• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    tilting drill rotary airship drilling system. the present invention relates to a well formed by an apparatus that can include an axle having an end part, a tiltable drill body around the end part, and at least one driver configured to apply a tilt force to the drill body.
    公开号:BR112013001409B1
    申请号:R112013001409-1
    申请日:2011-07-21
    公开日:2020-02-11
    发明作者:Andreas Peter；Johannes Witte；Michael Koppe；Joachim Treviranus
    申请人:Baker Hughes Incorporated；
    IPC主号:
    专利说明:

    DESCRIPTION REPORT OF THE APPLIANCE FOR FORMING A WELL IN AN UNDERGROUND FORMATION AND METHOD OF FORMING A WELL IN AN UNDERGROUND FORMATION.
    DESCRIPTION FIELD [001] This description refers, in general, to oilfield downhole tools. Specifically, the drilling assemblies used for directional well drilling.
    Background of the Technique [002] To obtain hydrocarbons such as oil and gas, the holes or wells when drilled by rotation of a drill fixed to the bottom of a drilling assembly (here also referred to as a Bottom Drilling Assembly or (BHA). The drill assembly is attached to the bottom end of a pipe, which is usually either an articulated rigid pipe or a relatively flexible pipe that can be coiled commonly referred to in the art as coiled pipe. The column comprising the pipe and the drilling assembly is usually referred to as the drill string. When the articulated pipe is used as the pipe, the drill bit is rotated by rotating the articulated pipe from the surface and / or by a mud motor contained in the drilling assembly. the drill is rotated by the mud motor. During drilling, a drilling fluid (also referred to as the mud) under pressure to the pipeline. The drilling fluid stops through the drilling assembly and then discharges to the bottom of the distaff. The drilling fluid provides lubrication for the drill and transports pieces of disintegrated rock to the surface by the drill bit when drilling the well. The mud motor is rotated by the drilling fluid that passes through the drilling assembly. A drive shaft connected to the motor and the drill rotate the drill.
    Petition 870190091735, of 9/13/2019, p. 5/28
    2/16 [003] A substantially proportion of current drilling activity involves bypass drilling and horizontal wells to fully exploit hydrocarbon reservoirs. Such holes can have relatively complex well profiles. The present description addresses the need for steering devices to drill such wells as well as wells for other applications such as geothermal wells, as well as other needs in the prior art.
    SUMMARY OF DESCRIPTION [004] In aspects, this description provides an apparatus for forming a well in an underground formation. The apparatus may include an axle having an end part, a tiltable drill body around the end part, and at least one actuator configured to apply tilt force to the drill body. One or more components of the device can be modular.
    [005] In aspects, the present description provides a method for forming a well in an underground formation. The method may include forming the well using an apparatus that may include an axle having an end part, a tiltable drill body around the end part, and at least one actuator configured to apply a tilt force to the drill.
    [006] Examples of certain characteristics of the description have been summarized rather broadly so that the detailed description of the following can be better understood and so that the contributions they represent to the technique are appreciated. Of course, there are additional features of the description which will be described below and which will form the subject of the attached claims.
    Brief Description of the Drawings [007] For a detailed understanding of this description, reference should be made to the following detailed description of the drawings
    Petition 870190091735, of 9/13/2019, p. 6/28
    3/16 dalities, taken in combination with the attached drawings, in which the similar elements received similar numbering, in which:
    [008] Figure 1 illustrates a drilling system made according to an embodiment of the present description;
    [009] Figure 2 schematically illustrates a steering device made according to an embodiment of the present description that uses a tiltable drill;
    [0010] Figure 3 illustrates a change of direction associated with an inclination generated by a steering device made in accordance with a modality of the present description;
    [0011] Figures 4 and 5 functionally illustrate modalities of the steering systems made in accordance with modalities of the present description; and [0012] Figure 6 schematically illustrates a mode of operation of a steering device made in accordance with an embodiment of the present description.
