CA2781353C - Timed impact drill bit steering - Google Patents
Timed impact drill bit steering Download PDFInfo
- Publication number
- CA2781353C CA2781353C CA2781353A CA2781353A CA2781353C CA 2781353 C CA2781353 C CA 2781353C CA 2781353 A CA2781353 A CA 2781353A CA 2781353 A CA2781353 A CA 2781353A CA 2781353 C CA2781353 C CA 2781353C
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- drill bit
- axis
- impact
- drill
- drill string
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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
- 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 DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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 DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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 DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
Abstract
A method of steering a drill bit while drilling a wellbore can include periodically delivering an impact to the drill bit as the drill bit is rotated by a drill string. The impact may be delivered to the drill bit when an axis of the drill bit is oriented in a desired azimuthal direction relative to an axis of the drill string. Another method of steering a drill bit while drilling a wellbore may include interconnecting a bend in a drill string between an impact tool and the drill bit, and periodically delivering an impact from the impact tool to the drill bit as the drill bit is rotated by the drill string. A directional drilling system can include a drill string having a bend interconnected therein, an impact tool, and a drill bit, the bend being interconnected in the drill string between the drill bit and the impact tool.
Description
TIMED IMPACT DRILL BIT STEERING
TECHNICAL FIELD
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 timed impact drill bit steering.
BACKGROUND
It is frequently desirable to drill a wellbore in a selected direction, for example, to steer toward a hydrocarbon reservoir, or to steer away from a fault or a water zone (although in some circumstances, such as geothermal and conformance operations, it may be desirable to steer toward a fault or water zone). Therefore, it will be appreciated that improvements are needed in the art of steering a drill bit to thereby drill a wellbore in a desired direction.
TECHNICAL FIELD
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 timed impact drill bit steering.
BACKGROUND
It is frequently desirable to drill a wellbore in a selected direction, for example, to steer toward a hydrocarbon reservoir, or to steer away from a fault or a water zone (although in some circumstances, such as geothermal and conformance operations, it may be desirable to steer toward a fault or water zone). Therefore, it will be appreciated that improvements are needed in the art of steering a drill bit to thereby drill a wellbore in a desired direction.
- 2 -BRIEF DESCRIPTION OF THE DRAWINGS
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 relationships of axes of a drill string in the system and method of FIG. 1.
FIG. 3 is a schematic depiction of an azimuthal direction of a drill bit axis relative to a drill string axis.
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.
DETAILED DESCRIPTION
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 principles of this disclosure can be effectively used for steering a drill bit, and for thereby drilling a wellbore in a desired direction.
As depicted in FIG. 1, 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) also rotates the drill bit 16, whereby the drill bit cuts into the earth to drill the wellbore 12.
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 relationships of axes of a drill string in the system and method of FIG. 1.
FIG. 3 is a schematic depiction of an azimuthal direction of a drill bit axis relative to a drill string axis.
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.
DETAILED DESCRIPTION
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 principles of this disclosure can be effectively used for steering a drill bit, and for thereby drilling a wellbore in a desired direction.
As depicted in FIG. 1, 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) also rotates the drill bit 16, whereby the drill bit cuts into the earth to drill the wellbore 12.
- 3 -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. Thus, 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.
A bend 20 is also interconnected in the drill string 14. Although not perceptible in FIG. 1, the bend 20 provides a small (e.g., approximately 1.5 degree) deviation in a longitudinal axis of the drill string 14. The bend 20 is of the type well known to those skilled in the art, which 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).
Indeed, 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). However, this disclosure provides for steering the drill bit 16 when the drill string 14 is rotated and the mud motor 18 is not used for rotating the drill bit in response to flow of drilling fluid through the mud motor.
Interconnected in the drill string 14 above the mud motor 18 is an impact tool 22. The impact tool 22 delivers timed periodic impacts to the drill bit 16 as described more fully below. The timing of the impacts is controlled by a controller 24, which is in communication with a sensor assembly 26, and which can be remotely operable (e.g., from the surface) via various forms of wired and wireless telemetry.
