US20070029095A1 - Apparatus and method for running a radially expandable tubular member - Google Patents

Apparatus and method for running a radially expandable tubular member Download PDF

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Publication number
US20070029095A1
US20070029095A1 US10/549,410 US54941004A US2007029095A1 US 20070029095 A1 US20070029095 A1 US 20070029095A1 US 54941004 A US54941004 A US 54941004A US 2007029095 A1 US2007029095 A1 US 2007029095A1
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United States
Prior art keywords
tubular member
filed
attorney docket
patent application
application ser
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
US10/549,410
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English (en)
Inventor
David Brisco
Michael Bullock
Kevin Waddell
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Enventure Global Technology Inc
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Enventure Global Technology Inc
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Publication date
Application filed by Enventure Global Technology Inc filed Critical Enventure Global Technology Inc
Priority to US10/549,410 priority Critical patent/US20070029095A1/en
Publication of US20070029095A1 publication Critical patent/US20070029095A1/en
Assigned to ENVENTURE GLOBAL TECHNOLOGY, L.L.C. reassignment ENVENTURE GLOBAL TECHNOLOGY, L.L.C. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: BULLOCK, MICHAEL DENNIS, BRISCO, DAVID PAUL, WADDELL, KEVIN KARL
Abandoned legal-status Critical Current

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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
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
    • E21B23/02—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for locking the tools or the like in landing nipples or in recesses between adjacent sections of tubing
    • 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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/02—Couplings; joints
    • E21B17/021—Devices for subsurface connecting or disconnecting by rotation
    • 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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/02—Couplings; joints
    • E21B17/04—Couplings; joints between rod or the like and bit or between rod and rod or the like
    • E21B17/06—Releasing-joints, e.g. safety joints
    • 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
    • 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
    • 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
    • E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
    • E21B19/16—Connecting or disconnecting pipe couplings or joints

