WO2011081673A1 - Direction de mèche de forage à vitesse de rotation variable - Google Patents

Direction de mèche de forage à vitesse de rotation variable Download PDF

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Publication number
WO2011081673A1
WO2011081673A1 PCT/US2010/028498 US2010028498W WO2011081673A1 WO 2011081673 A1 WO2011081673 A1 WO 2011081673A1 US 2010028498 W US2010028498 W US 2010028498W WO 2011081673 A1 WO2011081673 A1 WO 2011081673A1
Authority
WO
WIPO (PCT)
Prior art keywords
drill bit
axis
azimuthal direction
drill
drill string
Prior art date
Application number
PCT/US2010/028498
Other languages
English (en)
Inventor
Malcolm Upshall
John C. Gibb
Original Assignee
Halliburton Energy Services, 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 Halliburton Energy Services, Inc. filed Critical Halliburton Energy Services, Inc.
Priority to US12/960,087 priority Critical patent/US20110155466A1/en
Publication of WO2011081673A1 publication Critical patent/WO2011081673A1/fr

Links

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
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/04—Directional drilling
    • E21B7/06—Deflecting the direction of boreholes
    • E21B7/068—Deflecting the direction of boreholes drilled by a down-hole drilling motor
    • 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
    • E21B4/00—Drives for drilling, used in the borehole
    • E21B4/06—Down-hole impacting means, e.g. hammers
    • 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
    • E21B4/00—Drives for drilling, used in the borehole
    • E21B4/16—Plural down-hole drives, e.g. for combined percussion and rotary drilling; Drives for multi-bit drilling units
    • 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
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/04—Directional drilling
    • E21B7/06—Deflecting the direction of boreholes
    • E21B7/067—Deflecting the direction of boreholes with means for locking sections of a pipe or of a guide for a shaft in angular relation, e.g. adjustable bent sub