    DETAILED DESCRIPTION OF THE DESCRIPTION [0013] As will be appreciated from the comment below, aspects of this description provide a rotatable steering system for drilling poles. In general, the described steering methodology may involve tilting the angle of the drill's geometric axis with respect to the tool's geometric axis by tilting a drill body. In some embodiments, the drill bit can be tilted by using an actuator assembly that applies a tilting force to the bit. To compensate for the drill rotation, the shape can be applied sequentially to a specified azimuth or circular location on the drill to create a geostationary slope; that is, a slope that consistently points the bit in a desired drilling direction even when the wheel turns. As will be clear from the comment
    Petition 870190091735, of 9/13/2019, p. 7/28
    4/16 downstream, the steerable rotary systems according to the present description can be interpreted in such a way that the drill, which may include relatively high wear components, can be readily disconnected from the actuator assembly. Therefore, the actuator assembly can be subjected to less wear during operation. In some embodiments, the actuator assembly may be modular in nature to facilitate repair or replacement of the steering system. In addition, the features that enable the drill tilt are positioned within the drill itself. Since the distance between the drill face and the center point of deviation is relatively small (for example, perhaps half the length of the drill), the actuator assembly may require less energy and need to generate less force than conventional steering systems for orient the drill. Other desirable characteristics will also be commented on below.
    [0014] Referring now to Figure 1, there is shown an illustrative embodiment of a steering system 10 that uses an airship drilling assembly or bottom drilling assembly (BHA) 12 to directionally drill a well 14. Although an land probe, these concepts and methods are equally applicable to offshore drilling systems. System 10 may include a drill column 16 suspended from a probe 20. Drill column 16, which may be joined tubular or coiled tubing, may include power and / or data conductors such as wires to provide bidirectional communication and transmission of data. energy. In one configuration, BHA 12 includes a steerable assembly 100 that includes a drill bit 200, a sub 32 sensor, bidirectional communication and a power module (BCPM) 34, an assessment formation (FE) sub 36, and power devices rotary motors such as 38 drill motors. The sub 32 sensor can include sensors for measuring direction
    Petition 870190091735, of 9/13/2019, p. 8/28
    5/16 next to the drill (for example, BHA azimuth and slope, BHA coordinates, etc.) and sensors and tools for making rotary directional assessments. The tilt devices near the drill can include three (3) accelerometers with geometry axis and signal processing circuits. The system may also include information processing devices such as a surface controller 50 and / or a downhole controller 42. The drill 200 of the steering assembly 100 can be rotated by rotating the drill column 16 and / or by use of a 38 drill motor, or other suitable rotary power source. The communication between the surface and the BHA 12 can use uplink connections and / or downlink connections generated by a mud-powered alternator, a sludge and / or transported using wires (for example, electrical conductors, optical fibers), acoustic signals, EM or RF.
    [0015] Figure 2 illustrates a directional assembly sectorally
    100 to directionally drill a well in an underground formation. The steering assembly 100 includes a tilt drill 200 that can be guided by an actuator assembly 300. Referring now to Figures 2 and 3, for guidance, it means that the actuator assembly 300 can cause a specific angular deviation 105 between a drill geometry axis 102 and tool geometry axis 104. Geometry axes 102, 104 are generally aligned with the longitudinal geometry axis of the well (not shown). This angular deviation causes a drill face 201 to point to the desired drilling direction. The drill face 201 is generally the surface of the drill 200 that engages a lower part of the well (not shown). As used herein, the term inclines generally refers to an angular deviation 105. In addition, as will be discussed in more detail below, the actuator assembly 300 maintains the angular deviation in a geostationary condition.
