner cavity 52 to fluid passage exits 49. It is to be understood that piston 51 is not limited to the embodiment illustrated in FIG. 7A but instead may include other embodiments having configurations suitable for slidable disposition in inner cavity 43.
  • a flow restriction member 55 is disposed inside piston inner cavity 52.
  • Flow restriction member 55 may be a nozzle, an orifice, or any other flow restriction member that may be sized to provide a certain force at a given flow rate.
  • a shear member 61 is disposed in lower portion 44 and engaged in groove 56.
  • Shear member 61 may be a set screw, a shear pin, a shear ring, or other shear member capable of controlling the position of piston 51 relative to the outer body 41 in the longitudinal direction.
  • shear member 61 is designed to allow for release of piston 51 at a certain selected force applied to piston 51 in the longitudinal direction and then to allow unconstrained movement of piston 51 inside outer body 41.
  • the combination of the size of flow restriction member 55 and the size of shear member 61 may be selected to allow release of piston 51 relative to outer body 41 at a selected flow rate of operational fluid.
  • a bias member 48 is disposed in inner cavity 43 of outer body 41.
  • bias member 48 is disposed in inner cavity 43 of lower portion 44.
  • Bias member 48 may be a spring (i.e., such as a coil spring), an elastomeric member, a solenoid operated piston, or other member capable of applying a longitudinal force to piston 51.
  • Bias member 48 engages piston 51 on one end 63 and the outer body 41 on the other end 64.
  • bias member 48 engages the lower portion 44 on the other end 64.
  • bias member 48 is adapted to bias piston 51 in an upward position.
  • a position control member 53 is disposed in groove 60.
  • Position control member 53 may be a C-ring, a collet, or other position control member capable of locking piston 51 in outer body 41 thereby preventing longitudinal movement of piston 51 relative to outer body 41.
  • position control member 53 engages valve body groove 42 and permanently locks piston 51 against outer body 41.
  • position control member 53 is adapted to lock piston 51 in a position preventing longitudinal movement of piston 51 in outer body 41.
  • FIG. 7A also illustrates a sealing member 57 disposed in a sealing groove 59 located adjacent to piston fluid passages 54.
  • Sealing member 57 may be an elastomeric O-ring or any other hydraulic piston seal capable of providing a hydraulic seal between piston 51 and outer body 41.
  • valve 22 is in the first open position as illustrated in the embodiment of FIG. 7A and operational fluid is pumped through valve 22 at a selected circulation flow rate.
  • the selected circulation flow rate is referred to as the first flow rate.
  • the operational fluid passes through flow restriction member 55, piston fluid passage 54, and fluid passage exit 49 out into the wellbore to wash debris away from valve 22 and into the wellbore annulus.
  • the fluid flow creates a pressure drop through the flow restriction member 55, which results in a force urging the piston 51 toward lower portion 44.
  • the shear member 61 exerts a counterforce that maintains the piston 51 in the first position maintaining alignment of piston fluid passages 54 and fluid passage exits 49, thereby allowing flow of the fluid out of the valve 22.
  • size of flow restriction member 55 and size of shear member 61 are selected to maintain piston 51 in a first position with one or more piston fluid passages 54 and one or more fluid passage exits 49 aligned at flow rates below or about equal to the first flow rate.
  • the fluid flow rate is increased to a second flow rate.
  • the second flow rate develops increased pressure drop in the flow restriction member 55, which results in a force sufficient to shear the shear member 61 thereby releasing the piston 51 and allowing its longitudinal movement inside the outer body 41.
  • piston 51 moves toward the support flange 62 into the second position, thereby compressing the bias member 48.
  • piston fluid passage 54 and fluid passage exit 49 remain aligned, allowing fluid flow through the valve 22, and, therefore, the valve 22 remains open at a second flow rate.
  • the fluid flow rate is gradually decreased to about zero or near zero allowing the bias member 48 to move piston 51 backwards to the third position, as illustrated in FIG. 7C.
  • flow restriction member 55, shear member 61, and bias member 48 are selected such that at a flow rate equal to about the second flow rate, shear member 61 releases piston 51 and piston 51 moves longitudinally inside outer body 41 to a second position with one or more piston fluid passages 54 and one or more fluid passage exits 49 aligned in the second position.
  • bias member 48 is selected to generate a minimal force sufficient for the longitudinal displacement of piston 51 in outer body 41.
  • the displacement of piston 51 to the third position occurs only during very low pressure drop in flow restriction member 55, and, therefore, valve 22 closure takes place at near zero fluid flow rates, practically eliminating the pressure surge.
  • Certain embodiments of systems, methods and apparatus of this disclosure allow installation and expansion of 3-1/2 inch (8.9cm)-OD expandable tubular 2 into an open hole through a 4-1/2 inch (11.4cm)-0D base casing.
  • the following paragraphs discuss procedures for tubular/tool system make-up, deployment, tubular expansion, and system retrieval, and additionally discuss system performance and specifications along with contingency mitigation procedures.
  • Systems of this disclosure may be used in many applications, especially those in which the pre-expanded launchers of standard, bottom-up hydraulic systems cannot pass through wellbore restrictions. Possible applications include open-hole clads, sidetracking, cased-hole patches, and the like.
  • Systems of this disclosure, including the expansion tool and expandable tubular can be deployed downhole either on drill pipe (DP) or on coiled tubing (CT), through which the operational fluid (mud) is transmitted to the tool.
  • DP drill pipe
  • CT coiled tubing
  • the tool is positioned above the expandable tubular, and expansion takes place in top-down mode.
  • the tool can be disconnected from the tubular, retrieved, repaired or replaced with a spare tool, and redeployed in the well.
  • One complete expansion process cycle comprises, as its primary steps, an expansion step or stroke, where the expansion member moves axially to radially expand the expandable tubular, and a resetting stroke, where one or both anchors is moved axially within the pre-expanded expandable tubular, except in the last few strokes, where the rear anchor moves axially within an expanded section of expandable tubular.
  • Each expansion stroke involves the application of pressure to the tool and release of pressure at the end of the stroke.