Definitions

  • This invention relates generally to oil and gas exploration, and in particular to forming and repairing well bore casings to facilitate oil and gas exploration.
  • Expandable tubing may be used in, among other applications, the forming and repairing of well bore casings.
  • an expandable tubing string is lowered into and down a well bore by an expansion apparatus positioned at the bottom of the string.
  • the expansion apparatus is lowered down the well bore via another tubing string that is disposed through the expandable tubing string and connected to the expansion apparatus. Because the expansion apparatus supports the weight of the expandable tubing string, the string is in compression while being carried down the well bore. If the expandable tubing string is comprised of a series of interconnected joints, this compressive state can result in damage to the various joint connections along the expandable tubing string. Also, if the expandable tubing string is long enough, the overall weight of the string may cause the string to compress to such a degree that an unwanted and/or uncontrolled expansion of the string occurs.
  • FIG. 1 is a partial elevational/partial sectional/partial schematic view, not necessarily to scale, depicting a system according to one embodiment, the system including a tool 20 , a slip joint 24 , a safety sub 28 , an expansion apparatus 30 and an expandable member 34 wherein the expansion apparatus 30 , among other components, is being lowered.
  • FIG. 1 a is a partial sectional view, not necessarily to scale, depicting the tool 20 of FIG. 1 .
  • FIG. 1 b is a partial sectional view, not necessarily to scale, depicting the slip joint 24 of FIG. 1 .
  • FIG. 1 c is a partial elevational/partial sectional view, not necessarily to scale, depicting the sub 28 and the expansion apparatus 30 of FIG. 1 .
  • FIG. 2 a is a partial sectional view, not necessarily to scale, depicting the tool 20 of FIG. 1 but showing another operational mode.
  • FIG. 2 b is a partial sectional view, not necessarily to scale, depicting the slip joint 24 of FIG. 1 but showing another operational mode.
  • FIG. 3 a is a partial sectional view, not necessarily to scale, depicting the tool 20 of FIG. 1 but showing yet another operational mode.
  • FIG. 3 b is a partial sectional view, not necessarily to scale, depicting the slip joint 24 of FIG. 1 but showing yet another operational mode.
  • the reference numeral 10 refers to a well bore penetrating a subterranean ground formation F for the purpose of recovering hydrocarbon fluids from the formation, the well bore having a bottom 12 .
  • a series of components 14 is lowered into the well bore 10 by a tubular string 16 , in the form of coiled tubing, jointed tubing, or the like which is connected to the upper end of the series. The components in the series 14 will be described.
  • the string 16 extends from a rig 18 that is located above ground and extends over the well bore 10 .
  • the rig 18 is conventional and, as such, includes support structure, a motor driven winch, or the like, and other associated equipment for receiving and supporting the series 14 and lowering it into the well bore 10 by unwinding the string 16 from the winch.
  • the upper portion of the well bore 10 can be lined with a casing 19 in any conventional manner.
  • the series 14 includes a tool 20 to which the string 16 is connected.
  • a tubular string 22 in the form of coiled tubing, jointed tubing, or the like, is connected to and extends downward from the tool 20 .
  • a slip joint 24 is connected to the lower end of the string 22
  • a tubular string 26 in the form of coiled tubing, jointed tubing, or the like, is connected to and extends downward from the slip joint 24 and its lower end is connected to a safety sub 28 .
  • An expansion apparatus 30 is connected to the sub 28 .
  • the expansion apparatus 30 includes a float shoe 32 .
  • An expandable tubular member 34 is connected to, and extends downward from, the lower end of the tool 20 to the shoe 32 so that the slip joint 24 , the string 26 , the sub 28 , and the expansion apparatus 30 are all disposed within the member 34 .
  • the expansion apparatus 30 is slidably engaged with the internal wall of the member 34 .
  • the member 34 is comprised of a plurality of joints (not shown) that are each interconnected via a left hand thread engagement configuration.
  • the series of components 14 includes the tool 20 , the string 22 , the slip joint 24 , the string 26 , the sub 28 , the expansion apparatus 30 which includes the shoe 32 , and the member 34 .
  • variable-dimension annulus 35 is defined by the internal wall of the member 34 and the external walls of the string 22 , the slip joint 24 and the string 26 .
  • a variable-dimension annulus 36 is also defined between the inner wall of the well bore 10 and the external wall of the member 34 .
  • an embodiment of the tool 20 includes an elongated tubular member or coupling 37 to which the string 16 is connected via a conventional drillpipe box thread connection 38 .
  • the coupling 37 includes an o-ring 40 , a pair of openings 42 a and 42 b , and an internal straight thread connection 44 . Also, the coupling 37 defines a passage 45 .
  • a mandrel extension 46 in the form of an elongated tubular body member, is connected to the coupling 37 via the thread connection 44 , and the o-ring 40 seals against the mandrel extension 46 immediately above this connection.
  • the mandrel extension 46 includes a pair of openings 48 a and 48 b that are aligned with the openings 42 a and 42 b of the coupling 37 , and the aligned openings receive two torque pins 50 a and 50 b , respectively.
  • the mandrel extension 46 further includes an o-ring 52 , a pair of openings 54 a and 54 b , and an internal straight thread connection 55 .
  • a mandrel 56 also in the form of an elongated tubular body member, is connected to the mandrel extension 46 via the thread connection 55 , and the o-ring 52 seals against the mandrel immediately above this connection.