    Petition 870190091735, of 9/13/2019, p. 9/28
    6/16 [0016] Referring to Figure 2, in one embodiment, drill bit 200 may include a drill body 202 which is coupled to a drill shaft 204. Drill shaft 204 can be secured to drill body 202 with a connector 206. An annular opening 207 separates at least part of the drill shaft 204 and the connector 206. The opening 207 provides the space for tilting the drill body 202. The drill shaft 204 can have an end 212 which is configured to connect to a housing or sub 301 associated with actuator assembly 300. For example, end 212 may have a threaded point. In some embodiments, the actuator assembly 300 can be considered to be selectively connected to the drill bit 200 in which the drill bit 200 can be removed from housing 301 without disassembling or otherwise reaching the actuator assembly 300. It should be noted that the tilt occurs around a support structure 214 positioned within the drill body 202. The drill shaft 204 can be considered as a universal type, a Cardan joint, a joint using elastomeric members, or any other suitable joint to transmit torque although being able to withstand a large articulation angle. In one configuration, the torque transmission elements 216, which may be spherical members, rotationally lock drill shaft 204 for drill body 202. Therefore, drill shaft 204 and drill body rotate together. In a conventional manner, drilling fluid is supplied to drill bit 200 via a hole 218. The drilling fluid is ejected from drill body 202 through passages 220 to cool and lubricate drill face 201 and wash the cuts downhole drilling hole as drill face 201 cuts the bottom of the well. Since the drilling fluid is at a relatively high pressure, the sealing elements can be used to prevent the drilling fluid from invading the inside of the drill body 202. For example, seals 222 can be used
    Petition 870190091735, of 9/13/2019, p. 10/28
    7/16 to provide a fluid-tight seal, or lubricant-containing chamber, around a region 224 that includes the engagement surfaces of the drill shaft 204 and the drill body 202. Region 224 can be filled with grease, oil or other suitable liquid to lubricate the region and minimize contamination by drilling fluids or other undesirable materials.
    [0017] Referring now to Figures 2 and 4, in one embodiment, the actuator assembly 300 may include actuators 302 that are arranged circularly in sub 301. Although three actuators 302 are illustrated, a greater or lesser number may be used of actuators 302. In an illustrative arrangement, actuator 302 may include a force application member 304, a piston assembly 306, a valve 308 and a pump 310. The force application member 304 may be a rigid member such as a rod that engages and applies a tilt force to face 226 of connector 206. As used herein, the term tilt force refers to a force applied to a specified azimuth location in the drill body 202 that drives the drill body 202 to tilt in a desired direction. In the described modalities, the force can be an axial force, but in other modalities, the force does not need to be aligned with the geometric axis 104. Therefore, for example, a weight in the drill generated by the drill string is not an inclination force because the force is preferably not applied to a specific azimuth location in the drill body 202. The contact parts on the force application member 304 and the face 226 can be hardened or strengthened. For example, interlocking surfaces can be hardened using techniques such as carburizing and nitriding. In addition, materials such as PDC can be used. For example, the end of the force application member 304 may include compact polycrystalline diamond (PDC) cutters, a wear-resistant material that includes granule Petition 870190091735, 9/13/2019, pg. 11/28
    8/16 lo of tungsten carbide, etc.
    [0018] The force application member 304 can be hydraulically driven using pump 310, valve 308 and piston assembly 306. Piston assembly 306 can include a piston head 311 that translates into a cylinder or chamber 312. In one arrangement, pump 310 delivers pressurized hydraulic fluid via valve 308 to chamber 312 in which piston head 311 is arranged. The valve 308 can be controlled to pulse or otherwise control the fluid into chamber 312 to obtain a geostationary tilt angle.
    [0019] In one arrangement, a controller 314 can be operatively coupled to valve 308 to control one or more aspects of fluid flow in and / or out of chamber 312 to obtain a geostationary tilt angle. For example, the controller can activate (for example, open or close) valve 308 based on the rotational speed of drill 202. In some embodiments, valve 308 can be activated once per drill revolution. In other modalities, activation can occur once for two revolutions or another fractional amount that allows the angle of inclination to remain generally geostationary. Controller 314 can be configured to filter, sort, decimate, digitize or otherwise process data, and include suitable PCL's. For example, the processor may include one or more microprocessors that use a computer program implemented in a computer-readable medium that enables the processor to perform control and processing. The computer-readable medium can include ROMs, EPROMs, EAROMs, Flash memories and optical discs. Controller 314 can be controller 42 of Figure 1 or a separate controller.
    [0020] When the pressurized fluid enters chamber 312, piston head 311 and force member 304 are driven
    Petition 870190091735, of 9/13/2019, p. 12/28
    9/16 axially driven to drill 202. In some embodiments, a baseline polarizing force can be generated in chamber 312 using pressurized fluid and / or a polarizing element (not shown) such as a spring. In cases where the force application member 304 is hydraulically driven, the sealing elements can be used to prevent leakage of pressurized hydraulic fluid. For example, seals 318 such as o rings can be positioned on piston head 311, sealing cleaners 320 can be arranged on the stem portion of the force applying member 304, and a metal or rubber membrane 322 can be positioned on an opening from which the force application member 304 is projected.
