+

US20030075337A1 - Method of expanding a tubular member in a wellbore - Google Patents

Method of expanding a tubular member in a wellbore Download PDF

Info

Publication number
US20030075337A1
US20030075337A1 US10/003,968 US396801A US2003075337A1 US 20030075337 A1 US20030075337 A1 US 20030075337A1 US 396801 A US396801 A US 396801A US 2003075337 A1 US2003075337 A1 US 2003075337A1
Authority
US
United States
Prior art keywords
tubular
expanding
string
wellbore
casing
Prior art date
Legal status (The legal status 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 status listed.)
Abandoned
Application number
US10/003,968
Other languages
English (en)
Inventor
Patrick Maguire
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Weatherford Lamb Inc
Original Assignee
Weatherford Lamb Inc
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 Weatherford Lamb Inc filed Critical Weatherford Lamb Inc
Priority to US10/003,968 priority Critical patent/US20030075337A1/en
Assigned to WEATHERFORD/LAMB, INC. reassignment WEATHERFORD/LAMB, INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: MAGUIRE, PATRICK G.
Priority to PCT/GB2002/004571 priority patent/WO2003036026A1/fr
Publication of US20030075337A1 publication Critical patent/US20030075337A1/en
Abandoned legal-status Critical Current

Links

Images

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
    • E21B43/105—Expanding tools specially adapted therefor