  • the mandrel 56 includes a pair of openings 58 a and 58 b that are aligned with the openings 54 a and 54 b , respectively, of the mandrel extension 46 .
  • Two torque pins 60 a and 60 b extend through the aligned openings 54 a and 60 a , and the aligned openings 54 b and 60 b , respectively.
  • the mandrel 56 further includes a plurality of external splines 62 a and 62 b extending downwardly a predetermined distance along the mandrel 56 .
  • Each external spline 62 a and 62 b includes at least one chamfer 64 .
  • An external shoulder 66 is formed on the mandrel 56 below the external splines 62 a and 62 b , and a plurality of downward-extending grooves 68 are formed in the shoulder 66 (a side wall of one groove 68 is shown in FIG. 1a ).
  • the mandrel 56 further includes a conventional drillpipe pin thread connection 70 to which the string 22 is connected.
  • a tubular cap 72 extends around the mandrel 56 and has a plurality of internal splines 74 a and 74 b formed therein which are engaged with the external splines 62 a and 62 b , respectively, of the mandrel 56 .
  • Each of the splines 74 a and 74 b has at least one chamfer 76 (not shown) which is adapted to engage a corresponding chamfer 64 of the mandrel 56 .
  • the cap 72 further includes a radial surface 78 that is engaged with the shoulder 66 of the mandrel 56 , and a pair of fluid ports 80 a and 80 b are formed in the cap 72 at a predetermined distance below the surface 78 .
  • An annular recess 82 is formed in the cap 72 at a predetermined distance below the fluid ports 80 a and 80 b , and receives an anti-torque ring 84 , which is made of a conventional low-friction material.
  • the cap 72 further includes an internal right hand straight thread connection 86 .
  • a casing adapter 88 in the form of an elongated tubular member, is connected to the cap 72 via the connection 86 and the anti-torque ring 84 is adapted to allow the cap 72 to be removably connected to the casing adapter 88 . Since the anti-torque ring 84 is conventional, it will not be described in further detail.
  • the casing adapter 88 extends downwardly and includes an internal left hand thread connection 90 to which the member 34 is connected.
  • connection 86 may be tightened until the casing adapter 88 firmly shoulders against the anti-torque ring 84 and the recess 82 in the cap 72 , and then the casing adapter 88 may be backed off of at least a portion of the threads in the connection 86 so as to prevent any inadvertent right hand torque from being applied to the top of the member 34 and thereby loosen the aforementioned left hand threaded joint interconnections of the member 34 .
  • an embodiment of the slip joint 24 is shown within the expandable tubular member 34 and includes a tubular member 92 having a conventional drillpipe box thread connection 94 to which the string 22 is connected.
  • the bore of the member 92 is stepped to define three concentric inner passages 96 , 98 and 100 of increasing diameter in a downwardly direction, as viewed in FIG. 1 b .
  • An o-ring 101 is retained in an annular channel extending circumferentially about the passage 98 .
  • the upper end portion of a tubular member 102 is connected to the lower end portion of the tubular member 92 via a threaded connection 103 and a pair of torque pins 104 a and 104 b .
  • the tubular member 102 defines a passage 106 and includes a pair of protrusions 108 a and 108 b extending upwardly from the connection 103 .
  • a pair of channels 110 a and 110 b are formed in the bottom portion of the tubular member 102 (one inner side wall of each channel 110 a and 110 b are shown in FIG. 1 b ).
  • the slip joint 24 also includes an elongated tubular member 112 which is disposed in the passages 98 , 100 and 106 .
  • the tubular member 112 includes an upper portion 114 that is slidably engaged with a portion of the internal wall of the passage 98 of the tubular member 92 , with the o-ring 101 sealing against the upper portion 114 .
  • a integral flange or ring 116 extends radially outward from the tubular member 112 and a pair of channels 118 a and 118 b are formed therein (one inner side wall of each channel 118 a and 118 b are shown in FIG. 1 b ).
  • the channels 118 a and 118 b are configured to couple with the protrusions 108 a and 108 b , respectively, of the tubular member 102 .
  • a tubular member 120 also forms part of the slip joint 24 , defines an internal passage 121 , and is connected to the tubular member 112 via a threaded connection 122 and a pair of torque pins 124 a and 124 b .
  • the tubular member 120 has a pair of protrusions 126 a and 126 b extending upwardly from the connection 122 and configured to couple with the channels 110 a and 110 b , respectively, of the tubular member 102 .
  • the tubular member 120 further includes an o-ring 127 which is sealed against a bottom portion of the tubular member 112 , and a conventional drillpipe pin thread connection 128 to which the string 26 is connected.
  • an embodiment of the expansion apparatus 30 is shown within the tubular member 34 .
  • the upper end of the apparatus 30 is connected to the sub 28 in any conventional manner, and the sub 28 is connected to the string 26 via a conventional drillpipe box thread connection 130 .
  • the expansion apparatus 30 includes an expansion cone portion 132 that engages the inner wall of the member 34 .
  • the shoe 32 of the expansion apparatus 30 is connected to the member 34 via a threaded connection 134 and a pair of radially-extending threaded fasteners 136 a and 136 b are disposed through the member 34 and into the shoe 32 .
  • the sub 28 and the expansion apparatus 30 are designed so that torque may be transmitted from the string 26 to the member 34 via the shoe 32 .
  • the expansion apparatus 30 may be in the form of one of several existing expansion apparatuses, such as, for example, the expansion apparatus disclosed in detail in co-pending U.S. patent application Ser. No. ______ (attorney's docket no.
  • the external splines 62 a and 62 b of the mandrel 56 are engaged with the internal splines 74 a and 74 b of the cap 72 , and the surface 78 of the cap 72 is in contact with the shoulder 66 , as described above.