    [0021] In some modalities, the member applying force
    304 crosses a circular opening 318 that separates the housing 301 and the connector 206. The width of the opening 316 can be a factor that controls the magnitude or severity of the inclination of the drill body 202. To control the inclination of the drill, a shoulder 230 in drill body 202. Shoulder 230 may extend partially through aperture 316 to reduce the effective width of the aperture and therefore limit the magnitude of the inclination. In some embodiments, the shoulder 230 can be adjustable.
    [0022] In certain modalities, the actuator assembly
    200 and / or actuators 302 can be modular in nature. In one aspect, the term modular refers to a standardized structural configuration that has generic or universal coupling interfaces that enable a component to be interchangeable within the well tool. An illustrative module may include force application member 304, piston assembly 306, valve 308, and pump 310. These components can be packaged in a unitary housing that can be arranged to be removed in the
    Petition 870190091735, of 9/13/2019, p. 13/28
    10/16 housing 302. Another illustrative module can include only the 308 valves or just the 310 pump (s). Therefore, if a d = component fails or needs maintenance, a replacement component can be inserted instead. inside the drill assembly. In another aspect, the term module refers to a component available as a plurality of modules. Each module can have a standardized housing to be interchangeable although it is also functionally or operationally different from each other (for example, each module has a different operating setpoint or different operating range and / or performance characteristics). For example, force application members 304 may have different strokes or pumps 310 may have different operating pressure values. Therefore, as a change in drilling dynamics, the component module that has proper operating or realization characteristics for optimal drilling efficiency is inserted into the well drilling assembly.
    [0023] In some embodiments, steering device 100 may use one or more sensors 110, 32 to control drill 200 and actuator assembly 300. The sensors can be used to assess a position, orientation, operating status of the body drill bit 202, force application member 304, valve 308, pump 310, or any other component or device of steering device 100. For example, a sensor 112 can be used to evaluate the width of the opening 316 and a sensor 114 can be used to determine a position of piston head 311 and / or force application member 304. Illustrative sensors include, but are not limited to, ultrasonic sensors, capacitive sensors, and piezoelectric elements. Sensors 110 may also include sensors 32 (Figure 1) that provide directional information.
    [0024] It should be understood that numerous can be used
    Petition 870190091735, of 9/13/2019, p. 14/28
    11/16 arrangements for moving the force application member 304. For example, valve 308 can be formed as a static nozzle element that allows fluid to flow above a pressure limit valve. In such an arrangement, controller 314 can be operatively coupled to pump 310, which can be an adjustable speed pump. Therefore, controller 314 can increase the speed of pump 310 to increase the pressure of the pump. Speed increases can be periodic in nature to pulse fluid into chamber 312 at the desired frequency.
    [0025] Referring now to Figure 5, another arrangement for the steering system 300 is illustrated. In the arrangement illustrated, actuator 302 may include a force application member 304, a piston assembly 306, valves 332, and a common pump 330. Common pump 330 delivers pressurized fluid to valves 332 controlled by controller 314. In this embodiment, controller 314 can be programmed to control valves 332 as needed to maintain a geostationary drill tilt. Several different pump configurations can be used to supply hydraulic power; for example, radial piston pumps, axial piston pumps, swashplate pumps, etc. Still other modalities can use a non-hydraulic system. For example, the actuator assembly may use electromechanical systems that include, but are not limited to, spindle units, linear motors, and materials responsive to electrical current (for example, piezoelectric materials).
    [0026] Hydraulic systems can be energized using drilling column rotation, high pressure drilling fluid, a downhole electric power generator, a downhole battery, and / or an energy supplied from the surface. Similarly, the electrical energy for these systems can be generated at the bottom of the well, supplied from a battery at the bottom of the well, and / or supplied from the ground.
    Petition 870190091735, of 9/13/2019, p. 15/28
    12/16 surface. Referring now to figures 1 and 4, for example, bidirectional data communication and power module (BCPM) 34 can be used to supply electrical energy for the actuator assembly 300. In addition, BCPM 34 can be used to transmit control signals between controller 314 and the surface.