A bend 20 is also interconnected in the drill string 14. Although not perceptible in FIG. 1, the bend 20 provides a small (e.g., approximately 1.5 degree) deviation in a longitudinal axis of the drill string 14. The bend 20 is of the type well known to those skilled in the art, which 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).
Indeed, 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). However, this disclosure provides for steering the drill bit 16 when the drill string 14 is rotated and the mud motor 18 is not used for rotating the drill bit in response to flow of drilling fluid through the mud motor.
Interconnected in the drill string 14 above the mud motor 18 is an impact tool 22. The impact tool 22 delivers timed periodic impacts to the drill bit 16 as described more fully below. The timing of the impacts is controlled by a controller 24, which is in communication with a sensor assembly 26, and which can be remotely operable (e.g., from the surface) via various forms of wired and wireless telemetry.
- 4 -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 an azimuthal direction of the drill bit 16 relative to the longitudinal axis of the drill string above the bend 20.
Referring additionally now to 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 purposes.
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, and 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.
It will be appreciated that 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.
Note that, although the 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,
Referring additionally now to 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 purposes.
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, and 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.
It will be appreciated that 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.
Note that, although the 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,
- 5 -deviated, inclined relative to vertical, etc. The terms "above," "below" and similar directional terms are used for convenience to refer to positions relative to proximal and distal ends of the drill string 14. For example, the axis 28a is "above" the bend 20, in that it is nearer the proximal end of the drill string 14 (e.g., closer to the surface), and 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 is 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 is directed both along the axis 28a of the drill string 14 above the bend 20, and along the axis 28c of the drill string and drill bit 16 below the bend. This arrangement provides advantages to the system 10 as described more fully below.
Referring additionally now to 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.
As the drill string 14 rotates, the azimuthal direction 32 of the drill bit axis 28c relative to the drill string axis 28a also rotates (as indicated by arrow 34 in FIG. 3).
In one important feature of the system 10, the impact tool 22 delivers the impact 30 to the drill bit 16 when (and preferably only when) the azimuthal direction 32 of the
The impact tool 22 is 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 is directed both along the axis 28a of the drill string 14 above the bend 20, and along the axis 28c of the drill string and drill bit 16 below the bend. This arrangement provides advantages to the system 10 as described more fully below.
Referring additionally now to 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.
As the drill string 14 rotates, the azimuthal direction 32 of the drill bit axis 28c relative to the drill string axis 28a also rotates (as indicated by arrow 34 in FIG. 3).
In one important feature of the system 10, the impact tool 22 delivers the impact 30 to the drill bit 16 when (and preferably only when) the azimuthal direction 32 of the
- 6 -drill bit axis 28c relative to the drill string axis 28a is in a desired direction.
For example, if it is desired to steer the drill bit 16 in an azimuthal direction of 30 degrees relative to the drill bit axis 28a, then 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 bit 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.
Preferably, 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 principles of this disclosure.
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, and preferably based on commands, data, instructions, etc. received from a remote location (such as the surface) via telemetry. Any form of telemetry may be used, for example, wired or wireless telemetry.
Wireless telemetry may include acoustic, electromagnetic, pressure pulse (positive and/or negative), pipe manipulation, etc. Wired telemetry may be via conductors
For example, if it is desired to steer the drill bit 16 in an azimuthal direction of 30 degrees relative to the drill bit axis 28a, then 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 bit 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.
Preferably, 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 principles of this disclosure.
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, and preferably based on commands, data, instructions, etc. received from a remote location (such as the surface) via telemetry. Any form of telemetry may be used, for example, wired or wireless telemetry.
Wireless telemetry may include acoustic, electromagnetic, pressure pulse (positive and/or negative), pipe manipulation, etc. Wired telemetry may be via conductors
- 7 -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 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 principles of this disclosure to the depicted examples.
Instead, the examples depicted in FIGS. 4-7 are intended to demonstrate that a wide variety of impact tool configurations are possible in keeping with the principles of this disclosure.
In FIG. 4, the impact tool 22 is depicted in a configuration in which a 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 longitudinally through the impact tool. When the flow of the drilling fluid 38 is restricted by the device 36, the momentum of the fluid is converted to a force transmitted as the impact 30 through an outer housing 42 of the impact tool 22.
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 principles of this disclosure to the depicted examples.