  • the tubular member 34 is in tension since its weight is primarily carried by the shoulder 66 of the mandrel 56 of the tool 20 and neither the above-described joints nor the joint interconnections of the member 34 undergo compression due to the weight of the expandable tubular member.
  • the fluid ports 80 a and 80 b allow fluid to flow from the well bore 10 and into the annulus 35 , or vice versa, and the o-rings 40 and 52 provide a fluid seal between the well bore 10 and the passage 45 of the tool 20 .
  • the o-ring 101 provides a fluid seal between the passage 100 and the passage 98 of the slip joint 24
  • the o-ring 127 provides a fluid seal between the annulus 35 and the passage 121 .
  • the string 16 is further lowered into the well bore 10 which also lowers the mandrel extension 46 , the mandrel 56 , the string 22 , the member 92 and the member 102 relative to the expansion apparatus 30 , the shoe 32 , the sub 28 , the member 34 , the cap 72 , the members 112 and 120 and the string 26 which are prevented from further movement by the resistance.
  • This causes the external splines 62 a and 62 b of the mandrel 56 to disengage from the internal splines 74 a and 74 b of the cap 72 , respectively, and the shoulder 66 of the mandrel 56 to disengage from the surface 78 of the cap 72 , as shown in FIG. 2a .
  • the above lowering of the tubular member 102 causes the channels 110 a and 110 b of the member 102 to engage the protrusions 126 a and 126 b , respectively, of the tubular member 120 and thus connect the member 102 to the member 120 as shown in FIG. 2 b , and therefore to the string 26 , the expansion apparatus 30 , and the tubular member 34 .
  • the grooves 68 allow fluid to flow between the annulus 35 and the ports 80 a and 80 b.
  • a torque from the rig 18 is applied to the string 16 in any conventional manner, to rotate the string 16 clockwise, as viewed downwardly towards the bottom 12 of the well bore 10 , to apply a right hand torque that is transmitted from the string 16 through the coupling 37 , the mandrel extension 46 , the mandrel 56 , the string 22 , the tubular member 92 , the tubular member 102 , the tubular member 120 , the string 26 , the sub 28 , the expansion apparatus 30 , the shoe 32 and the member 34 , due to the above-described connections between these components.
  • This torque thus causes the shoe 32 and the member 34 to rotate in a clockwise direction, as defined above and hopefully free them from the above-described resistance, thus allowing the string 16 and the series of components 14 to be lowered further until the shoe 32 reaches the bottom 12 of the well bore 10 . Due to the above-described left hand thread engagement configuration of the various joint interconnections of the member 34 , the interconnections are not loosened due to this rotation.
  • the expansion apparatus 30 can be conditioned for expansion in the following manner.
  • the string 16 and therefore the coupling 37 , the mandrel extension 46 and the mandrel 56 , are raised as necessary in order to directly connect the mandrel 56 with the cap 72 by engaging the external splines 62 a and 62 b of the mandrel with the internal splines 74 a and 74 b , respectively, of the cap, and by engaging the shoulder 66 of the mandrel 56 with the surface 78 of the cap 72 .
  • the anti-torque ring 84 functions in a conventional manner, allowing the cap 72 to be removed from the casing adapter 88 .
  • the torque is not transmitted from the string 22 to the string 26 since there is no engagement between the members 102 and 112 , nor between the members 102 and 120 , as described above and as shown in FIG. 1 b.
  • the string 16 is raised further, thereby raising the coupling 37 , the mandrel extension 46 , the mandrel 56 , the cap 72 (via the shoulder 66 of the mandrel 56 ) and the string 22 .
  • the tubular members 92 and 102 are also raised until the protrusions 108 a and 108 b of the member 102 engage the channels 118 a and 118 b of the member 112 , as shown in FIG. 3 b . This places the components in condition for an expansion procedure in which the expansion apparatus 30 expands the tubular member 34 .
  • the above-mentioned right hand torque can be applied to the string 16 to rotate the shoe 32 and the member 34 for reasons other than those discussed above.
  • a hardenable fluidic sealing material into at least a lower region of the annulus 36 between the member 34 and the wall of the well bore 10 .
  • the sealing material would be introduced from the rig 18 into the string 16 and pass through the tool 20 , the string 22 , the slip joint 24 , the string 26 and the expansion apparatus 30 and flow into at least a lower region of the annulus 36 between the member 34 and the wall of the well bore 10 .
  • the series of components 14 may be entirely positioned below the casing 19 , or the series may be entirely positioned within the casing, or a portion of the series may be within the casing 19 and another portion of the series may be below the casing 19 , such as, for example, the tool 20 being positioned within the casing 19 and the majority of the member 34 being positioned below the casing 19 .
  • the mandrel extension 46 may be combined with the mandrel 56 to form an integral component.
  • Additional external splines may be added to the mandrel 56 , and additional corresponding internal splines may be added to the cap 72 .
  • Additional grooves and fluid ports for fluid flow may be formed in the shoulder 66 and the cap 72 , respectively.
  • Conventional supporting structures such as, for example, solid centralizers or standoffs, may be added in any conventional manner in order to decrease the possibility of the member 34 buckling during the above-described operation.
  • Additional channels may be formed in the tubular member 112 of the slip joint 24 and these additional channels may be coupled to additional protrusions that may be added to the tubular member 102 .
  • Additional channels may be formed in the tubular member 102 of the slip joint 24 and these additional channels may be coupled to additional protrusions that may be added to the tubular member 120 .