Definitions

  • the present disclosure relates generally to equipment utilized and operations performed in conjunction with a subterranean well and, in an embodiment described herein, more particularly provides for drill bit steering by varying a rotational speed of the drill bit.
  • FIG. 1 is a schematic view of a directional drilling system and associated method which may embody principles of the present disclosure.
  • FIG. 2 is a schematic depiction of relative
  • FIG. 3 is a schematic depiction of an azimuthal
  • FIGS. 4-7 are schematic cross-sectional views of various configurations of an impact tool which may be used in the system and method of FIG. 1.
  • FIG. 8 is a schematic cross-sectional view of a brake which may be used in the system and method of FIG. 1.
  • FIG. 1 Representatively illustrated in FIG. 1 is a directional drilling system 10 and associated method which can embody principles of the present disclosure. It should be clearly understood, however, that the principles of this disclosure are not limited at all to the specific details of the system 10 and method described herein. Instead, the system 10 and method are provided as merely one example of how the
  • a wellbore 12 is being drilled with a generally tubular drill string 14.
  • a drill bit 16 is connected at a lower end of the drill string 14.
  • Rotation of the drill string 14 e.g., by a drilling rig at or near the earth's surface
  • a mud motor 18 is also preferably interconnected as part of the drill string 14.
  • the mud motor 18 is of the type well known to those skilled in the art, which rotates the drill bit 16 in response to flow of drilling fluid through the drill string 14.
  • the mud motor 18 can be used to rotate the drill bit 16, even if the drill string 14 above the mud motor is not rotated.
  • Mud motors are also known as positive displacement motors, Moineau-type motors and progressive cavity motors.
  • motors include a helical rotor which rotates within, and sealingly engages, a multi-lobed stator.
  • a bend 20 is also interconnected in the drill string 14. Although not perceptible in FIG. 1, the bend 20
  • the bend 20 is of the type well known to those skilled in the art, and is typically used for directional drilling when a mud motor (such as the mud motor 18) rotates a drill bit (such as the drill bit 16) .
  • the bend 20 can be used for steering the drill bit 16 in the system 10 when the mud motor 18 rotates the drill bit (e.g., when the drill string 14 is not rotated from the surface).
  • this disclosure also provides for steering the drill bit 16 when the drill string 14 is rotated, and the mud motor 18 is used for rotating the drill bit in response to flow of drilling fluid through the mud motor .
  • the rotational speed of the drill bit when the drill string 14 and the mud motor 18 are used for rotating the drill bit 16, the rotational speed of the drill bit
  • rpm rotation per minute
  • the timing of the rpm variations is controlled by a controller 24, which is in communication with a sensor assembly 26, and which can be remotely operable and communicated with (e.g., from the surface) via various forms of wired and wireless telemetry.
  • rotational speed of the drill bit 16 can be varied by operation of a brake 17.
  • the brake 17 selectively applies a braking force to a shaft of the mud motor 18, to thereby vary the rotational speed of the drill bit 16.
  • the brake 17 can deliver timed periodic variations of drill bit 16 rpm as described more fully below.
  • the timing of application of the braking force is preferably controlled by the controller 24.
  • the sensor assembly 26 can be of the type well known to those skilled in the art as a measurement while drilling (MWD) system. Such MWD systems are capable of measuring a multitude of drilling parameters, and in this system 10 the sensor assembly 26 is beneficially capable of detecting an orientation of the drill string 14 and, in conjunction with a sensor 19 of the mud motor 18, an azimuthal direction of the drill bit 16 relative to the longitudinal axis of the drill string above the bend 20 can be readily determined.
  • MWD measurement while drilling
  • the impact tool 22 can deliver timed periodic impacts to the drill bit 16 as described more fully below, although use of the impact tool is not necessary in keeping with the principles of this disclosure.
  • the timing of the impacts is controlled by the controller 24, and can also be remotely operable (e.g., from the surface) via various forms of wired and wireless
  • FIG. 2 a schematic depiction of the longitudinal axis 28 of the drill string 14 is representatively illustrated.
  • the bend 20 in the drill string 14 is exaggerated in FIG. 2 for illustrative
  • the longitudinal axis 28 of the drill string 14 above the bend 20 is designated as 28a
  • the longitudinal axis of the drill string at the bend is designated as 28b
  • the longitudinal axis of the drill string below the bend is designated as 28c in FIG. 2. Note that the longitudinal axis 28c of the drill string 14 below the bend 20 coincides with the longitudinal axis of the drill bit 16.
  • the axis 28c of the drill bit 16 deviates from the longitudinal axis 28a of the drill string 14 above the bend 20 by an angle A.