Definitions

  • the present invention relates to methods for wellbore completions. More particularly, the invention relates to completing a wellbore by expanding tubulars therein. More particularly still, the invention relates to the expansion of a tubular within a wellbore through the use of compressive forces.
  • Hydrocarbon and other wells are completed by forming a borehole in the earth and then lining the borehole with steel pipe or casing to form a wellbore. After a section of wellbore is formed by drilling, a section of casing is lowered into the wellbore and temporarily hung therein from the surface of the well. Using apparatus known in the art, the casing is cemented into the wellbore by circulating cement into the annular area defined between the outer wall of the casing and the borehole. The combination of cement and casing strengthens the wellbore and facilitates the isolation of certain areas of the formation behind the casing for the production of hydrocarbons.
  • a first string of casing is set in the wellbore when the well is drilled to a first designated depth.
  • the first string of casing is hung from the surface, and then cement is circulated into the annulus behind the casing.
  • the well is then drilled to a second designated depth, and a second string of casing, or liner, is run into the well.
  • the second string is set at a depth such that the upper portion of the second string of casing overlaps the lower portion of the first string of casing.
  • the second liner string is then fixed or “hung” off of the existing casing by the use of slips which utilize slip members and cones to wedgingly fix the new string of liner in the wellbore.
  • the second casing string is then cemented. This process is typically repeated with additional casing strings until the well has been drilled to total depth. In this manner, wells are typically formed with two or more strings of casing of an ever decreasing diameter.
  • the apparatus typically includes expander tools which are fluid powered and are run into the wellbore on a working string.
  • the hydraulic expander tools include radially expandable members which, through fluid pressure, are urged outward radially from the body of the expander tool and into contact with a tubular therearound.
  • the tubular being acted upon by the expansion tool is expanded past its point of plastic deformation. In this manner, the inner and outer diameter of the tubular is increased in the wellbore.
  • an intermediate string of casing can be hung off of a string of surface casing by expanding a portion of the intermediate string into frictional contact with the lower portion of surface casing therearound. This allows for the hanging of a string of casing without the need for a separate slip assembly.
  • Additional applications for the expansion of downhole tubulars exist. These include the use of an expandable sand screen, employment of an expandable seat for seating a diverter tool, and the use of an expandable seat for setting a packer.
  • Another problem encountered pertains to a change in wall thickness which results from the expansion of a tubular, regardless of the type of expander employed. It has been discovered that the expansion process results in a reduction in wall thickness of that portion of casing or other tubular being expanded. As the wall begins to thin, the amount of force needed to expand that portion of tubular decreases. The roller or other expander member tends to push the tubular material out radially at the expense of the material on the flanks of the roller. The tubular material in the flank region essentially acts as a sacrificial zone for the expansion process as it provides the bulk of the material for the expansion process.
  • the present invention provides methods for expanding a tubular within a wellbore.
  • the tubular to be expanded is run into a wellbore on a working string.
  • the tubular is supported by a collet or other carrying mechanism at the lower end of the working string.
  • the expander tool is a rotary expander tool, meaning it is rotated by rotating the working string or, perhaps, a rotary mud motor.
  • the expander tool employs a series of rollers which are actuated by hydraulic pressure.
  • the expander tool has a hollow bore in fluid communication with a series of rollers. Injection of fluid under pressure into the working string causes the rollers to move outwardly from the body of the expander tool, and to apply an outward force against the inner surface of the expandable tubular.
  • a hydraulically actuated ram Above the expander tool, and also in series with the working string, is a hydraulically actuated ram.
  • the ram is positioned on top of the tubular to be expanded, such as a lower string of casing, or liner.
  • the ram has a mandrel which serves as a tubular for transporting fluids from the working string downward to the expander tool.
  • the ram further has a body surrounding the mandrel. An annulus is thus defined between the mandrel and the body.
  • Seals are circumferentially fitted between the mandrel and an inner surface of the body in order to seal the annulus.
  • the diameter of the annulus is greater at the location of the upper seal than at the location of the lower seal. Thus, a difference in cross-sectional area is provided within the sealed annulus. Because the lower casing string 140 is held in place by the carrying mechanism 150 , a compressive force is applied to the lower casing string 140 along the portion designated for expansion.
  • a through-opening is placed in the mandrel between the upper seal and the lower seal.
  • the through-opening allows fluid to flow down the working string, through the mandrel, and into the annulus.
  • the annulus is sealed above and below the through-opening by the upper and lower seals.
  • fluid under pressure is injected into an annular region defined by the body, the mandrel, and the upper and lower seals.
  • the application of pressure in the annulus acts on the net hydraulic area between the upper and lower seals to create a downward force.
  • the result is that fluid injected into the annulus applies a force downward against the expandable tubular.
  • the expandable tubular is supported and held in place within the wellbore by the carrying mechanism at the lower end of the working string.
  • a compressive force is exerted onto that portion of the tubular to be expanded.
  • the expander tool is actuated against the inner surface of the expandable tubular.
  • the expandable tubular is a portion of a string of casing, or liner.
  • the expander tool acts against the lower string of casing, causing the lower string of casing to be expanded radially into a surrounding string of casing.
  • the application of compressive force serves to assist in the expansion process, meaning that less radial force is needed in order to achieve a sufficient frictional engagement between the two strings of casing. Further, a more uniform wall thickness and expansion job is achieved.
  • a bias is machined into that portion of a tubular to be expanded.
  • the tubular could be pre-stressed outwardly into a barrel configuration. This would cause the tubular to more readily buckle outwardly upon application of an expansive force from within the expandable tubular, thus aiding the expander rollers. This process, in turn, would further alleviate the thinning effect which would otherwise occur on the flanks of the expander members.
  • the ultimate benefit is a stronger transition zone that will carry more weight axially and also enjoy stronger resistance to collapse.
  • FIG. 1 is a cross-sectional view of a wellbore having an upper string of casing.
  • a lower string of casing has been run into the wellbore on a working string.
  • an expander tool for expanding the lower string of casing at the desired depth in the wellbore, and a hydraulic ram for applying a compressive load onto the lower string of casing during the expansion process.
  • FIG. 2 is an exploded view of a rotary expander tool as might be used in the methods of the present invention.
  • FIG. 3 is an enlarged sectional view of a hydraulic ram as might be used to apply a compressive load onto an expandable tubular during the expansion process.
  • FIG. 4 is a sectional view of a wellbore having an upper string of casing, and showing a lower string of casing being expanded into frictional contact with the upper string of casing. In this view, a compressive load is being applied to the lower string of casing. Further, the rollers of the expander tool are being activated and rotated.
  • FIG. 5 is a sectional view of the wellbore of FIG. 4, showing the portion of expandable tubular in complete, frictional communication with the upper string of casing. The working string and associated tools are being removed from the wellbore.
  • FIG. 6 is a partial section view of the wellbore of FIG. 5, illustrating the upper section of the lower casing string expanded into the upper casing string after the expander tool and run-in string have been removed. This view more fully illustrates the portion of the lower string of casing, including optional slip and sealing members, having been expanded into the upper string of casing therearound.
  • FIG. 7 is a cross-sectional view of a wellbore illustrating an alternate means for assisting in the expansion of a tubular. Visible in this view is a barrel-shaped configuration for a portion of the expandable tubular where expansion is to begin.
  • FIG. 1 is a cross-sectional view of a wellbore 100 having an upper string of casing 110 disposed therein.
  • the upper string of casing 110 has been set within the wellbore 100 through a cementing process.
  • the cement layer is visible in the annulus 120 , defined by the upper string of casing 110 and the surrounding formation 130 .
  • FIG. 1 Visible also in FIG. 1 is a working string 200 .
  • the working string 200 is a tubular such as drill pipe having a hollow bore therein.