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  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Environmental & Geological Engineering (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Physics & Mathematics (AREA)
  • Fluid Mechanics (AREA)
  • Mechanical Engineering (AREA)
  • Compressors, Vaccum Pumps And Other Relevant Systems (AREA)
  • Lining Or Joining Of Plastics Or The Like (AREA)
  • Polishing Bodies And Polishing Tools (AREA)
  • Prostheses (AREA)
  • Apparatus Associated With Microorganisms And Enzymes (AREA)
  • Medicines That Contain Protein Lipid Enzymes And Other Medicines (AREA)
  • Containers And Plastic Fillers For Packaging (AREA)
  • Earth Drilling (AREA)
  • Shaping Of Tube Ends By Bending Or Straightening (AREA)
US10/549,410 2003-03-18 2004-03-18 Apparatus and method for running a radially expandable tubular member Abandoned US20070029095A1 (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
US10/549,410 US20070029095A1 (en) 2003-03-18 2004-03-18 Apparatus and method for running a radially expandable tubular member

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
US45571803P 2003-03-18 2003-03-18
PCT/US2004/008073 WO2004083592A2 (fr) 2003-03-18 2004-03-18 Appareil et procede pour mettre en place un element tubulaire extensible radialement
US10/549,410 US20070029095A1 (en) 2003-03-18 2004-03-18 Apparatus and method for running a radially expandable tubular member

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US20070029095A1 true US20070029095A1 (en) 2007-02-08

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US10/549,410 Abandoned US20070029095A1 (en) 2003-03-18 2004-03-18 Apparatus and method for running a radially expandable tubular member

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GB (3) GB2435064B (fr)
NO (1) NO20054774L (fr)
WO (1) WO2004083592A2 (fr)

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US20050039928A1 (en) * 1998-11-16 2005-02-24 Cook Robert Lance Radial expansion of tubular members
US20050144777A1 (en) * 2003-06-13 2005-07-07 Cook Robert L. Method and apparatus for forming a mono-diameter wellbore casing
US20050161228A1 (en) * 1998-12-07 2005-07-28 Cook Robert L. Apparatus for radially expanding and plastically deforming a tubular member
US20050223535A1 (en) * 2000-10-02 2005-10-13 Cook Robert L Method and apparatus for forming a mono-diameter wellbore casing
US7383889B2 (en) 2001-11-12 2008-06-10 Enventure Global Technology, Llc Mono diameter wellbore casing
US20080257560A1 (en) * 2007-04-20 2008-10-23 Brisco David P Running Tool for Expandable Liner Hanger and Associated Methods
US20090107686A1 (en) * 2007-10-24 2009-04-30 Watson Brock W Setting tool for expandable liner hanger and associated methods
US20100147535A1 (en) * 2006-04-18 2010-06-17 Read Well Services Limited Expandable Liner Hanger
US20100155084A1 (en) * 2008-12-23 2010-06-24 Halliburton Energy Services, Inc. Setting tool for expandable liner hanger and associated methods
US20110168411A1 (en) * 2010-01-11 2011-07-14 Braddick Britt O Tubular expansion tool and method
US20110220356A1 (en) * 2010-03-11 2011-09-15 Halliburton Energy Services, Inc. Multiple stage cementing tool with expandable sealing element
AU2012249510B2 (en) * 2011-04-27 2016-01-07 Weatherford Technology Holdings, Llc Expansion system for an expandable tubular assembly
US9725992B2 (en) 2010-11-24 2017-08-08 Halliburton Energy Services, Inc. Entry guide formation on a well liner hanger
US11566486B2 (en) * 2019-10-28 2023-01-31 Frac Master Fz-Llc Transforming bridge-to-flow-through frac plug
US20240052719A1 (en) * 2022-08-15 2024-02-15 SBS Technology AS Two-stage torque release sub