Instead, the examples depicted in FIGS. 4-7 are intended to demonstrate that a wide variety of impact tool configurations are possible in keeping with the principles of this disclosure.
In FIG. 4, the impact tool 22 is depicted in a configuration in which a 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 longitudinally through the impact tool. When the flow of the drilling fluid 38 is restricted by the device 36, the momentum of the fluid is converted to a force transmitted as the impact 30 through an outer housing 42 of the impact tool 22.
- 8 -The device 36 could be provided as a spool valve, rotary valve, poppet valve or any other type of valve.
However, it is not necessary for flow of the fluid 38 to be entirely prevented in order for the impact 30 to be generated, since a sufficient change in momentum of the fluid through the passage 40 could result from substantially restricting (rather than entirely preventing) the flow of the fluid.
Operation of the device 36 (for example, the timing of the restriction to flow of the fluid 38 through the passage 40) 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.
In FIG. 5, 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. When the impact 30 is to be delivered to the drill bit 16, 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.
In FIG. 6, 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.
In FIG. 7, the impact tool 22 is depicted as including a piezoelectric material 58 in the form of a stack of
However, it is not necessary for flow of the fluid 38 to be entirely prevented in order for the impact 30 to be generated, since a sufficient change in momentum of the fluid through the passage 40 could result from substantially restricting (rather than entirely preventing) the flow of the fluid.
Operation of the device 36 (for example, the timing of the restriction to flow of the fluid 38 through the passage 40) 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.
In FIG. 5, 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. When the impact 30 is to be delivered to the drill bit 16, 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.
In FIG. 6, 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.
In FIG. 7, the impact tool 22 is depicted as including a piezoelectric material 58 in the form of a stack of
- 9 -annular disks 60. When an electrical potential is applied across the piezoelectric material 58, 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.
Although the 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. For example, 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 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 mud motor 18 in conjunction with the bend 20 may be used for directional drilling when the drill string 14 is not being rotated, which is known to those skilled in the art as directional drilling in sliding mode. Thus, although the mud motor 18 is not necessary for directional drilling when the drill string 14 is being rotated and the impact tool 22 is being used to deliver the impact 30 to the drill bit 16, its presence in the drill string is useful in that it provides the capability of directional drilling in sliding mode, if desired.
It may now be fully appreciated that the above disclosure provides several advancements to the art of steering a drill bit and directional drilling of a wellbore.
In particular, the drill bit 16 can be steered while rotating the drill string 14 by delivering an impact 30 to the drill bit when an azimuthal direction 32 of its axis 28c is in a desired direction relative to an axis 28a of the
Although the 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. For example, 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 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 mud motor 18 in conjunction with the bend 20 may be used for directional drilling when the drill string 14 is not being rotated, which is known to those skilled in the art as directional drilling in sliding mode. Thus, although the mud motor 18 is not necessary for directional drilling when the drill string 14 is being rotated and the impact tool 22 is being used to deliver the impact 30 to the drill bit 16, its presence in the drill string is useful in that it provides the capability of directional drilling in sliding mode, if desired.
It may now be fully appreciated that the above disclosure provides several advancements to the art of steering a drill bit and directional drilling of a wellbore.
In particular, the drill bit 16 can be steered while rotating the drill string 14 by delivering an impact 30 to the drill bit when an azimuthal direction 32 of its axis 28c is in a desired direction relative to an axis 28a of the
- 10 -drill string. The impact 30 being delivered to the drill bit 16 when its axis 28c is oriented in the desired azimuthal direction 32 causes the wellbore 12 to be preferentially drilled 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 delivering an impact 30 to the drill bit 16 as the drill bit is rotated by a drill string 14, and the impact 30 being delivered to the drill bit 16 when an axis 28c of the drill bit is oriented in a desired azimuthal direction 32 relative to an axis 28a of the drill string 14.
The impact 30 can be directed along the drill string axis 28a and along the drill bit axis 28c.
The drill bit axis 28c preferably rotates about the drill string axis 28a while the impact 30 is delivered to the drill bit 16.
The impact 30 may be delivered to the drill bit 16 only when the drill bit axis 28c is oriented in the desired azimuthal direction 32 relative to the drill string axis 28a.