  • the working string 200 is used to run various tools into the wellbore 100 during the completion process, as well as to inject fluids such as cement as needed.
  • the working string 200 is also used to run in a lower string of casing 140 into the wellbore 100 .
  • the lower string of casing 140 is supported on the working string 200 by a carrying mechanism 150 .
  • the carrying mechanism 150 may be a threaded connection, a fluid actuated connection, or other known carrying device.
  • an expandable collet is used as the carrying mechanism 150 .
  • the collet 150 is landed into a radial profile 155 within the lower string of casing 140 so as to support the lower string of casing 140 .
  • the collet 150 is hydraulically or mechanically actuated as is known in the art, and supports the lower string of casing 140 until such time as the lower string of casing 140 has been expandably set by actuation of the expander tool 300 .
  • the swivel 160 allows the working string 200 to rotate within the wellbore 100 without upsetting the connection between the expandable tubular 140 and the working string 200 . As will be shown, the working string 200 must rotate within the wellbore 100 so that it may rotate the expander tool 300 , thereby radially expanding the lower string of casing 140 or other expandable tubular at the desired depth in the wellbore 100 .
  • the swivel 160 allows the body 350 of the expander tool 300 to be rotated by the working tubular 200 while the carrying mechanism 150 remains stationary.
  • the expander tool 300 is a rotary expander tool. This means that the desired expansion is accomplished by rotating expanded rollers 365 against the inner surface of the expandable tubular 140 . Preferably, rotation of the expander tool 300 is imparted by rotating the working string 200 . However, rotation may also be imparted by a downhole mud-type motor (not shown).
  • FIG. 2 is an exploded view of an exemplary expander tool 300 .
  • the expander tool 300 consists of a cylindrical body 350 having a plurality of windows 355 formed therearound. Within each window 355 is an expansion assembly 360 which includes a roller 365 disposed on an axle 370 which is supported at each end by a piston 375 . The piston 375 is optionally retained in the body 350 by a pair of retention members 372 that are held in place by screws 374 .
  • the assembly 360 includes a piston surface 380 formed opposite the piston 375 which is acted upon by pressurized fluid in the bore 390 of the expander tool 300 . The pressurized fluid causes the expansion assembly 360 to extend radially outward and into contact with the inner surface of the lower string of casing 140 . With a predetermined amount of fluid pressure acting on the piston surface 380 of piston 375 , the lower string of casing 140 is expanded past its elastic limits and into plastic deformation.
  • the expander tool 300 shown in FIG. 2 is intended to serve only as an example. Various other embodiments of rotary expander tools exist. It is within the scope of the present invention to utilize any type of rotary expander tool to accomplish the methods of the present invention. However, it is preferred that an expander tool 300 having multiple rows of rollers 365 be used, allowing for a greater length of tubular expansion while the tubular 140 is under compression.
  • the wellbore 100 of FIG. 1 includes a compressive force apparatus 400 .
  • the compressive force apparatus 400 is disposed in the wellbore 100 above the expander tool 300 , and serves to apply a force downward on the top of the lower string of casing 140 .
  • FIG. 3 presents an enlarged sectional view of a hydraulically actuated ram 400 as might be used to apply a compressive load onto the lower string of casing 140 during the expansion process.
  • the ram 400 first comprises an inner mandrel 420 .
  • the mandrel 420 is generally tubular such that it defines a hollow bore 422 therein.
  • the mandrel 420 has a top end 425 which is threadedly connected to the working string 200 .
  • the mandrel 420 also has a bottom end 430 which is in fluid communication with the expander tool 300 (shown in FIG. 1).
  • the bottom end 430 is threadedly connected to a make-up joint 320 , which itself is connected to the expander tool 300 .
  • the mandrel 420 creates a hollow bore 422 , placing the ram 400 in fluid communication with the bore 210 of the working string 200 and the bore 390 (FIG. 2) of the expander tool 300 .
  • the ram 400 also comprises a body 450 surrounding the mandrel 420 .
  • the body 450 has a top surface 412 , a bottom surface 414 , and an inner surface 415 therebetween facing the mandrel 420 .
  • An annular region 470 is left between the outer body 450 and the mandrel 420 .
  • fluid is injected from the surface into the annulus 470 .
  • at least one through-opening 435 is fabricated into the mandrel 420 of the hydraulic ram 400 . Fluid can then travel from the hollow bore 210 of the working string 200 , through the bore 422 defined within the mandrel 420 , and into the annulus 470 .
  • the annulus 470 is configured such that the cross-sectional area of fluid above the through-opening 435 is greater than the cross-sectional area of fluid below the through-opening 435 .
  • the annulus 470 is sealed by the use of an upper seal ring 440 and a lower seal ring 445 . Both the upper seal 440 the lower seal 445 are disposed circumferentially around the tubular mandrel 420 .
  • the through-opening 435 resides between the upper and lower seals 440 , 445 , allowing fluid to be injected under pressure into the annulus 470 .
  • Pressure injected into the annulus 470 acts on the net hydraulic area between seals 440 and 445 to create a downward force. This downward force causes the ram 400 to apply a force downward on the expandable tubular 140 below.
  • the body 450 of the ram 400 is configured to have an outer surface 410 and an inner surface 415 .
  • the inner surface 415 is tapered such that the diameter of the inner surface at an upper end 412 is greater than the diameter of the inner surface at the bottom 414 . This creates the desired surface area differential between the seals 440 and 445 when pressure is injected into the annulus.
  • the ram 400 in FIG. 3 includes an optional shoulder area 426 along the mandrel 420 .
  • the seals are circumferentially fitted between the mandrel 420 and the inner surface 415 of the body 450 in order to seal the annulus 470 so as to hold injected fluid. Again, this pressure creates a downward force that in turn causes the ram 400 to apply a force downward on the expandable tubular 140 .
  • the body 450 of the ram 400 is a separate body from the mandrel 420 . This is necessary in order to allow a downward movement of the body 450 relative to the mandrel 420 when the ram 400 is actuated.
  • the lower seal ring 445 travels with the body 450 during actuation, while the upper seal ring 440 is affixed external to the mandrel 420 and does not travel. With this arrangement, sufficient distance is provided in the design between the upper seal ring 440 and the top end 412 of the body 450 to accommodate the stroke of the body 450 downward without losing hydraulic integrity.
  • An optional feature for the hydraulic ram 400 in FIG. 3 is the use of shearable screws 460 .
  • One or more shearable screws 460 maintain the position of the outer body 450 relative to the mandrel 420 of the ram 400 during run-in. In this way, shearable screws 460 serve to prevent premature actuation of the ram 400 , and also support the body 450 during run-in.
  • At least one shearable screw 460 is optionally run through the mandrel 420 and the body 450 . When additional pressure is injected so as to actuate the ram 400 , the screws 460 are sheared, allowing the body 450 to move downwardly against the lower string of casing 140 .
  • fluid is injected into bore 210 of the working string 200 under pressure. From there, fluid travels into the bore 422 of the mandrel 420 where it encounters the through-opening 435 .
  • the through-opening 435 permits fluid to flow into the annulus 470 of the ram 400 , still under pressure.
  • the application of pressure in the annulus 470 acts on the net hydraulic area between seals 440 and 445 to create a downward force on the lower string of casing 140 . Because the lower casing string 140 is held in place by the carrying mechanism 150 , a compressive force is applied to the lower casing string 140 along the portion designated for expansion.
  • the embodiment for a hydraulic ram 400 of FIG. 3 is only an example, and is not to scale.
  • the scope of the present invention includes the use of any hydraulic ram which creates a difference in cross-sectional area for receiving an application of hydraulic pressure, thereby accomplishing a movement or relative motion between two parts.
  • the embodiment for a compressive force apparatus 400 of FIG. 3 is only an example such that it is within the scope of the present invention to utilize any compressive force apparatus 400 which applies a compressive force onto a portion of expandable tubular, with the force being directed opposite a carrying mechanism 150 .
  • the present invention is not limited to the use of a compressive force apparatus which is on top of the expandable tubular.
  • a compressive force apparatus could be disposed below an expandable tubular, with an upward force being applied therefrom.
  • the portion of tubular to be expanded would be above the compressive force apparatus, and below the carrying mechanism.
  • FIG. 4 presents a sectional view of the wellbore 100 of FIG. 1, having the upper string of casing 110 in place, and showing the lower string of casing 140 being expanded into frictional contact with the upper string of casing 110 .
  • a compressive load is being applied to the lower string of casing 140 by virtue of hydraulic pressure being injected into the ram annulus 470 , as described above.
  • the rollers 365 of the expander tool 300 are being activated.