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US7168496B2 (en) 2001-07-06 2007-01-30 Eventure Global Technology Liner hanger
US7357188B1 (en) 1998-12-07 2008-04-15 Shell Oil Company Mono-diameter wellbore casing
US6823937B1 (en) 1998-12-07 2004-11-30 Shell Oil Company Wellhead
US6557640B1 (en) 1998-12-07 2003-05-06 Shell Oil Company Lubrication and self-cleaning system for expansion mandrel
US7231985B2 (en) 1998-11-16 2007-06-19 Shell Oil Company Radial expansion of tubular members
US7552776B2 (en) 1998-12-07 2009-06-30 Enventure Global Technology, Llc Anchor hangers
CA2310878A1 (fr) 1998-12-07 2000-12-07 Shell Internationale Research Maatschappij B.V. Systeme de lubrification et d'autonettoyage pour mandrin expansible
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US6739392B2 (en) 1998-12-07 2004-05-25 Shell Oil Company Forming a wellbore casing while simultaneously drilling a wellbore
US7363984B2 (en) 1998-12-07 2008-04-29 Enventure Global Technology, Llc System for radially expanding a tubular member
US7185710B2 (en) 1998-12-07 2007-03-06 Enventure Global Technology Mono-diameter wellbore casing
AU770359B2 (en) 1999-02-26 2004-02-19 Shell Internationale Research Maatschappij B.V. Liner hanger
US7055608B2 (en) 1999-03-11 2006-06-06 Shell Oil Company Forming a wellbore casing while simultaneously drilling a wellbore
US7350563B2 (en) 1999-07-09 2008-04-01 Enventure Global Technology, L.L.C. System for lining a wellbore casing
US7048067B1 (en) 1999-11-01 2006-05-23 Shell Oil Company Wellbore casing repair
US7516790B2 (en) 1999-12-03 2009-04-14 Enventure Global Technology, Llc Mono-diameter wellbore casing
US7234531B2 (en) 1999-12-03 2007-06-26 Enventure Global Technology, Llc Mono-diameter wellbore casing
US7100684B2 (en) 2000-07-28 2006-09-05 Enventure Global Technology Liner hanger with standoffs
WO2002023007A1 (fr) 2000-09-18 2002-03-21 Shell Oil Company Suspension de colonne perdue comprenant une soupape a manchon
GB2389597B (en) 2000-10-02 2005-05-18 Shell Oil Co Plastically deforming and radially expanding a tubular member
CA2428819A1 (fr) 2001-01-03 2002-07-11 Enventure Global Technology Cuvelage de diametre nanometrique pour puits fore
US7410000B2 (en) 2001-01-17 2008-08-12 Enventure Global Technology, Llc. Mono-diameter wellbore casing
CA2453034C (fr) 2001-07-06 2010-09-14 Enventure Global Technology Suspension de colonne perdue
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
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GB0706799D0 (en) 2007-05-16
GB2416361A (en) 2006-01-25
GB2436743A (en) 2007-10-03
GB2416361B (en) 2007-09-05
GB2435064B (en) 2007-10-17
WO2004083592A2 (fr) 2004-09-30
NO20054774L (no) 2005-11-28
WO2004083592B1 (fr) 2005-06-16
GB2436743B (en) 2007-11-21
GB0706794D0 (en) 2007-05-16
NO20054774D0 (no) 2005-10-17
GB2435064A (en) 2007-08-15
WO2004083592A3 (fr) 2005-05-19
GB0518893D0 (en) 2005-10-26

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