A bend 20 may be interconnected between the drill bit 16 and an impact tool 22 which produces the impact 30. A
mud motor 18 may be interconnected between the impact tool 22 and the bend 20.
Periodically delivering the impact 30 to the drill bit 16 can be performed by, for example, periodically restricting flow of fluid 38 through the drill string 14, periodically displacing a mass 50 with a piston 48, periodically displacing a mass 50 by energizing a solenoid 56, or periodically energizing a piezoelectric material 58.
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 delivering an impact 30 to the drill bit 16 as the drill bit is rotated by a drill string 14, and the impact 30 being delivered to the drill bit 16 when an axis 28c of the drill bit is oriented in a desired azimuthal direction 32 relative to an axis 28a of the drill string 14.
The impact 30 can be directed along the drill string axis 28a and along the drill bit axis 28c.
The drill bit axis 28c preferably rotates about the drill string axis 28a while the impact 30 is delivered to the drill bit 16.
The impact 30 may be delivered to the drill bit 16 only when the drill bit axis 28c is oriented in the desired azimuthal direction 32 relative to the drill string axis 28a.
A bend 20 may be interconnected between the drill bit 16 and an impact tool 22 which produces the impact 30. A
mud motor 18 may be interconnected between the impact tool 22 and the bend 20.
Periodically delivering the impact 30 to the drill bit 16 can be performed by, for example, periodically restricting flow of fluid 38 through the drill string 14, periodically displacing a mass 50 with a piston 48, periodically displacing a mass 50 by energizing a solenoid 56, or periodically energizing a piezoelectric material 58.
- 11 -Periodically delivering the impact 30 to the drill bit 16 may include detecting the azimuthal direction 32 of the drill bit axis 28c relative to the drill string axis 28a utilizing a sensor assembly 26 interconnected in the drill string 14.
The method can include changing the desired azimuthal direction 32 of the drill bit axis 28c 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.
Also provided by the above disclosure is a method of steering a drill bit 16 while drilling a wellbore 12, which method can include: interconnecting a bend 20 in a drill string 14 between an impact tool 22 and the drill bit 16, and periodically delivering an impact 30 from the impact tool 22 to the drill bit 16 as the drill bit is rotated by the drill string 14.
A directional drilling system 10 is also described above. The system 10 can include a drill string 14 having a bend 20 interconnected therein, an impact tool 22, and a drill bit 16. The bend 20 is preferably interconnected in the drill string 14 between the drill bit 16 and the impact tool 22.
The impact tool 22 can deliver an impact 30 to the drill bit 16, with the impact 30 being directed along an axis 28c of the drill bit 16. The impact tool 22 may deliver the impact 30 to 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.
A sensor assembly 26 interconnected in the drill string 14 may sense an azimuthal direction 32 of an axis 28c of the
The method can include changing the desired azimuthal direction 32 of the drill bit axis 28c 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.
Also provided by the above disclosure is a method of steering a drill bit 16 while drilling a wellbore 12, which method can include: interconnecting a bend 20 in a drill string 14 between an impact tool 22 and the drill bit 16, and periodically delivering an impact 30 from the impact tool 22 to the drill bit 16 as the drill bit is rotated by the drill string 14.
A directional drilling system 10 is also described above. The system 10 can include a drill string 14 having a bend 20 interconnected therein, an impact tool 22, and a drill bit 16. The bend 20 is preferably interconnected in the drill string 14 between the drill bit 16 and the impact tool 22.
The impact tool 22 can deliver an impact 30 to the drill bit 16, with the impact 30 being directed along an axis 28c of the drill bit 16. The impact tool 22 may deliver the impact 30 to 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.
A sensor assembly 26 interconnected in the drill string 14 may sense an azimuthal direction 32 of an axis 28c of the
- 12 -drill bit 16 relative to an axis 28a of the drill string 14.
A controller 24 may cause the impact tool 22 to deliver an impact 30 to the drill bit 16 in response to the azimuthal direction 32 of the drill bit axis 28c being at a desired azimuthal direction. The desired azimuthal direction 32 may be changed from a remote location.