  • the same hydraulic pressure which activates the compressive force apparatus 400 is also used to activate the rollers 365 , as described above in connection with FIG. 2.
  • the expander tool 300 is also being rotated. Rotation is accomplished by rotating the working string 200 .
  • a sleeve must be able to rotate through the ram 400 .
  • the mandrel 420 of the hydraulic ram 400 serves as the sleeve. This means that the working string 200 rotates the mandrel 420 of the hydraulic ram 400 , which in turn rotates the expander tool 300 .
  • the compressive force apparatus 400 is designed so that the mandrel 420 is able to rotate within the upper 440 and lower 445 seal rings. Rotation of the working string 200 also assists in shearing the screws 460 .
  • a bore 390 shown in FIG. 2, runs through the expander tool 300 , placing the working string 200 and the expander tool 300 in fluid communication.
  • a fluid outlet 395 is provided at the lower end of the expander tool 300 .
  • a tubular member serves as the fluid outlet 395 .
  • the expander tool 300 By actuation of the expander tool 300 against the inner surface of the lower string of casing 140 , a portion of the lower string of casing 140 is expanded into the upper string of casing 110 . In this manner, the top portion of the lower string of casing 140 U is placed in essentially sealed fluid communication with the upper string of casing 110 .
  • the working string 200 is optionally raised from the surface after the initial expansion of the lower string of casing 140 U has taken place.
  • an apparatus may be placed downhole which translates the expander tool 300 within the wellbore 100 without pulling the working string 200 . Hydraulic pressure continues to be provided to the expander tool 300 while the working string 200 is raised.
  • connection between the carrying mechanism 150 and the lower string of casing 140 must be released.
  • the collet 150 has been released from the profile 155 .
  • Such release mechanisms are known in the art.
  • FIG. 5 is a sectional view of the wellbore of FIG. 4, showing the upper portion 140 U of expandable tubular 140 in complete, frictional engagement with the upper string of casing 110 .
  • the working string 200 and associated tools e.g., expander tool 300 and hydraulic ram 400 , are being removed from the wellbore 100 .
  • the expander tool 300 has been deactivated. In this regard, fluid pressure supplied to the pistons 375 is reduced or released, allowing the pistons 375 to return to the recesses 355 within the central body 350 of the tool 300 .
  • the expander tool 300 can then be withdrawn from the wellbore 100 by pulling the working string 200 .
  • FIG. 6 is a sectional view of the wellbore of FIG. 5, illustrating the upper portion 140 U of the lower casing string 140 expanded into the upper casing string 110 after the expander tool 300 and working string 200 have been removed. This view more fully illustrates the frictional engagement between the upper 110 and lower 140 strings of casing.
  • FIG. 6 demonstrates that the lower string of casing 140 has also been cemented into the wellbore 100 . Cement is shown in the annulus 500 behind the lower string of casing 140 . In the view of FIG. 6, optional slip 195 and sealing 190 members are shown disposed around the lower string of casing 140 .
  • a sealing ring 190 is shown disposed on the outer surface of the lower string of casing 140 .
  • the sealing ring 190 is an elastomeric member circumferentially fitted onto the outer surface of the casing 140 .
  • non-elastomeric sealing materials may also be used.
  • the sealing ring 190 is designed to seal an annular area 500 formed between the outer surface of the lower string of casing 140 and the inner surface of the upper string of casing 110 upon expansion of the lower string 140 into the upper string 110 .
  • the slip member 195 defines a pair of rings having grip surfaces formed thereon for engaging the inner surface of the upper string of casing 110 when the lower string of casing 140 is expanded.
  • one slip ring 195 is disposed above the sealing ring 190
  • one slip ring 195 is disposed below the sealing ring 190 .
  • the grip surface includes teeth formed on each slip ring 195 .
  • the slips could be of any shape and the grip surfaces could include any number of geometric shapes, including button-like inserts (not shown) made of high carbon material.
  • slip 195 and sealing 190 members are optional.
  • other arrangements for slip and sealing members could be employed.
  • an elastomeric sealing material could be disposed in a matrix of grooves (not shown) within the outer surface of the upper portion 140 U of the lower string of casing 140 .
  • Carbide buttons (not shown) or other gripping members could be placed between the grooves.
  • FIG. 7 is a cross-sectional view of a wellbore illustrating an alternate means for assisting in the expansion of a tubular. Visible in this view is a barrel-shaped configuration for a portion of the expandable tubular where expansion is to begin.
  • the barrel-shaped portion is identified at 140 B.
  • the barrel-shaped portion 140 B of the lower string of casing 140 is created by pre-stressing the tubular 140 before it is run into the hole 100 .
  • Pre-stressing the tubular 140 causes the tubular 140 to more readily buckle outwardly upon application of an expansive force from within the expandable tubular 140 , thus aiding the expander rollers 365 . This, in turn, further alleviates the thinning effect which would otherwise occur on the flanks of the expander members 365 .
  • the ultimate benefit is a stronger transition zone in the casing 140 U that will carry more weight axially and also enjoy stronger resistance to collapse.
  • FIG. 7 demonstrates the use of both a compressive force apparatus 400 and a barrel-shape pre-formed in the expandable tubular 140 B.
  • a compressive force apparatus 400 is optional where a pre-stressing or other bias has been applied to the expandable tubular 140 B.
  • other biasing means for more easily expanding a tubular.
  • An example would be a biasing feature or structure machined into the expandable tubular.
  • the method of the present invention in one embodiment is useful in a wellbore 100 having a first string of cemented casing 110 .
  • the wellbore 100 is drilled to a new depth so that a second string of casing, or liner, may be set. Thereafter, the drill string and drill bit are removed, and a rotary expander tool 300 is run into the wellbore 100 on a working string 200 .
  • a carrying mechanism 150 is utilized for carrying the second string of casing 140 into the hole 100 on the working string 200 .
  • the second string of casing 140 is then positioned within the wellbore 100 so that the upper portion 140 U of the second string of casing 140 overlaps with the bottom portion of the first string of casing 110 .
  • a compressive force apparatus 400 is run into the wellbore 100 .
  • the compressive force apparatus 400 defines a hydraulically actuated ram.
  • the ram 400 is positioned downhole over the top of the lower string of casing 140 .
  • Fluid is then injected into the working string 200 from the surface. Fluid enters the annulus 470 of the ram 400 , thereby causing a downward force to be applied onto the top of the lower string of casing 140 . Compression is thereby achieved between the top of the lower string of casing 140 and the point of connection between the lower string of casing 140 and the carrying mechanism 150 .
  • the application of hydraulic pressure into the wellbore 100 also activates the rotary expander tool 300 .
  • the rotary expander tool 300 applies an outward force from the inner surface of the lower string of casing 140 , bringing the outer surface of the lower string of casing 140 into frictional engagement with the inner surface of the first, or upper string of casing 110 .
  • the expander tool 300 may optionally be raised within the wellbore 100 during the expansion process so as to obtain expansion of the lower string of casing 140 along a desired length. This step would require release of the connection between the carrying mechanism 150 and the tubular 140 being expanded.
  • roller assemblies 300 could be positioned along the entire length of desired expansion.
  • the working string 200 is removed from the wellbore 100 along with the expander tool 300 and the compressive force apparatus 400 .
  • the result is in an effective hanging of the lower string of casing 140 upon the upper string of casing 110 within the wellbore 100 .
  • the method of the present invention enables a lower string of casing 140 or other expandable tubular to be more effectively hung onto an upper string of casing 110 by compressively expanding the lower string 140 into an overlapping portion of the upper string 110 .
  • a shoulder 480 is needed in order to pull the outer body 450 of the ram 400 from the hole. This is because the outer body 450 defines a separate body from the mandrel 420 of the ram 400 .
  • an enlarged collar 480 is used as the shoulder for lifting the outer body 450 from the wellbore 100 .
  • the collar 480 comes into contact with the bottom end or base 414 of the outer body 450 when the expander tool 300 is pulled.
  • an enlarged collar 480 is used as the shoulder in the preferred embodiment, it is acceptable to utilize other “no-go” arrangements.
  • the body 350 of the expander tool 300 itself could serve as a shoulder for lifting the outer body 450 .
  • a shoulder could be added to a make-up joint 320 (arrangement not shown).
  • the preferred embodiment for the method of the present invention involves the expansion of a lower string of casing into an overlapping portion of an upper string of casing.
  • Other types of expandable tubulars include, but are not limited to, expandable sand screens, expandable seats for packers or whipstocks or for other tools, and expandable production tubing.