    [0027] Referring to Figure 6, a cross-sectional view of the drill bit 200 that can be tilted using three actuators arranged circularly 302 is schematically illustrated. The drill bit 200 is illustrated in a direction 350. Referring now to Figures 2 and 6, it is desired to drill along the axis 104, that is, without deviation, then all actuators 302 are energized in such a way that all force application members 304 engage connector 206. Sensor 112 can evaluate the inclination of the drill head 202. If necessary, controller 314 can adjust one or more of actuators 302 to balance or control the axial forces applied to have a substantially zero slope. For example, controller 314 can increase or decrease the fluid supplied to the piston (s) to hold drill body 202 in a zero-tilt orientation.
    [0028] It is desirable to drill in a specific direction 352, so the controller operates actuators 302 to apply axial force to drill 200 to tilt drill 200 in the specified direction 352. As previously mentioned, drill 200 is turning in direction 350. Therefore , in one mode, controller 314 (Figure 4) can activate actuator 302 in an azimuthal sector 354 that is opposite the direction of drilling 352. This activation can be a signal to valve 308 that opens valve 308 to inject pressurized fluid in chamber 3122. In response, piston head 311 displaces force member 304 against connector 206. Once actuator 302 leaves azimuthal sector 354, the fluid pressure in chamber 312 is released or
    Petition 870190091735, of 9/13/2019, p. 16/28
    13/16 reduced to a lower pressure value. This loss of pressure allows the piston head 311 and the force applying member 304 to slide back due to the weight on the distaff and the contact of the bit against the formation. In a variant, controller 314 (Figure 4) can activate two or more actuators 302 to generate a resulting axial force in the azimuth sector 354. Therefore, each actuator 202 is activated as it rotates to the appropriate position and then is deactivated at as the actuator 202 rotates out of the proper position. That is, actuators 202 are activated sequentially to continuously apply a tilting force to an appropriate azimuth location.
    [0029] In another mode, controller 314 (Figure 4) can activate only actuator 302 that is in the same azimuthal sector of drilling direction 352. This activation can be a signal to valve 308 that opens valve 308 to release fluid pressurized from chamber 312. In response, piston head 311 allows the force applying member 34 to reduce the force applied to connector 206. Once connector 302 leaves azimuth sector 354, the fluid pressure in chamber 314 increases to a desired pressure value. As before, controller 314 (/ figure 4) can activate two or more actuators 302 to obtain a resulting tilt force.
    [0030] It should be understood that the drill can rotate at speeds of one hundred RPM or greater. Therefore, actuators 302 can be activated for a period in the order of a second or a fraction of a second. However, as the axial force is always applied in or near the azimuthal sector 354, the inclination is geostationary.
    [0031] In another mode of operation, the magnitude of the drilling direction can also be controlled. In the example described above, actuators 302 move the drill body 202 from a zero tilt orientation to a maximum tilt orientation. Actuator assembly 300 can also be configured to position or
    Petition 870190091735, of 9/13/2019, p. 17/28
    14/16 orient drill 202 at a tilt value that is immediate from zero tilt and maximum tilt. In such an arrangement, controller 314 can operate actuators 302 to restrict the travel of the force application member 304 to less than the maximum travel or to apply a force that is less than a maximum force. Therefore, drill body 202 may not be tilted to the maximum value. The stroke may be limited by modulating or reducing the volume or pressure of a fluid applied to piston head 311, physically preventing movement of the force limiter 304, or some other method.
    [0032] Referring now to Figures 1, 2 and 4, in an exemplary way of use, BHA is transported to well 14 from device 20. During drilling of well 14, steering device 100 directs drill column 16 in a selected direction. The drilling direction can follow a pre-set path that is programmed into a surface and / or downhole controller (for example, controller 50 and / or controller 42). Controller (s) 50 and / or 42 use directional data received from directional downhole sensors 32 to determine the orientation of BHA 12. If a stroke correction is required, controller 314 transmits signals to valves 308 and pumps 310 to move the force members to tilt the drill body 202 in the desired direction. In addition, these signals can also control the magnitude of the slope. In another exemplary use, surface personnel transmit signals to controller 314 to direct drill column 16 in the desired direction. And yet another exemplary use, geological direction can be performed using the sensors in sub FE 36. These sensors can include sensors to assess gamma ray emissions, temperature, various propagations of resistivity, sensors to determine parameters of interest related to the force
    Petition 870190091735, of 9/13/2019, p. 18/28
    15/16 masonry, holes, geophysical faces, hard fluids and adjacent conditions. Formation assessment sensors (eg resistivity, dielectric, constant, water saturation, porosity, density and permeability), sensors for measuring hole parameters (eg hole size, hole roughness, true vertical depth, depth measurement), sensors to measure geophysical parameters (for example, acoustic speed time and acoustic path). In an automated, semi-automated or controlled surface manner, BHA 12 can be addressed with respect to one or more specified formation or reservoir characteristics.