  • This angle A may be relatively small, but when compounded over distances of, for example, a hundred meters or more, can produce a much larger change in direction of the wellbore 12.
  • axis 28a is depicted in FIG. 2 as being vertical, the axis 28a is described herein as being “above” the bend 20, and the axis 28c is described herein as being “below” the bend, it is not necessary in keeping with the principles of this disclosure for the axis 28a to be vertical, since the axis 28a could be generally horizontal, deviated, inclined relative to vertical, etc.
  • proximal end of the drill string 14 e.g., closer to the surface
  • the axis 28c is "below" the bend, in that it is nearer the distal end (in this case, the bottom end) of the drill string (e.g., farther from the surface).
  • the impact tool 22 can be used to deliver an impact (represented by arrows 30 in FIG. 2) directed along the longitudinal axis 28 of the drill string 14. Due to the bend 20 in the drill string 14, the impact 30 can be
  • FIG. 3 a schematic view of the relationship between the azimuthal direction of the drill bit 16 (represented by arrow 32 in FIG. 3) and the drill string axis 28a is representatively illustrated. That is, FIG. 3 presents a view downward along the axis 28a and, due to the angle A by which the drill bit axis 28c deviates from the drill string axis 28a, the drill bit 16 has an azimuthal direction 32 relative to the drill string axis 28a.
  • the brake 17 causes the drill bit 16 rpm to increase when the azimuthal
  • the direction 32 of the drill bit axis 28c relative to the drill string axis 28a is in a desired direction (or at least within a selected range of the desired direction, for example, within a window of 10 degrees to either side of the desired direction) .
  • the brake 17 causes the drill bit 16 rpm to decrease when the azimuthal direction 32 of the drill bit axis 28c relative to the drill string axis 28a is not in the desired direction.
  • the impact tool 22 delivers the impact 30 to the drill bit 16 when (and preferably only when) the azimuthal direction 32 of the drill bit axis 28c relative to the drill string axis 28a is in a desired direction.
  • the impact tool 22 may be used to deliver the impact 30 in conjunction with the drill bit 16 speed variations, or the impact tool may be used separately from the variations in drill bit speed (i.e., so that the two techniques are not simultaneously used to steer the drill bit 16) .
  • the impact 30 would be delivered to the drill bit 16 when the drill bit axis 28c is oriented in an azimuthal direction 32 of 30 degrees relative to the drill string axis 28a (as depicted in FIG. 3). Since the azimuthal direction 32 of the drill bit axis 28c rotates about the drill string axis 28a (as represented by arrow 34 in FIG. 3) as the drill string 14 rotates, the azimuthal direction of the drill bit axis will coincide with the desired azimuthal direction once for every rotation of the drill string 14.
  • the brake 17 increases the rpm of the drill bit 16 once for each rotation of the drill string 14 (when the azimuthal direction 32 of the drill bit axis 28c is oriented toward the desired direction), but the increased rpm could be provided every other rotation, every third rotation, multiple times per rotation, or at other times, in keeping with the principles of this disclosure.
  • the controller 24 controls the timing of the increased rpm, based on the detection of the orientation of the drill bit axis 28c relative to the drill string axis 28a as sensed by the sensor assembly 26 and the mud motor sensor 19, and preferably based on commands, data, instructions, etc.
  • telemetry may be communicated with a remote location (such as the surface) via telemetry.
  • a remote location such as the surface
  • telemetry Any form of telemetry may be used, for example, wired or wireless telemetry.
  • Wireless telemetry may include acoustic, electromagnetic, pressure pulse
  • Wired telemetry may be via conductors internal to, external to, or in a wall of the drill string 14, etc.
  • the controller 24 may be used to activate or deactivate the brake 17 (e.g., to cause the brake to begin or cease delivering the variations in drill bit 16 rpm) , to change the frequency of the rpm variations (e.g., the number of rpm variations per rotation of the drill string 14), to change the desired azimuthal direction for steering the drill bit, to change the amplitude of rpm variation, etc. Any
  • controller 24 may be controlled using the controller 24, in keeping with the principles of this disclosure.
  • the controller 24, or any portion of it, may be located downhole or at a remote location (such as the earth's surface, a sea floor location, a floating rig, etc.), and the controller can be part of a more comprehensive control system.
  • the bend 20 below the mud motor 18 rotates through the hole it will create a rotating contact pressure on the inner wall of the wellbore 12, due to the bend.
  • some of the force (such as, due to the weight of the drill string 14) applied to the drill bit 16 is directed laterally, instead of only in an axial direction.