Landscapes

  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)
US10/003,968 2001-10-24 2001-10-24 Method of expanding a tubular member in a wellbore Abandoned US20030075337A1 (en)

Priority Applications (2)

Application Number Priority Date Filing Date Title
US10/003,968 US20030075337A1 (en) 2001-10-24 2001-10-24 Method of expanding a tubular member in a wellbore
PCT/GB2002/004571 WO2003036026A1 (fr) 2001-10-24 2002-10-09 Procede permettant d'etendre un materiel tubulaire dans un puits

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
US10/003,968 US20030075337A1 (en) 2001-10-24 2001-10-24 Method of expanding a tubular member in a wellbore

Publications (1)

Publication Number Publication Date
US20030075337A1 true US20030075337A1 (en) 2003-04-24

Family

ID=21708451

Family Applications (1)

Application Number Title Priority Date Filing Date
US10/003,968 Abandoned US20030075337A1 (en) 2001-10-24 2001-10-24 Method of expanding a tubular member in a wellbore

Country Status (2)

Country Link
US (1) US20030075337A1 (fr)
WO (1) WO2003036026A1 (fr)

Cited By (59)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20030066655A1 (en) * 1999-02-26 2003-04-10 Shell Oil Co. Apparatus for coupling a tubular member to a preexisting structure
US20030121558A1 (en) * 1998-11-16 2003-07-03 Cook Robert Lance Radial expansion of tubular members
US20030146003A1 (en) * 2001-12-27 2003-08-07 Duggan Andrew Michael Bore isolation
US20040065445A1 (en) * 2001-05-15 2004-04-08 Abercrombie Simpson Neil Andrew Expanding tubing
US6739392B2 (en) 1998-12-07 2004-05-25 Shell Oil Company Forming a wellbore casing while simultaneously drilling a wellbore
US20050000697A1 (en) * 2002-07-06 2005-01-06 Abercrombie Simpson Neil Andrew Formed tubulars
US6892819B2 (en) 1998-12-07 2005-05-17 Shell Oil Company Forming a wellbore casing while simultaneously drilling a wellbore
WO2004083592A3 (fr) * 2003-03-18 2005-05-19 Eventure Global Technology Appareil et procede pour mettre en place un element tubulaire extensible radialement
US6968618B2 (en) 1999-04-26 2005-11-29 Shell Oil Company Expandable connector
US7011161B2 (en) 1998-12-07 2006-03-14 Shell Oil Company Structural support
US7021390B2 (en) 1998-12-07 2006-04-04 Shell Oil Company Tubular liner for wellbore casing
US7044218B2 (en) 1998-12-07 2006-05-16 Shell Oil Company Apparatus for radially expanding tubular members
US7055608B2 (en) 1999-03-11 2006-06-06 Shell Oil Company Forming a wellbore casing while simultaneously drilling a wellbore
US7100685B2 (en) 2000-10-02 2006-09-05 Enventure Global Technology Mono-diameter wellbore casing
US7100684B2 (en) 2000-07-28 2006-09-05 Enventure Global Technology Liner hanger with standoffs
US7147053B2 (en) 1998-12-07 2006-12-12 Shell Oil Company Wellhead
US20070000664A1 (en) * 2005-06-30 2007-01-04 Weatherford/Lamb, Inc. Axial compression enhanced tubular expansion
US7168496B2 (en) 2001-07-06 2007-01-30 Eventure Global Technology Liner hanger
US7172021B2 (en) 2000-09-18 2007-02-06 Shell Oil Company Liner hanger with sliding sleeve valve
US7172024B2 (en) 2000-10-02 2007-02-06 Shell Oil Company Mono-diameter wellbore casing
US7195064B2 (en) 1998-12-07 2007-03-27 Enventure Global Technology Mono-diameter wellbore casing
GB2431184A (en) * 2005-10-14 2007-04-18 Weatherford Lamb Improved Rotary Expansion
US7231985B2 (en) 1998-11-16 2007-06-19 Shell Oil Company Radial expansion of tubular members
US7234531B2 (en) 1999-12-03 2007-06-26 Enventure Global Technology, Llc Mono-diameter wellbore casing
US7258168B2 (en) 2001-07-27 2007-08-21 Enventure Global Technology L.L.C. Liner hanger with slip joint sealing members and method of use
US7290605B2 (en) 2001-12-27 2007-11-06 Enventure Global Technology Seal receptacle using expandable liner hanger
US7290616B2 (en) 2001-07-06 2007-11-06 Enventure Global Technology, L.L.C. Liner hanger
US7308755B2 (en) 2003-06-13 2007-12-18 Shell Oil Company Apparatus for forming a mono-diameter wellbore casing
US7325602B2 (en) 2000-10-02 2008-02-05 Shell Oil Company Method and apparatus for forming a mono-diameter wellbore casing
US7350563B2 (en) 1999-07-09 2008-04-01 Enventure Global Technology, L.L.C. System for lining a wellbore casing
US7350564B2 (en) 1998-12-07 2008-04-01 Enventure Global Technology, L.L.C. Mono-diameter wellbore casing
US7360591B2 (en) 2002-05-29 2008-04-22 Enventure Global Technology, Llc System for radially expanding a tubular member
US7363984B2 (en) 1998-12-07 2008-04-29 Enventure Global Technology, Llc System for radially expanding a tubular member
US20080110641A1 (en) * 2004-10-08 2008-05-15 Caledus Limited Hanging Apparatus And Method
US7377326B2 (en) 2002-08-23 2008-05-27 Enventure Global Technology, L.L.C. Magnetic impulse applied sleeve method of forming a wellbore casing
US7383889B2 (en) 2001-11-12 2008-06-10 Enventure Global Technology, Llc Mono diameter wellbore casing
US20080156499A1 (en) * 2007-01-03 2008-07-03 Richard Lee Giroux System and methods for tubular expansion
US7398832B2 (en) 2002-06-10 2008-07-15 Enventure Global Technology, Llc Mono-diameter wellbore casing
US7404444B2 (en) 2002-09-20 2008-07-29 Enventure Global Technology Protective sleeve for expandable tubulars
US7410000B2 (en) 2001-01-17 2008-08-12 Enventure Global Technology, Llc. Mono-diameter wellbore casing
US7416027B2 (en) 2001-09-07 2008-08-26 Enventure Global Technology, Llc Adjustable expansion cone assembly
US7424918B2 (en) 2002-08-23 2008-09-16 Enventure Global Technology, L.L.C. Interposed joint sealing layer method of forming a wellbore casing
US7438133B2 (en) 2003-02-26 2008-10-21 Enventure Global Technology, Llc Apparatus and method for radially expanding and plastically deforming a tubular member
US7503393B2 (en) 2003-01-27 2009-03-17 Enventure Global Technology, Inc. Lubrication system for radially expanding tubular members
US7513313B2 (en) 2002-09-20 2009-04-07 Enventure Global Technology, Llc Bottom plug for forming a mono diameter wellbore casing
US7516790B2 (en) 1999-12-03 2009-04-14 Enventure Global Technology, Llc Mono-diameter wellbore casing
US7552776B2 (en) 1998-12-07 2009-06-30 Enventure Global Technology, Llc Anchor hangers
US7571774B2 (en) 2002-09-20 2009-08-11 Eventure Global Technology Self-lubricating expansion mandrel for expandable tubular
US7603758B2 (en) 1998-12-07 2009-10-20 Shell Oil Company Method of coupling a tubular member
US7712522B2 (en) 2003-09-05 2010-05-11 Enventure Global Technology, Llc Expansion cone and system
US7740076B2 (en) 2002-04-12 2010-06-22 Enventure Global Technology, L.L.C. Protective sleeve for threaded connections for expandable liner hanger
US7775290B2 (en) 2003-04-17 2010-08-17 Enventure Global Technology, Llc Apparatus for radially expanding and plastically deforming a tubular member
US7793721B2 (en) 2003-03-11 2010-09-14 Eventure Global Technology, Llc Apparatus for radially expanding and plastically deforming a tubular member
US7819185B2 (en) 2004-08-13 2010-10-26 Enventure Global Technology, Llc Expandable tubular
US7886831B2 (en) 2003-01-22 2011-02-15 Enventure Global Technology, L.L.C. Apparatus for radially expanding and plastically deforming a tubular member
US7918284B2 (en) 2002-04-15 2011-04-05 Enventure Global Technology, L.L.C. Protective sleeve for threaded connections for expandable liner hanger
US20110232355A1 (en) * 2010-03-26 2011-09-29 Evans Merle E Dynamic load expansion test bench
US20130319692A1 (en) * 2012-05-31 2013-12-05 Nader Elias Abedrabbo Compliant cone system
US20180154498A1 (en) * 2016-12-05 2018-06-07 Onesubsea Ip Uk Limited Burnishing assembly systems and methods