It is to be understood that the various embodiments of the present disclosure described herein may be utilized in various orientations, such as inclined, inverted, horizontal, vertical, etc., and in various configurations, without departing from the principles of the present disclosure. The embodiments are described merely as examples of useful applications of the principles of the disclosure, which is not limited to any specific details of these embodiments.
Of course, a person skilled in the art would, upon a careful consideration of the above description of representative embodiments of the disclosure, readily appreciate that many modifications, additions, substitutions, deletions, and other changes may be made to the specific embodiments, and such changes are contemplated by the principles of the present disclosure. Accordingly, the foregoing detailed description is to be clearly understood as being given by way of illustration and example only, the spirit and scope of the present invention being limited solely by the appended claims and their equivalents.
A controller 24 may cause the impact tool 22 to deliver an impact 30 to the drill bit 16 in response to the azimuthal direction 32 of the drill bit axis 28c being at a desired azimuthal direction. The desired azimuthal direction 32 may be changed from a remote location.
It is to be understood that the various embodiments of the present disclosure described herein may be utilized in various orientations, such as inclined, inverted, horizontal, vertical, etc., and in various configurations, without departing from the principles of the present disclosure. The embodiments are described merely as examples of useful applications of the principles of the disclosure, which is not limited to any specific details of these embodiments.
Of course, a person skilled in the art would, upon a careful consideration of the above description of representative embodiments of the disclosure, readily appreciate that many modifications, additions, substitutions, deletions, and other changes may be made to the specific embodiments, and such changes are contemplated by the principles of the present disclosure. Accordingly, the foregoing detailed description is to be clearly understood as being given by way of illustration and example only, the spirit and scope of the present invention being limited solely by the appended claims and their equivalents.
Claims (27)
1. A method of steering a drill bit while drilling a wellbore, the method comprising:
delivering a single impact for each rotation of the drill bit via an impact tool as the drill bit is rotated, the impact being delivered to the drill bit when a longitudinal axis of the drill bit is oriented in a desired azimuthal direction relative to a longitudinal axis of a drill string, wherein the drill bit axis is angularly offset from the drill string axis and the drill bit axis rotates around the drill string axis, wherein the impact tool is interconnected in the drill string and a bend is interconnected between the drill bit and the impact tool, and wherein a mud motor is interconnected between the impact tool and the bend.
delivering a single impact for each rotation of the drill bit via an impact tool as the drill bit is rotated, the impact being delivered to the drill bit when a longitudinal axis of the drill bit is oriented in a desired azimuthal direction relative to a longitudinal axis of a drill string, wherein the drill bit axis is angularly offset from the drill string axis and the drill bit axis rotates around the drill string axis, wherein the impact tool is interconnected in the drill string and a bend is interconnected between the drill bit and the impact tool, and wherein a mud motor is interconnected between the impact tool and the bend.
2. The method of claim 1, wherein the impact is directed along the drill string axis and along the drill bit axis.
3. The method of claim 1, wherein the delivering further comprises permitting fluid flow from an internal flow passage of the impact tool into an exterior of the impact tool.
4. The method of claim 1, wherein the delivering further comprises displacing a mass which is disposed between an internal flow passage of the impact tool and an exterior of the impact tool.
5. The method of claim 4, wherein the delivering further comprises displacing the mass by energizing a solenoid.
6. A method of steering a drill bit while drilling a wellbore, the method comprising:
delivering a single impact for each rotation of the drill bit as the drill bit is rotated by a drill string, the impact being delivered to the drill bit when a longitudinal axis of the drill bit is oriented in a desired azimuthal direction relative to a longitudinal axis of the drill string, wherein the drill bit axis is longitudinally offset from the drill string axis and the drill bit axis rotates around the drill string axis, and wherein the impact is produced by energizing a piezoelectric material, wherein the impact tool is interconnected in the drill string and a bend is interconnected between the drill bit and the impact tool, and wherein a mud motor is interconnected between the impact tool and the bend.
delivering a single impact for each rotation of the drill bit as the drill bit is rotated by a drill string, the impact being delivered to the drill bit when a longitudinal axis of the drill bit is oriented in a desired azimuthal direction relative to a longitudinal axis of the drill string, wherein the drill bit axis is longitudinally offset from the drill string axis and the drill bit axis rotates around the drill string axis, and wherein the impact is produced by energizing a piezoelectric material, wherein the impact tool is interconnected in the drill string and a bend is interconnected between the drill bit and the impact tool, and wherein a mud motor is interconnected between the impact tool and the bend.