  • the rpm of the drill bit 16 is varied at any given azimuthal orientation of the bend 20, it will facilitate either more or less cutting into the earth at that orientation, thereby providing for steering in a desired direction.
  • the impact tool 22 delivers the impact 30 to the drill bit 16 once for each rotation of the drill string 14 (when the azimuthal direction 32 of the drill bit axis 28c is oriented toward the desired direction), but the impact could be delivered every other rotation, every third rotation, multiple times per rotation, or at other times, in keeping with the
  • the controller 24 controls the timing of the impact 30, based on the detection of the orientation of the drill bit axis 28c relative to the drill string axis 28a as sensed by the sensor assembly 26, the sensor 19, and preferably based on commands, data, instructions, etc. received from a remote location (such as the surface) via telemetry.
  • the controller 24 may be used to activate or deactivate the impact tool 22 (e.g., to cause the impact tool to begin or cease delivering the impact 30 to the drill bit 16), to change the frequency of the impact (e.g., the number of impacts per rotation of the drill string 14), to change the desired azimuthal direction for steering the drill bit, to change the impact force delivered, etc. Any parameter related to the delivery of the impact 30 by the impact tool 22 may be controlled using the controller 24, in keeping with the principles of this disclosure. Referring additionally now to FIGS. 4-7, various configurations of the impact tool 22 are schematically and representatively illustrated. However, it should be clearly understood that these examples of configurations of the impact tool 22 are not to be taken as limiting the
  • FIGS. 4-7 are intended to demonstrate that a wide variety of impact tool
  • valve or other flow restricting device 36 is used to periodically close off or restrict flow of the drilling fluid 38 through a passage extending
  • the device 36 could be provided as a spool valve, rotary valve, poppet valve or any other type of valve.
  • Operation of the device 36 is controlled by the controller 24, as described above.
  • Lines 44 are depicted in FIG. 4 for connecting the device 36 to the controller 24, but it should be understood that the controller could control operation of the device mechanically, hydraulically, electrically, optically, or in any other manner, in keeping with the principles of this disclosure .
  • the impact tool 22 is depicted as including a valve 46, a piston 48, a mass 50, a biasing device 52 and a shoulder 54.
  • the valve 46 is opened, thereby exposing the piston 48 to fluid pressure in the passage 40, and the piston displaces the mass 50 into contact with the shoulder 54.
  • the timing of the opening of the valve 46 is controlled by the controller 24, as described above.
  • the impact tool 22 is depicted as including a solenoid 56 which is used to displace the mass 50 into contact with the shoulder 54 to thereby produce the impact 30.
  • the timing of energizing the solenoid 56 is controlled by the controller 24, as described above.
  • the impact tool 22 is depicted as including a piezoelectric material 58 in the form of a stack of annular disks 60.
  • a piezoelectric material 58 in the form of a stack of annular disks 60.
  • the material distorts and thereby produces the impact 30.
  • the timing of applying the electrical potential across the piezoelectric material 58 is controlled by the controller 24, as described above.
  • FIG. 8 a schematic cross-sectional view of one configuration of the brake 17 which may be used in the system 10 is representatively illustrated.
  • a shaft 62 rotated by the mud motor 18 extends through the brake 17.
  • the shaft 62 is connected to the drill bit 16 below, whereby the mud motor 18 rotates the drill bit via the shaft.
  • the brake 17 is used to apply a braking force to the shaft 62, thereby decreasing the drill bit 16 rpm, when the azimuthal direction 32 of the drill bit axis 28c relative to the drill string axis 28a does not coincide with the desired azimuthal direction.
  • the braking force is released (or at least decreased) , thereby increasing the drill bit 16 rpm, when the azimuthal direction 32 of the drill bit axis 28c relative to the drill string axis 28a does coincide with the desired direction (or at least when the azimuthal direction of the drill bit axis is within a selected range of the desired direction).
  • the brake 17 includes an
  • controller could control operation of the device
  • the interface and power supply 64 Upon receiving an appropriate command from the controller 24, the interface and power supply 64 causes electrical power to be applied to a braking device 66, which in response applies a braking force to the shaft 62.
  • the braking device 66 could be any type of device which is capable of applying a variable braking force to the shaft 62.
  • the braking device 66 could comprise a magnetic brake which utilizes a magnetic field in
  • the braking force applied to the shaft 62 can be conveniently varied as desired.
  • other means of applying a braking force to the shaft 62 may be used, in keeping with the principles of this disclosure.