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10934796B2 (en) * 2018-05-10 2021-03-02 Deep Casing Tools, Ltd. Method for removing casing from a wellbore

Family Cites Families (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
MY116920A (en) * 1996-07-01 2004-04-30 Shell Int Research Expansion of tubings
GB9920936D0 (en) * 1999-09-06 1999-11-10 E2 Tech Ltd Apparatus for and a method of anchoring an expandable conduit

Cited By (107)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US7108072B2 (en) 1998-11-16 2006-09-19 Shell Oil Company Lubrication and self-cleaning system for expansion mandrel
US20030121558A1 (en) * 1998-11-16 2003-07-03 Cook Robert Lance Radial expansion of tubular members
US7231985B2 (en) 1998-11-16 2007-06-19 Shell Oil Company Radial expansion of tubular members
US7246667B2 (en) 1998-11-16 2007-07-24 Shell Oil Company Radial expansion of tubular members
US7270188B2 (en) 1998-11-16 2007-09-18 Shell Oil Company Radial expansion of tubular members
US7275601B2 (en) 1998-11-16 2007-10-02 Shell Oil Company Radial expansion of tubular members
US7299881B2 (en) 1998-11-16 2007-11-27 Shell Oil Company Radial expansion of tubular members
US7357190B2 (en) 1998-11-16 2008-04-15 Shell Oil Company Radial expansion of tubular members
US7168499B2 (en) 1998-11-16 2007-01-30 Shell Oil Company Radial expansion of tubular members
US7121337B2 (en) 1998-12-07 2006-10-17 Shell Oil Company Apparatus for expanding a tubular member
US7363984B2 (en) 1998-12-07 2008-04-29 Enventure Global Technology, Llc System for radially expanding a tubular member
US7240728B2 (en) 1998-12-07 2007-07-10 Shell Oil Company Expandable tubulars with a radial passage and wall portions with different wall thicknesses
US7011161B2 (en) 1998-12-07 2006-03-14 Shell Oil Company Structural support
US7021390B2 (en) 1998-12-07 2006-04-04 Shell Oil Company Tubular liner for wellbore casing
US7044218B2 (en) 1998-12-07 2006-05-16 Shell Oil Company Apparatus for radially expanding tubular members
US7665532B2 (en) 1998-12-07 2010-02-23 Shell Oil Company Pipeline
US7048062B2 (en) 1998-12-07 2006-05-23 Shell Oil Company Method of selecting tubular members
US7216701B2 (en) 1998-12-07 2007-05-15 Shell Oil Company Apparatus for expanding a tubular member
US7603758B2 (en) 1998-12-07 2009-10-20 Shell Oil Company Method of coupling a tubular member
US7077211B2 (en) 1998-12-07 2006-07-18 Shell Oil Company Method of creating a casing in a borehole
US7077213B2 (en) 1998-12-07 2006-07-18 Shell Oil Company Expansion cone for radially expanding tubular members
US7434618B2 (en) 1998-12-07 2008-10-14 Shell Oil Company Apparatus for expanding a tubular member
US6739392B2 (en) 1998-12-07 2004-05-25 Shell Oil Company Forming a wellbore casing while simultaneously drilling a wellbore
US7552776B2 (en) 1998-12-07 2009-06-30 Enventure Global Technology, Llc Anchor hangers
US7240729B2 (en) 1998-12-07 2007-07-10 Shell Oil Company Apparatus for expanding a tubular member
US6758278B2 (en) 1998-12-07 2004-07-06 Shell Oil Company Forming a wellbore casing while simultaneously drilling a wellbore
US7147053B2 (en) 1998-12-07 2006-12-12 Shell Oil Company Wellhead
US7419009B2 (en) 1998-12-07 2008-09-02 Shell Oil Company Apparatus for radially expanding and plastically deforming a tubular member
US7198100B2 (en) 1998-12-07 2007-04-03 Shell Oil Company Apparatus for expanding a tubular member
US7195064B2 (en) 1998-12-07 2007-03-27 Enventure Global Technology Mono-diameter wellbore casing
US6892819B2 (en) 1998-12-07 2005-05-17 Shell Oil Company Forming a wellbore casing while simultaneously drilling a wellbore
US7195061B2 (en) 1998-12-07 2007-03-27 Shell Oil Company Apparatus for expanding a tubular member
US7357188B1 (en) 1998-12-07 2008-04-15 Shell Oil Company Mono-diameter wellbore casing
US7350564B2 (en) 1998-12-07 2008-04-01 Enventure Global Technology, L.L.C. Mono-diameter wellbore casing
US7174964B2 (en) 1998-12-07 2007-02-13 Shell Oil Company Wellhead with radially expanded tubulars
US7159667B2 (en) 1999-02-25 2007-01-09 Shell Oil Company Method of coupling a tubular member to a preexisting structure
US20030066655A1 (en) * 1999-02-26 2003-04-10 Shell Oil Co. Apparatus for coupling a tubular member to a preexisting structure
US6857473B2 (en) 1999-02-26 2005-02-22 Shell Oil Company Method of coupling a tubular member to a preexisting structure
US7556092B2 (en) 1999-02-26 2009-07-07 Enventure Global Technology, Llc Flow control system for an apparatus for radially expanding tubular members
US7044221B2 (en) 1999-02-26 2006-05-16 Shell Oil Company Apparatus for coupling a tubular member to a preexisting structure
US7438132B2 (en) 1999-03-11 2008-10-21 Shell Oil Company Concentric pipes expanded at the pipe ends and method of forming
US7055608B2 (en) 1999-03-11 2006-06-06 Shell Oil Company Forming a wellbore casing while simultaneously drilling a wellbore
US6968618B2 (en) 1999-04-26 2005-11-29 Shell Oil Company Expandable connector
US7350563B2 (en) 1999-07-09 2008-04-01 Enventure Global Technology, L.L.C. System for lining a wellbore casing
US7234531B2 (en) 1999-12-03 2007-06-26 Enventure Global Technology, Llc Mono-diameter wellbore casing
US7516790B2 (en) 1999-12-03 2009-04-14 Enventure Global Technology, Llc Mono-diameter wellbore casing
US7100684B2 (en) 2000-07-28 2006-09-05 Enventure Global Technology Liner hanger with standoffs
US7172021B2 (en) 2000-09-18 2007-02-06 Shell Oil Company Liner hanger with sliding sleeve valve
US7146702B2 (en) 2000-10-02 2006-12-12 Shell Oil Company Method and apparatus for forming a mono-diameter wellbore casing
US7325602B2 (en) 2000-10-02 2008-02-05 Shell Oil Company Method and apparatus for forming a mono-diameter wellbore casing
US7363691B2 (en) 2000-10-02 2008-04-29 Shell Oil Company Method and apparatus for forming a mono-diameter wellbore casing
US7172019B2 (en) 2000-10-02 2007-02-06 Shell Oil Company Method and apparatus for forming a mono-diameter wellbore casing
