WO2004083592A2 - Apparatus and method for running a radially expandable tubular member - Google Patents
Apparatus and method for running a radially expandable tubular member Download PDFInfo
- Publication number
- WO2004083592A2 WO2004083592A2 PCT/US2004/008073 US2004008073W WO2004083592A2 WO 2004083592 A2 WO2004083592 A2 WO 2004083592A2 US 2004008073 W US2004008073 W US 2004008073W WO 2004083592 A2 WO2004083592 A2 WO 2004083592A2
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- WO
- WIPO (PCT)
- Prior art keywords
- tubular member
- filed
- attorney docket
- patent application
- application serial
- Prior art date
Links
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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 the boreholes or wells
- E21B23/02—Apparatus for displacing, setting, locking, releasing, or removing tools, packers or the like in the 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 DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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 DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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 DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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 DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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 DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- patent number 6,568,471 which was filed as patent application serial no. 09/512,895, attorney docket no. 25791.12.02, filed on 2/24/2000, which claims priority from provisional application 60/121,841, filed on 2/26/99, (55)
- U.S. patent application serial no. 10/078,922, attorney docket no. 25791.80, filed on 2/20/02 which is a divisional of U.S. patent number 6,568,471, which was filed as patent application serial no. 09/512,895, attorney docket no. 25791.12.02, filed on 2/24/2000, which claims priority from provisional application 60/121,841, filed on 2/26/99, (56)
- patent number 6,557,640 which was filed as patent application serial no. 09/588,946, attorney docket no. 25791.17.02, filed on 6/7/2000, which claims priority from provisional application 60/137,998, filed on 6/7/99, (60) U.S. patent application serial no. 10/092,481, attorney docket no. 25791.85, filed on 3/7/02, which is a divisional of U.S. patent number 6,568,471, which was filed as patent application serial no. 09/512,895, attorney docket no. 25791.12.02, filed on 2/24/2000, which claims priority from provisional application 60/121,841, filed on 2/26/99, (61) U.S. patent application serial no. 10/261,926, attorney docket no.
- Patent Number 6,497,289 which was filed as U.S. Patent Application serial no. 09/454,139, attorney docket no. 25791.03.02, filed on 12/3/1999, which claims priority from provisional application 60/111,293, filed on 12/7/98, (74) PCT application US 03/10144, filed on 3/28/03, attorney docket no. 25791.101.02, which claims priority from U.S. provisional patent application serial no. 60/372,632, attorney docket no. 25791.101, filed on 4/15/02, (75) U.S. provisional patent application serial no. 60/412,542, attorney docket no.
- 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. la is a partial sectional view, not necessarily to scale, depicting the tool 20 of Fig. 1.
- Fig. lb is a partial sectional view, not necessarily to scale, depicting the slip joint 24 of Fig. 1.
- Fig. lc is a partial elevational/partial sectional view, not necessarily to scale, depicting the sub 28 and the expansion apparatus 30 of Fig. 1.
- Fig. 2a is a partial sectional view, not necessarily to scale, depicting the tool 20 of Fig. 1 but showing another operational mode.
- Fig. 2b 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. 3b 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, and 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.
- a 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 is shown and 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 42a and 42b, 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 48a and 48b that are aligned with the openings 42a and 42b of the coupling 37, and the aligned openings receive two torque pins 50a and 50b, respectively.
- the mandrel extension 46 further includes an o-ring 52, a pair of openings 54a and 54b, 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 58a and 58b that are aligned with the openings 54a and 54b, respectively, of the mandrel extension 46.
- Two torque pins 60a and 60b extend through the aligned openings 54a and 60a, and the aligned openings 54b and 60b, respectively.
- the mandrel 56 further includes a plurality of external splines 62a and 62b extending downwardly a predetermined distance along the mandrel 56.
- Each external spline 62a and 62b includes at least one chamfer 64.
- An external shoulder 66 is formed on the mandrel 56 below the external splines 62a and 62b, 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. la).
- 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 74a and 74b formed therein which are engaged with the external splines 62a and 62b, respectively, of the mandrel 56.
- Each of the splines 74a and 74b 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 80a and 80b 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 80a and 80b, 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. lb.
- 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 104a and 104b.
- the tubular member 102 defines a passage 106 and includes a pair of protrusions 108a and 108b extending upwardly from the connection 103.
- a pair of channels 110a and 110b are formed in the bottom portion of the tubular member 102 (one inner side wall of each channel 110a and 110b are shown in Fig. lb).
- 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 118a and 118b are formed therein (one inner side wall of each channel 118a and 118b are shown in Fig. lb).
- the channels 118a and 118b are configured to couple with the protrusions 108a and 108b, 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 124a and 124b.
- the tubular member 120 has a pair of protrusions 126a and 126b extending upwardly from the connection 122 and configured to couple with the channels 110a and 110b, 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.
- FIG. lc 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 136a and 136b 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 no. (attorney's docket no. 25791.238.02), which claims the benefit of the filing date of U.S. provisional patent application serial no. 60/450,504, attorney docket no. 25791.238, filed on February 26, 2003, the disclosure of which is incorporated herein by reference.
- 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 80a and 80b 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, and 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 62a and 62b of the mandrel 56 to disengage from the internal splines 74a and 74b 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 110a and 110b of the member 102 to engage the protrusions 126a and 126b, respectively, of the tubular member 120 and thus connect the member 102 to the member 120 as shown in Fig. 2b, and therefore to the string 26, the expansion apparatus 30, and the tubular member 34. It is noted that the grooves 68 allow fluid to flow between the annulus 35 and the ports 80a and 80b.