  • a rotational speed of the mud motor 18 could be varied by, for example, varying a flow rate of fluid through the motor, or varying fluid pressure applied to the motor.
  • a variable braking force could be applied mechanically, hydraulically, magnetically (as described above), or in any other manner.
  • the brake 17, mud motor 18, bend 20, impact tool 22, controller 24 and sensor assembly 26 are separately described above, any of these elements could be combined with any of the other elements, as desired.
  • the mud motor 18 could be provided with the bend 20 as a single assembly
  • the impact tool 22 and controller 24 could be provided as a single assembly
  • the brake 17 could be incorporated into the mud motor or bend
  • the mud motor 18 can be provided with the sensor assembly 26 for detecting when the drill bit axis 28c is pointing in the desired azimuthal direction relative to the drill string axis 28a, etc .
  • the drill bit 16 can be steered while the mud motor 18 rotates the drill bit, by increasing the rpm of the drill bit when an azimuthal direction 32 of its axis 28c is in a desired direction relative to an axis 28a of the drill string.
  • the increase in rotational speed of the drill bit 16 when its axis 28c is oriented in the desired azimuthal direction 32 (or within a selected range of the desired direction) causes the wellbore 12 to be preferentially drilled in the desired direction.
  • the impact tool 22 can be used to deliver the impact 30 to the drill bit 16 when its axis 28c is in the desired azimuthal direction 32 relative to the drill string axis 28a, to thereby enhance the steering of the drill bit in the desired direction.
  • the above disclosure provides to the art a method of steering a drill bit 16 while drilling a wellbore 12.
  • the method can include periodically increasing a rotational speed of the drill bit 16 while drilling the wellbore 12, with the rotational speed of the drill bit 16 being
  • the rotational speed of the drill bit 16 may be
  • the drill bit axis 28c preferably rotates about the drill string axis 28a while the rotational speed of the drill bit 16 varies.
  • the rotational speed of the drill bit 16 may be
  • the method can include periodically delivering an impact to the drill bit 16 as the drill bit is rotated.
  • the impact may be delivered by an impact tool 22 interconnected in the drill string 14.
  • the impact 30 is preferably
  • the desired azimuthal direction 32 of the drill bit axis 28c can be changed from a remote location. Changing the desired azimuthal direction 32 may be performed in part by transmitting a command from the remote location via a telemetry signal.
  • Increasing the rotational speed of the drill bit 16 can be performed by decreasing a braking force.
  • a directional drilling system 10 which can include a drill string 14 having a bend 20 interconnected therein, a drill bit 16, and a controller 24 which selectively increases a rotational speed of the drill bit 16 when an axis 28c of the drill bit 16 is oriented in a desired azimuthal direction 32 relative to an axis 28a of the drill string 14 above the bend 20.
  • the controller 24 may selectively decrease the
  • the controller 24 can selectively decrease the rotational speed of the drill bit 16 by selectively increasing a braking force applied to the drill string 14.
  • the controller 24 may selectively increase the
  • the controller 24 can selectively increase the rotational speed of the drill bit 16 by selectively decreasing a braking force applied to the drill string 14.
  • the system 10 can also include an impact tool 22 which delivers an impact 30 to the drill bit 16.
  • the impact tool 22 may deliver the impact 30 to the drill bit 16 when the axis 28c of the drill bit is oriented in the desired
  • At least one sensor 19, 26 interconnected in the drill string 14 may sense the azimuthal direction of the axis 28c of the drill bit 16 relative to the axis 28a of the drill string 14 above the bend 20.
  • the desired azimuthal direction 32 may be changeable from a remote location.
  • the desired azimuthal direction 32 may be changed in part by transmission of a command from the remote location to the controller 24 via a telemetry signal.
  • the method can include
  • the braking force may be decreased when an axis 28c of the drill bit 16 is oriented in a desired azimuthal
  • the desired azimuthal direction may be changed from a remote location, in some examples, at least in part by transmitting a command from the remote location via a telemetry signal.
  • a rotational speed of the drill bit 16 can be increased as a result of decreasing the braking force.
  • the rotational speed of the drill bit 16 may be increased while an axis 28c of the drill bit 16 is oriented in a desired azimuthal direction 32 relative to an axis 28a of the drill string 14, or at least while the axis 28c of the drill bit 16 is oriented within a selected range of the desired azimuthal direction 32.
  • the method can include periodically delivering an impact 30 to the drill bit 16 as the drill bit is rotated.
  • the impact 30 may be delivered by an impact tool 22
  • the impact 30 is preferably delivered to the drill bit 16 when an axis 28c of the drill bit 16 is oriented in a desired azimuthal