US7363690B2 (en) 2000-10-02 2008-04-29 Shell Oil Company Method and apparatus for forming a mono-diameter wellbore casing
US7204007B2 (en) 2000-10-02 2007-04-17 Shell Oil Company Method and apparatus for forming a mono-diameter wellbore casing
US7100685B2 (en) 2000-10-02 2006-09-05 Enventure Global Technology Mono-diameter wellbore casing
US7201223B2 (en) 2000-10-02 2007-04-10 Shell Oil Company Method and apparatus for forming a mono-diameter wellbore casing
US7172024B2 (en) 2000-10-02 2007-02-06 Shell Oil Company Mono-diameter wellbore casing
US7410000B2 (en) 2001-01-17 2008-08-12 Enventure Global Technology, Llc. Mono-diameter wellbore casing
US7172027B2 (en) 2001-05-15 2007-02-06 Weatherford/Lamb, Inc. Expanding tubing
US20040065445A1 (en) * 2001-05-15 2004-04-08 Abercrombie Simpson Neil Andrew Expanding tubing
US7290616B2 (en) 2001-07-06 2007-11-06 Enventure Global Technology, L.L.C. Liner hanger
US7168496B2 (en) 2001-07-06 2007-01-30 Eventure Global Technology Liner hanger
US7258168B2 (en) 2001-07-27 2007-08-21 Enventure Global Technology L.L.C. Liner hanger with slip joint sealing members and method of use
US7416027B2 (en) 2001-09-07 2008-08-26 Enventure Global Technology, Llc Adjustable expansion cone assembly
US7559365B2 (en) 2001-11-12 2009-07-14 Enventure Global Technology, Llc Collapsible expansion cone
US7383889B2 (en) 2001-11-12 2008-06-10 Enventure Global Technology, Llc Mono diameter wellbore casing
US20060283607A1 (en) * 2001-12-27 2006-12-21 Duggan Andrew M Bore isolation
US7066259B2 (en) * 2001-12-27 2006-06-27 Weatherford/Lamb, Inc. Bore isolation
US7798223B2 (en) 2001-12-27 2010-09-21 Weatherford/Lamb, Inc. Bore isolation
US20030146003A1 (en) * 2001-12-27 2003-08-07 Duggan Andrew Michael Bore isolation
US7290605B2 (en) 2001-12-27 2007-11-06 Enventure Global Technology Seal receptacle using expandable liner hanger
US7740076B2 (en) 2002-04-12 2010-06-22 Enventure Global Technology, L.L.C. Protective sleeve for threaded connections for expandable liner hanger
US7918284B2 (en) 2002-04-15 2011-04-05 Enventure Global Technology, L.L.C. Protective sleeve for threaded connections for expandable liner hanger
US7360591B2 (en) 2002-05-29 2008-04-22 Enventure Global Technology, Llc System for radially expanding a tubular member
US7398832B2 (en) 2002-06-10 2008-07-15 Enventure Global Technology, Llc Mono-diameter wellbore casing
US7350584B2 (en) 2002-07-06 2008-04-01 Weatherford/Lamb, Inc. Formed tubulars
US20050000697A1 (en) * 2002-07-06 2005-01-06 Abercrombie Simpson Neil Andrew Formed tubulars
US7377326B2 (en) 2002-08-23 2008-05-27 Enventure Global Technology, L.L.C. Magnetic impulse applied sleeve method of forming a wellbore casing
US7424918B2 (en) 2002-08-23 2008-09-16 Enventure Global Technology, L.L.C. Interposed joint sealing layer method of forming a wellbore casing
US7571774B2 (en) 2002-09-20 2009-08-11 Eventure Global Technology Self-lubricating expansion mandrel for expandable tubular
US7513313B2 (en) 2002-09-20 2009-04-07 Enventure Global Technology, Llc Bottom plug for forming a mono diameter wellbore casing
US7404444B2 (en) 2002-09-20 2008-07-29 Enventure Global Technology Protective sleeve for expandable tubulars
US7886831B2 (en) 2003-01-22 2011-02-15 Enventure Global Technology, L.L.C. Apparatus for radially expanding and plastically deforming a tubular member
US7503393B2 (en) 2003-01-27 2009-03-17 Enventure Global Technology, Inc. Lubrication system for radially expanding tubular members
US7438133B2 (en) 2003-02-26 2008-10-21 Enventure Global Technology, Llc Apparatus and method for radially expanding and plastically deforming a tubular member
US7793721B2 (en) 2003-03-11 2010-09-14 Eventure Global Technology, Llc Apparatus for radially expanding and plastically deforming a tubular member
WO2004083592A3 (fr) * 2003-03-18 2005-05-19 Eventure Global Technology Appareil et procede pour mettre en place un element tubulaire extensible radialement
GB2416361B (en) * 2003-03-18 2007-09-05 Enventure Global Technology Apparatus and method for running a radially expandable tubular member
GB2416361A (en) * 2003-03-18 2006-01-25 Enventure Global Technology Apparatus and method for running a radially expandable tubular member
US7775290B2 (en) 2003-04-17 2010-08-17 Enventure Global Technology, Llc Apparatus for radially expanding and plastically deforming a tubular member
US7308755B2 (en) 2003-06-13 2007-12-18 Shell Oil Company Apparatus for forming a mono-diameter wellbore casing
US7712522B2 (en) 2003-09-05 2010-05-11 Enventure Global Technology, Llc Expansion cone and system
US7819185B2 (en) 2004-08-13 2010-10-26 Enventure Global Technology, Llc Expandable tubular
US7686089B2 (en) * 2004-10-08 2010-03-30 Caledus Limited Hanging apparatus and method
US20080110641A1 (en) * 2004-10-08 2008-05-15 Caledus Limited Hanging Apparatus And Method
US20070000664A1 (en) * 2005-06-30 2007-01-04 Weatherford/Lamb, Inc. Axial compression enhanced tubular expansion
GB2431184A (en) * 2005-10-14 2007-04-18 Weatherford Lamb Improved Rotary Expansion
US7836741B2 (en) 2005-10-14 2010-11-23 Weatherford/Lamb, Inc. Rotary expansion
GB2431184B (en) * 2005-10-14 2011-01-12 Weatherford Lamb Improved rotary expansion
US20070084599A1 (en) * 2005-10-14 2007-04-19 Gary Johnston Rotary expansion
US20080156499A1 (en) * 2007-01-03 2008-07-03 Richard Lee Giroux System and methods for tubular expansion
US8069916B2 (en) 2007-01-03 2011-12-06 Weatherford/Lamb, Inc. System and methods for tubular expansion
US20110232355A1 (en) * 2010-03-26 2011-09-29 Evans Merle E Dynamic load expansion test bench
US9044802B2 (en) * 2010-03-26 2015-06-02 Weatherford Technology Holdings, Llc Dynamic load expansion test bench and method of expanding a tubular
US20130319692A1 (en) * 2012-05-31 2013-12-05 Nader Elias Abedrabbo Compliant cone system
US9187988B2 (en) * 2012-05-31 2015-11-17 Weatherford Technology Holdings, Llc Compliant cone system
US20180154498A1 (en) * 2016-12-05 2018-06-07 Onesubsea Ip Uk Limited Burnishing assembly systems and methods