  • Each resetting stroke involves lowering the tool through the DP or CT.
  • System operating specifications may be as shown in Table 2, while Table 3 provides some emergency pressure levels and related events.
  • a vertical base casing 29 (for example, a 4-1/2 inch (11.4cm) base casing) has already been installed and cemented in a vertical wellbore, and a liner 30 and deflector or whipstock 31 installed.
  • a forklift and crane may optionally be used to move the tool into position and attach it to CT or DP as the case may be.
  • slips or dog collars for 3-1/2 inch (11.4cm) OD pipe and 3.70 inch (9.4cm) OD tool may be used.
  • the slips and dog collars would be sized accordingly.
  • a mouse hole (not shown in FIG. 2) would be drilled near the main wellbore for insertion of a positioning tool and shroud to assure the tool remains vertical.
  • the mouse hole may have an ID of 6 inches (15.2cm) minimum, and a depth of 40 ft (12.2m) minimum.
  • a window 34 is milled, having a minimum window length, w, of 3.81 inches (9.68cm).
  • the build section, 36 may have a minimum ID of 4.75 inch (12.07cm).
  • the Dog-Leg Severity (DLS) in this embodiment is 457100ft (45730.5m), which is near the maximum for systems and apparatus of this disclosure.
  • the length of the dog leg rat hole, r is calculated based primarily on the length of dimension "e" in FIG. 2, defined as the distance between the bottom of window 34 to bottom of the unstable shale section.
  • equipment such as a weight indicator, a pressure monitoring system, a depth measuring device, a pop-off valve, and the mud pumps may be used.
  • equipment such as a weight indicator, a pressure monitoring system, a depth measuring device, a pop-off valve, and the mud pumps may be used.
  • FIG. 2 illustrates one system set up in accordance with this disclosure right on the onset of expansion, with the expansion member 14 below the lower edge of milled window 34.
  • the operator must be aware of the distance "e” between the bottom of the window (BOW) to the bottom of the shale, or equivalently, the minimum 'true measured depth' of where the expandable tubular must sit after expansion minus the depth of the bottom of the milled window.
  • the parameters in FIG. 2 are as follows:
  • R downhole rathole
  • w Window length. [0062] After the distance "e” is determined, Table 4 is used to determine the downhole rathole length "R” needed after the shale is exited. "L” corresponds to the total length of expandable tubular (liner) before expansion. During drilling of the bend, once shale is exited, drilling must continue until a rathole "R" is completed.
  • FIGS. 1, 2 and 3 An operational procedure for making up the embodiment illustrated in FIGS. 1, 2 and 3 may be as follows, and is also illustrated as a process logic diagram in FIG. 5.
  • this embodiment 500 at the surface, tubular bundles are unloaded from trucks using slings to prevent scratching and banging of tubulars (box 502).
  • a rated sling may then be wrapped around the collar of the tool shroud (box 506).
  • the combined weight of tool plus shroud is less than 2,100 lbf (9.3 knewtons). Lift the shroud with tool vertical and insert in surface rat hole. Leave there until tool is ready to be deployed (box 508).
  • the make-up may proceed as follows. Lift the 46-foot (14m)-long tool out of protective shroud, remove the pin thread protector on tubular. Position the lower end of the tool above the box of the tubular inserted in well. Lower expansion tool and complete the following checks: (1) check for damage or wear on the welded strips on pipe next to the expansion member; (2) check the distance of exposed shaft between the rear anchor and drive unit (this should be no more than 1/2 in (1.3cm)); (3) check if rear shear screw is fully screwed into rear anchor; (4) check if all rear anchor bows are in place and with two socket screws fully screwed per bow; (5) check if rear anchor pads are retracted.
  • the tool string is set so that the expansion member (cone) is a distance of about 5 ft (1.5m) below the bottom of the window (see FIG. 2).
  • the distance between the expansion member (cone) and the end of the fluid filter (end of tool) is about 33 ft (10m).
  • Expansion of the expandable tubular or liner may proceed according to the following non-limiting procedure, as illustrated in FIG. 6.
  • Set the surface pop-off valve at 3500 psi (24 MPa) (box 602).
  • Pressure will start increasing while the following sequence of events takes place (box 604).
  • Drive unit shear disk breaks at 900 psi (6 MPa) (box 606).
  • Rear anchor shear screw breaks at 1800 psi (12 MPa) (box 608).
  • the expansion pressure during the first stroke should be within the 2,200-2,800 psi (15-19 MPa) range (box 610). This is larger than the uniform expansion pressure due to the anchoring mechanism during the first stroke.
  • Pressure should come up to steady expansion pressure of approximately 2,200 psi (15 MPa) for the length of the stroke. At the end of the stroke pressure will rise which will again trigger the pop-off valve (box 616). Continue repeating these steps until all the expandable tubular length has expanded. Monitor the length of expanded tubular by the length of the lowered DP or CT, accounting for the tubular shrinkage due to expansion. Also, monitor the number of expanded connectors by their pressure variation signature (box 618). Use Expansion Job Sheet. In the second to last resetting stroke, the expansion tool should remove valve 22 from the expandable tubular. This requires approximately 500 lbf (22 knewtons), which should be seen on the weight indicator.
  • Retrieval of the expansion tool may proceed according to the following non-limiting procedure. After completing expansion, pull the DP or CT all the way out through the expanded pipe, open hole and production casing.
  • the load to pop the expansion member off the mouth of the expanded liner should be no greater than 13,000-15,000 lb f (56-65 knewtons). This should be seen as an equivalent increase in the weight indicator.
  • stop pulling increase pressure to 4,500 psi (31 MPa) to shear the rear anchor for permanent closure.
  • Continue pulling the string out. Clamp the tool on well head through the fluid filter.
  • the risk assessment table contains a non-limiting list of 14 possible scenarios that could decrease the degree of success of a specific expansion job in different degrees.
  • the legend used to quantify each risk was as follows:
  • the semi- expanded liner would have to be fished out of the well.
  • a fishing mechanism could engage either on the pre- or post- expanded ID of the expandable tubular. In one embodiment their dimensions are as follows:
  • FIG. 4 A fishing tool that might be used in the above example if the expansion tool is lost in the well is illustrated in cross-section in FIG. 4, which contains all the dimensions of the connection on which breakage may occur.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)
  • Piles And Underground Anchors (AREA)