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (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)
  • Mechanical Engineering (AREA)
  • Earth Drilling (AREA)

Abstract

L'invention porte sur un procédé de direction d'une mèche de forage lors du forage d'un forage de puits, lequel procédé peut mettre en œuvre l'augmentation périodique d'une vitesse de rotation de la mèche de forage lors du forage du forage de puits, la vitesse de rotation étant accrue lorsqu'un axe de la mèche de forage est orienté dans une direction azimutale désirée par rapport à un axe de train de tiges de forage. Un système de forage directionnel peut comprendre un train de tiges de forage comportant une courbure interconnectée à l'intérieur de celui-ci, une mèche de forage, et un dispositif de commande qui accroît de façon sélective une vitesse de rotation de la mèche de forage lorsqu'un axe de la mèche de forage est orienté dans une direction azimutale désirée par rapport à un axe du train de tiges de forage au-dessus de la courbure. Un autre procédé de direction d'une mèche de forage lors du forage d'un forage de puits peut comprendre l'interconnexion d'un frein dans un train de tiges de forage, et la diminution périodique d'une force de freinage du frein lorsque l'on fait tourner la mèche de forage.
PCT/US2010/028498 2009-12-28 2010-03-24 Direction de mèche de forage à vitesse de rotation variable WO2011081673A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
US12/960,087 US20110155466A1 (en) 2009-12-28 2010-12-03 Varied rpm drill bit steering

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
USPCT/US2009/069609 2009-12-28
PCT/US2009/069609 WO2011081621A1 (fr) 2009-12-28 2009-12-28 Direction de mèche de forage à impact temporisé

Publications (1)

Publication Number Publication Date
WO2011081673A1 true WO2011081673A1 (fr) 2011-07-07

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ID=42306727

Family Applications (2)

Application Number Title Priority Date Filing Date
PCT/US2009/069609 WO2011081621A1 (fr) 2009-12-28 2009-12-28 Direction de mèche de forage à impact temporisé
PCT/US2010/028498 WO2011081673A1 (fr) 2009-12-28 2010-03-24 Direction de mèche de forage à vitesse de rotation variable

Family Applications Before (1)

Application Number Title Priority Date Filing Date
PCT/US2009/069609 WO2011081621A1 (fr) 2009-12-28 2009-12-28 Direction de mèche de forage à impact temporisé

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CA (2) CA2781353C (fr)
WO (2) WO2011081621A1 (fr)

Cited By (1)

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Publication number Priority date Publication date Assignee Title
US10202840B2 (en) 2014-01-02 2019-02-12 Shell Oil Company Steerable drilling method and system

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CN107246238B (zh) * 2017-08-01 2021-04-27 西南石油大学 一种一体化冲击井下动力钻具

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US20030024739A1 (en) * 1999-03-03 2003-02-06 Vermeer Manufacturing Company Method and apparatus for directional boring under mixed conditions
US20070137897A1 (en) * 2005-12-16 2007-06-21 Sanders Michael P Combined directional and impact drilling motor
US20090057018A1 (en) * 2007-08-31 2009-03-05 Precision Energy Services, Inc. Directional drilling control using modulated bit rotation
US20090260884A1 (en) * 2008-04-16 2009-10-22 Baker Hughes Incorporated Steering Device for Downhole Tools

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Publication number Priority date Publication date Assignee Title
EP0467642A3 (en) * 1990-07-17 1993-03-10 Camco Drilling Group Limited Earth drilling system and method for controlling the direction of a borehole
US5421420A (en) * 1994-06-07 1995-06-06 Schlumberger Technology Corporation Downhole weight-on-bit control for directional drilling
US6609579B2 (en) * 1997-01-30 2003-08-26 Baker Hughes Incorporated Drilling assembly with a steering device for coiled-tubing operations
US6659202B2 (en) * 2000-07-31 2003-12-09 Vermeer Manufacturing Company Steerable fluid hammer

Patent Citations (4)

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Publication number Priority date Publication date Assignee Title
US20030024739A1 (en) * 1999-03-03 2003-02-06 Vermeer Manufacturing Company Method and apparatus for directional boring under mixed conditions
US20070137897A1 (en) * 2005-12-16 2007-06-21 Sanders Michael P Combined directional and impact drilling motor
US20090057018A1 (en) * 2007-08-31 2009-03-05 Precision Energy Services, Inc. Directional drilling control using modulated bit rotation
US20090260884A1 (en) * 2008-04-16 2009-10-22 Baker Hughes Incorporated Steering Device for Downhole Tools

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10202840B2 (en) 2014-01-02 2019-02-12 Shell Oil Company Steerable drilling method and system

Also Published As

Publication number Publication date
CA2920421C (fr) 2018-09-04
CA2781353A1 (fr) 2011-07-07
CA2920421A1 (fr) 2011-07-07
WO2011081621A1 (fr) 2011-07-07
CA2781353C (fr) 2016-05-10

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