7. The method of claim 1, wherein the delivering further comprises detecting the azimuthal direction of the drill bit axis relative to the drill string axis utilizing a sensor assembly.
8. The method of claim 1, further comprising changing the desired azimuthal direction of the drill bit axis from a remote location.
9. The method of claim 8, wherein the changing is performed in part by transmitting a command from the remote location via a telemetry signal.
10. A method of steering a drill bit while drilling a wellbore, the method comprising:
interconnecting a bend in a drill string between an impact tool and the drill bit, whereby a longitudinal axis of the drill bit is angularly offset from a longitudinal axis of the drill string, and the drill bit axis rotates around the drill string axis;
interconnecting the impact tool in the drill string and interconnecting a mud motor between the impact tool and the bend; and during steering of the drill bit, for each rotation of the drill bit delivering a single impact from the impact tool to the drill bit based on a desired azimuthal orientation of the drill bit axis relative to the drill string axis.
interconnecting a bend in a drill string between an impact tool and the drill bit, whereby a longitudinal axis of the drill bit is angularly offset from a longitudinal axis of the drill string, and the drill bit axis rotates around the drill string axis;
interconnecting the impact tool in the drill string and interconnecting a mud motor between the impact tool and the bend; and during steering of the drill bit, for each rotation of the drill bit delivering a single impact from the impact tool to the drill bit based on a desired azimuthal orientation of the drill bit axis relative to the drill string axis.
11. The method of claim 10, wherein the impact is delivered to the drill bit when the drill bit is oriented in a desired azimuthal direction relative to the drill string axis.
12. The method of claim 11, further comprising changing the desired azimuthal direction of the drill bit axis from a remote location.
13. The method of claim 12, wherein the changing is performed in part by transmitting a command from the remote location via a telemetry signal.
14. The method of claim 10, wherein the impact is directed along the drill string axis and along the drill bit axis.
15. The method of claim 10, wherein the delivering further comprises displacing a mass which is reciprocally disposed within a wall of an outer housing of the impact tool.
16. The method of claim 10, wherein the impact is delivered to the drill bit only when the drill bit axis is oriented in a desired azimuthal direction relative to the drill string axis.
17. The method of claim 10, wherein the delivering further comprises permitting fluid flow from the internal flow passage into the outer housing of the impact tool.
18. The method of claim 15, wherein the mass comprises a piston.
19. The method of claim 15, wherein the delivering further comprises displacing the mass by energizing a solenoid.
20. The method of claim 10, wherein the delivering further comprises detecting an azimuthal direction of the drill bit axis relative to the drill string axis utilizing a sensor assembly interconnected in the drill string.
21. A directional drilling system, comprising:
a drill string having a bend interconnected therein;
an impact tool interconnected in the drill string and having a wall disposed between an internal flow passage of the impact tool and an exterior of the impact tool;
a reciprocating mass disposed within the wall, wherein an impact is delivered to the drill bit in response to displacement of the reciprocating mass;
a drill bit, the bend being interconnected in the drill string between the drill bit and the impact tool; and a drill motor, the drill motor being interconnected in the drill string between the impact tool and the bend, wherein a longitudinal axis of the drill bit is angularly offset from a longitudinal axis of the drill string, and the drill bit axis rotates around the drill string axis, wherein the impact tool delivers the impact to the drill bit in response to a longitudinal axis of the drill bit being at a desired azimuthal direction relative to a longitudinal axis of the drill string.
a drill string having a bend interconnected therein;
an impact tool interconnected in the drill string and having a wall disposed between an internal flow passage of the impact tool and an exterior of the impact tool;
a reciprocating mass disposed within the wall, wherein an impact is delivered to the drill bit in response to displacement of the reciprocating mass;
a drill bit, the bend being interconnected in the drill string between the drill bit and the impact tool; and a drill motor, the drill motor being interconnected in the drill string between the impact tool and the bend, wherein a longitudinal axis of the drill bit is angularly offset from a longitudinal axis of the drill string, and the drill bit axis rotates around the drill string axis, wherein the impact tool delivers the impact to the drill bit in response to a longitudinal axis of the drill bit being at a desired azimuthal direction relative to a longitudinal axis of the drill string.