    [0033] When desired, BHA 12 can be pushed out of the well. If desired, drill bit 200 can be removed from BHA 12 at the bottom of the apparatus. It should be noted that the removal of the drill bit 200 can be performed by disconnecting the drill bit 200 from the alo 301. Other components, for example, the actuator assembly 300, can remain on the BHA 12. In addition, the separation of the drill bit 200, or the selected components of drill 200, can be performed with standard equipment and apparatus bottom.
    [0034] From the above, it should be appreciated that what has been described includes, in part, an apparatus for forming a well in an underground formation. The apparatus may include an axle having an end part, a drill body that can be tilted around an end part, and at least one actuator configured to apply a tilting force to the drill body.
    [0035] From the above, it should be appreciated that what has been described also includes, in part, a method for forming a well in an underground formation. The method may include forming the well using an apparatus that may include an axle having an end part, a tiltable drill body around the end part, and at least one actuator configured to apply force
    Petition 870190091735, of 9/13/2019, p. 19/28
    16/16 tilt for the drill body.
    [0036] Although the foregoing description is directed to certain modalities of the description, several modifications will be apparent to those skilled in the art. All variations are intended to be within the scope of the appended claims encompassed in the foregoing description.
    权利要求:
    Claims (16)
    [1]
    1. Apparatus for forming a well in an underground formation using a drilling column (16), characterized by comprising:
    an axis having an end portion, the axis being configured to be arranged in the drill string (16);
    a joint coupled to the end portion, wherein the joint includes a hole for carrying a drilling fluid;
    a drill bit (200), the drill bit (200) having a drill bit body (202) and a drill face (201) configured to cut the downhole, the drill bit (200) disposed of including the drill bit (202) includes at least one passage in communication with the joint hole, at least one passage ejecting the drilling fluid into the face of the drill, where the shaft passes through a circumferential gap that separates the drill string (16) and the drill bit (200) and where the joint is inside the drill bit (200) and between the circumferential gap and the face of the drill; and at least one actuator (300) configured to generate a tilt force to tilt the drill bit (200).
    [2]
    2. Apparatus according to claim 1, characterized by the fact that the at least one actuator (300) includes a force application member (304); and further comprises a connector (206) limiting the end part between the circumferential gap and the drill face (201), wherein the connector (206) is separated from the drill bit body (202) with an annular clearance, in that the force applying member (304) engages a face of the connector (206) to apply the tilting force to the drill bit body (202).
    [3]
    3. Apparatus according to claim 1, characterized by the fact that at least one actuator (300) is positioned on the
    Petition 870190091735, of 9/13/2019, p. 21/28
    2/4 drilling column (16), and that the at least one actuator (300) includes a pump (304) for supplying pressurized fluid; a piston assembly (306) energized by the pressurized fluid; and a valve (308) configured to control the flow of fluid between the pump (304) and the piston assembly (306).
    [4]
    4. Apparatus, according to claim 1, characterized by the fact that at least one actuator (300) is energized using an energy source selected from one of: (i) pressurized fluid, and (ii) electrical energy .
    [5]
    5. Apparatus according to claim 1, characterized in that the at least one actuator (300) is configured to apply the tilting force as a function of a rotational speed of the drill bit body (202).
    [6]
    6. Apparatus according to claim 1, characterized by the fact that it additionally comprises a controller (314) operably coupled to at least one actuator (300), in which the controller (314) is programmed to maintain a geostationary inclination of the drill bit body (202).