Also Published As

Publication number Publication date
WO2003036026A1 (fr) 2003-05-01

Similar Documents

Publication Publication Date Title
US20030075337A1 (en) Method of expanding a tubular member in a wellbore
US7350588B2 (en) Method and apparatus for supporting a tubular in a bore
AU2004201822B2 (en) Expandable Hanger with Compliant Slip System
US6325148B1 (en) Tools and methods for use with expandable tubulars
US20030168222A1 (en) Closed system hydraulic expander
AU772473B2 (en) Drilling method
US6752215B2 (en) Method and apparatus for expanding and separating tubulars in a wellbore
US6752216B2 (en) Expandable packer, and method for seating an expandable packer
US6722441B2 (en) Threaded apparatus for selectively translating rotary expander tool downhole
US6585053B2 (en) Method for creating a polished bore receptacle
US7028780B2 (en) Expandable hanger with compliant slip system
US20030042022A1 (en) High pressure high temperature packer system, improved expansion assembly for a tubular expander tool, and method of tubular expansion
AU2012226245A1 (en) Expansion cone assembly for setting a liner hanger in a wellbore casing
EP2681404A1 (fr) Ensemble de cônes de dilatation destiné au positionnement d'un dispositif de suspension dans un tubage de trou de forage
US20040140086A1 (en) Expansion apparatus having resistive medium
AU2004203212B2 (en) Tools and Methods for use with Expandable Tubulars
CA2683103C (fr) Procede et appareil pour etendre et separer des tubulaires dans un puits
GB2415453A (en) Expanding tool for a wellbore tubular

Legal Events

Date Code Title Description
AS Assignment

Owner name: WEATHERFORD/LAMB, INC., TEXAS

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:MAGUIRE, PATRICK G.;REEL/FRAME:012361/0146

Effective date: 20011023

STCB Information on status: application discontinuation

Free format text: ABANDONED -- FAILURE TO PAY ISSUE FEE

点击 这是indexloc提供的php浏览器服务，不要输入任何密码和下载