22. The system of claim 21, wherein the impact is directed along the drill bit axis.
23. The system of claim 21, wherein the impact tool delivers the impact to the drill bit when the drill bit axis is oriented in a desired azimuthal direction relative to the drill string axis.
24. The system of claim 21, wherein a sensor assembly interconnected in the drill string senses the azimuthal direction of the drill bit axis relative to the drill string axis.
25. The system of claim 24, wherein a controller causes the impact tool to deliver the impact to the drill bit.
26. The system of claim 25, wherein the desired azimuthal direction is changed from a remote location.
27. The system of claim 25, wherein the impact comprises a single impact delivered for each rotation of the drill bit as the drill bit is rotated by the drill string.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA2920421A CA2920421C (en) | 2009-12-28 | 2009-12-28 | Timed impact drill bit steering |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| PCT/US2009/069609 WO2011081621A1 (en) | 2009-12-28 | 2009-12-28 | Timed impact drill bit steering |
Related Child Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2920421A Division CA2920421C (en) | 2009-12-28 | 2009-12-28 | Timed impact drill bit steering |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2781353A1 CA2781353A1 (en) | 2011-07-07 |
| CA2781353C true CA2781353C (en) | 2016-05-10 |
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| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2781353A Active CA2781353C (en) | 2009-12-28 | 2009-12-28 | Timed impact drill bit steering |
| CA2920421A Expired - Fee Related CA2920421C (en) | 2009-12-28 | 2009-12-28 | Timed impact drill bit steering |
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| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2920421A Expired - Fee Related CA2920421C (en) | 2009-12-28 | 2009-12-28 | Timed impact drill bit steering |
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| CA (2) | CA2781353C (en) |
| WO (2) | WO2011081621A1 (en) |
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|---|---|---|---|---|
| GB2536379B (en) | 2014-01-02 | 2017-03-22 | Shell Int Research | Steerable drilling method and system |
| CN107246238B (en) * | 2017-08-01 | 2021-04-27 | 西南石油大学 | Integrated impact downhole power drilling tool |
Family Cites Families (8)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| AU8044091A (en) * | 1990-07-17 | 1992-01-23 | Camco Drilling Group Limited | A drilling system and method for controlling the directions of holes being drilled or cored in subsurface formations |
| 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 |
| US6439319B1 (en) * | 1999-03-03 | 2002-08-27 | Earth Tool Company, L.L.C. | Method and apparatus for directional boring under mixed conditions |
| US6659202B2 (en) * | 2000-07-31 | 2003-12-09 | Vermeer Manufacturing Company | Steerable fluid hammer |
| US20070137897A1 (en) * | 2005-12-16 | 2007-06-21 | Sanders Michael P | Combined directional and impact drilling motor |
| US7766098B2 (en) * | 2007-08-31 | 2010-08-03 | Precision Energy Services, Inc. | Directional drilling control using modulated bit rotation |
| US8360172B2 (en) * | 2008-04-16 | 2013-01-29 | Baker Hughes Incorporated | Steering device for downhole tools |
-
2009
- 2009-12-28 CA CA2781353A patent/CA2781353C/en active Active
- 2009-12-28 WO PCT/US2009/069609 patent/WO2011081621A1/en active Application Filing
- 2009-12-28 CA CA2920421A patent/CA2920421C/en not_active Expired - Fee Related
-
2010
- 2010-03-24 WO PCT/US2010/028498 patent/WO2011081673A1/en active Application Filing
Also Published As
| Publication number | Publication date |
|---|---|
| CA2920421A1 (en) | 2011-07-07 |
| CA2920421C (en) | 2018-09-04 |
| CA2781353A1 (en) | 2011-07-07 |
| WO2011081621A1 (en) | 2011-07-07 |
| WO2011081673A1 (en) | 2011-07-07 |
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