- 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. Assuming that the shoe 32 reaches the bottom 12 of the well bore 10 either directly by the lowering operation described above, or as a result of the shoe 32 and/or the member 34 being freed up as described above, and further lowered as necessary, 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 62a and 62b of the mandrel with the internal splines 74a and 74b, respectively, of the cap, and by engaging the shoulder 66 of the mandrel 56 with the surface 78 of the cap 72.
- This also raises the string 22 and the tubular members 92 and 102 of the slip joint 24, thereby disengaging the channels 110a and 110b from the protrusions 126a and 126b, respectively and thus disconnecting the member 102 from the member 120.
- 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 108a and 108b of the member 102 engage the channels 118a and 118b of the member 112, as shown in Fig. 3b.
- This places the components in condition for an expansion procedure in which the expansion apparatus 30 expands the tubular member 34.
- one of several existing expansion procedures may be employed to expand the member 34 such as, for example, the methods disclosed in detail in co-pending U.S. patent application no.
- 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.
- 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.
Abstract
Description
Claims
Priority Applications (3)
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 |
GB0518893A GB2416361B (en) | 2003-03-18 | 2004-03-18 | Apparatus and method for running a radially expandable tubular member |
NO20054774A NO20054774L (en) | 2003-03-18 | 2005-10-17 | Device and method for handling an expandable rudder body |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US45571803P | 2003-03-18 | 2003-03-18 | |
US60/455,718 | 2003-03-18 |
Publications (3)
Publication Number | Publication Date |
---|---|
WO2004083592A2 true WO2004083592A2 (en) | 2004-09-30 |
WO2004083592A3 WO2004083592A3 (en) | 2005-05-19 |
WO2004083592B1 WO2004083592B1 (en) | 2005-06-16 |
Family
ID=33030046
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2004/008073 WO2004083592A2 (en) | 2003-03-18 | 2004-03-18 | Apparatus and method for running a radially expandable tubular member |
Country Status (4)
Country | Link |
---|---|
US (1) | US20070029095A1 (en) |
GB (3) | GB2416361B (en) |
NO (1) | NO20054774L (en) |
WO (1) | WO2004083592A2 (en) |
Cited By (12)
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US7384981B2 (en) | 2001-11-14 | 2008-06-10 | N.V. Nutricia | Preparation for improving the action of receptors |
US7665532B2 (en) | 1998-12-07 | 2010-02-23 | Shell Oil Company | Pipeline |
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 |
US7739917B2 (en) | 2002-09-20 | 2010-06-22 | Enventure Global Technology, Llc | Pipe formability evaluation for expandable tubulars |
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 |
WO2013014440A3 (en) * | 2011-07-27 | 2013-12-05 | Expro North Sea Limited | Landing string |
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AU6981001A (en) * | 1998-11-16 | 2002-01-02 | Shell Oil Co | Radial expansion of tubular members |
GB2344606B (en) * | 1998-12-07 | 2003-08-13 | Shell Int Research | Forming a wellbore casing by expansion of a tubular member |
US7100685B2 (en) * | 2000-10-02 | 2006-09-05 | Enventure Global Technology | Mono-diameter wellbore casing |
US20050166387A1 (en) * | 2003-06-13 | 2005-08-04 | Cook Robert L. | Method and apparatus for forming a mono-diameter wellbore casing |
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US8875783B2 (en) * | 2011-04-27 | 2014-11-04 | Weatherford/Lamb, Inc. | Expansion system for an expandable tubular assembly |
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- 2004-03-18 GB GB0706799A patent/GB2435064B/en not_active Expired - Fee Related
- 2004-03-18 WO PCT/US2004/008073 patent/WO2004083592A2/en active Application Filing
- 2004-03-18 US US10/549,410 patent/US20070029095A1/en not_active Abandoned
- 2004-03-18 GB GB0706794A patent/GB2436743B/en not_active Expired - Fee Related
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US7665532B2 (en) | 1998-12-07 | 2010-02-23 | Shell Oil Company | Pipeline |
US7384981B2 (en) | 2001-11-14 | 2008-06-10 | N.V. Nutricia | Preparation for improving the action of receptors |
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 |
US7739917B2 (en) | 2002-09-20 | 2010-06-22 | Enventure Global Technology, Llc | Pipe formability evaluation 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 |
US7793721B2 (en) | 2003-03-11 | 2010-09-14 | Eventure Global Technology, Llc | Apparatus for radially expanding and plastically deforming a tubular member |
US7775290B2 (en) | 2003-04-17 | 2010-08-17 | Enventure Global Technology, Llc | Apparatus for radially expanding and plastically deforming a tubular member |
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 |
WO2013014440A3 (en) * | 2011-07-27 | 2013-12-05 | Expro North Sea Limited | Landing string |
WO2016018283A1 (en) * | 2014-07-30 | 2016-02-04 | Halliburton Energy Services, Inc. | Deployable baffle |
GB2540915A (en) * | 2014-07-30 | 2017-02-01 | Halliburton Energy Services Inc | Deployable baffle |
Also Published As
Publication number | Publication date |
---|---|
GB2435064B (en) | 2007-10-17 |
GB2436743A (en) | 2007-10-03 |
GB2435064A (en) | 2007-08-15 |
GB0706799D0 (en) | 2007-05-16 |
NO20054774L (en) | 2005-11-28 |
US20070029095A1 (en) | 2007-02-08 |
GB2436743B (en) | 2007-11-21 |
WO2004083592A3 (en) | 2005-05-19 |
NO20054774D0 (en) | 2005-10-17 |
GB0706794D0 (en) | 2007-05-16 |
GB2416361A (en) | 2006-01-25 |
WO2004083592B1 (en) | 2005-06-16 |
GB2416361B (en) | 2007-09-05 |
GB0518893D0 (en) | 2005-10-26 |
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