    [7]
    7. Apparatus according to claim 6, characterized by the fact that it additionally comprises a rotating energy source that rotates the drill bit body (202), the controller (314) being programmed to operate the at least one actuator ( 300) based on a rotation speed of the drill bit body (202).
    [8]
    8. Apparatus according to claim 1, characterized by the fact that the at least one actuator (300) includes a plurality of actuators and further comprises a controller (314) operationally coupled to the plurality of actuators, the controller (314) being programmed to sequentially activate the plurality of actuators.
    Petition 870190091735, of 9/13/2019, p. 22/28
    3/4
    [9]
    9. Apparatus, according to claim 1, characterized by the fact that the joint is selected from one of: (i) universal joint, (ii) a Cardan joint; and (iii) joint with an elastomeric member.
    [10]
    10. Apparatus, according to claim 1, characterized by the fact that it also comprises:
    a housing (301) that receives the shaft and at least one actuator (300), in which the circumferential clearance separates the housing (301) from the drill bit (200), the circumferential clearance being configured to allow a predetermined degree of inclination for the drill bit (200) and where the joint is positioned between the circumferential gap and the drill face (201); and at least one torque transmitting element positioned in an interior region of the drill bit (200), the at least one torque transmitting element connecting the joint to the drill bit (200).
    [11]
    11. Apparatus according to claim 1, characterized by the fact that it also comprises at least one torque transmitting element positioned in an inner region of the bit, the at least one torque transmitting element connecting the joint to the bit.
    [12]
    12. Method of forming a well in an underground formation, characterized by comprising:
    arranging a joint within a drill bit body (202), the joint being positioned at an end portion of an axis;
    connect the shaft to a housing (301) positioned on a drill string (16), where the shaft passes through a circumferential gap that separates the housing (301) and the drill bit body, and where the joint is positioned between circumferential clearance and
    Petition 870190091735, of 9/13/2019, p. 23/28
    4/4 the drill face of the drill bit body (202);
    form the well using the drilling column (16); and controlling the drilling direction of the drill face (201) by tilting the drill bit body (202) around the end portion by applying a tilt force generated by at least one actuator.
    [13]
    13. Method, according to claim 12, characterized by the fact that it further comprises positioning the at least one actuator (300) inside the drilling column (16), in which the at least one actuator (300) includes a pump ( 304), a piston assembly (306), and a valve (308), and further comprises:
    energize the piston assembly (306) using pressurized fluid from the pump (304); and controlling fluid flow between the pump (304) and the piston assembly (306) using the valve (308).
    [14]
    14. Method according to claim 12, characterized by the fact that the at least one actuator includes a plurality of actuators and further comprises sequentially driving the plurality of actuators using a programmed controller (314).
    [15]
    15. Method according to claim 12, characterized in that it further comprises applying the tilt force as a function of a rotational speed of the drill body (202).
    [16]
    16. Method according to claim 12, characterized in that it additionally comprises maintaining a geostatic inclination of the drill bit body (202) using a programmed controller (314) that is operably coupled to at least one actuator ( 300).
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    公开号 | 公开日
    US20120018225A1|2012-01-26|
    BR112013001409A2|2016-05-24|
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    GB2511291A|2014-09-03|
    NO20130113A1|2013-02-14|
    NO346073B1|2022-02-07|
    US9145736B2|2015-09-29|
    GB201301163D0|2013-03-06|
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    法律状态:
    2016-09-20| B08F| Application dismissed because of non-payment of annual fees [chapter 8.6 patent gazette]|Free format text: REFERENTE A 3A ANUIDADE. |
    2017-01-03| B08G| Application fees: restoration [chapter 8.7 patent gazette]|
    2018-12-26| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|
    2019-07-16| B06T| Formal requirements before examination [chapter 6.20 patent gazette]|
    2019-12-24| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|
    2020-02-11| B16A| Patent or certificate of addition of invention granted [chapter 16.1 patent gazette]|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 21/07/2011, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US36645310P| true| 2010-07-21|2010-07-21|
    US61/366,453|2010-07-21|
    US13/187,199|2011-07-20|
    US13/187,199|US9145736B2|2010-07-21|2011-07-20|Tilted bit rotary steerable drilling system|
    PCT/US2011/044831|WO2012012624A1|2010-07-21|2011-07-21|Titled bit rotary steerable drilling system|
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