Abstract

L'invention porte sur des systèmes, un appareil et des procédés d'intervention dans un puits. Un appareil d'expansion radiale d'élément tubulaire comprend un élément de support ayant des extrémités avant et arrière; une unité d'entraînement et un élément d'expansion disposés sur l'élément de support fournissant une force pour propulser l'élément d'expansion à travers un tubulaire expansible et pour l'agrandir, l'unité d'entraînement étant disposée à l'arrière de l'élément d'expansion; des ancres avant et arrière disposées sur l'élément de support pour entrer en position avec le diamètre interne du tubulaire expansible pour fournir des forces de réaction pour propulser l'élément d'expansion à travers le tubulaire expansible, l'ancre arrière étant positionnée derrière l'unité d'entraînement et fournissant sa force de réaction après que l'ancre avant est sortie du tubulaire expansible; un verrou de boîtier disposé sur l'élément de support et positionné entre l'élément d'expansion et l'ancre avant, fixant le tubulaire expansible à l'élément du support pendant un parcours dans un trou (RIH); et une soupape fixée à l'extrémité avant du tubulaire expansible.
PCT/US2009/066349 2008-12-02 2009-12-02 Systèmes d'installation tubulaire expansibles, procédés et appareils WO2010065597A2 (fr)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US11922708P 2008-12-02 2008-12-02
US61/119,227 2008-12-02
US12/628,925 US20100132958A1 (en) 2008-12-02 2009-12-01 Expandable tubular installation systems, methods, and apparatus
US12/628,925 2009-12-01

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WO2010065597A2 true WO2010065597A2 (fr) 2010-06-10
WO2010065597A3 WO2010065597A3 (fr) 2010-08-26

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CN104499977B (zh) * 2014-12-31 2018-07-03 北方斯伦贝谢油田技术（西安）有限公司 一种水平井套管整形修复方法及装置
CN105840154B (zh) * 2016-04-19 2018-09-18 陕西汇丰悦石油科技开发有限公司 一种新型卡瓦式井下节流器
CN105863611B (zh) * 2016-06-18 2018-09-14 东北石油大学 一种多井型多相环空携屑模拟装置
CN110716305B (zh) * 2019-10-28 2022-01-18 长春理工大学 仿生复眼的六边形子眼拼接定位方法
CN110984924B (zh) * 2019-12-20 2021-08-24 新疆恒智伟业石油工程技术开发有限公司 一种易钻磨裸眼完井管柱施工方法
CA3219972A1 (fr) * 2021-05-24 2022-12-01 Joel Eugene ADAMS Colonne montante dilatable exempte de coulis
CN117266776B (zh) * 2023-11-14 2024-01-30 东营市恒信机械有限责任公司 一种井下套管液压双向膨胀整形装置

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