• 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:
    METHOD OF REDUCING AND APPLIANCE TO CONTROL A VIBRATION OF A DRILLING COLUMN IN A WELL HOLE. The present invention relates to a computer-readable method, apparatus and means for reducing the vibration of a drill string (120) in a well bore. A sensor (158a) of the drill string (120) takes one or more measurements of a vibration parameter. A processor (212) determines at least one force for controlling the measured vibration of the measured parameter. At least one driver applies at least one force against the well hole wall to control the vibration of the drill string (120).
    公开号:BR112014009094B1
    申请号:R112014009094-7
    申请日:2012-10-05
    公开日:2021-03-02
    发明作者:Olof Hummes；Matthias Meister；Sven Krueger；Bernd Santelmann；Michael Koppe
    申请人:Baker Hughes Incorporated；
    IPC主号:
    专利说明:

    Cross-reference to related orders
    [001] This application claims priority to US Provisional Patent Application Serial No. 61/547. 433, filed on October 14, 2011. Rationale
    [002] Drilling operations generally include a drill column driven through a well hole to a formation. A drill bit at a lower end of a drill string is operated to disintegrate the formation. Drilling the formation generally causes vibrations in the drill string, which can cause wear to the drill string, shorten the life of the drill string, impair the drilling efficiency and lead to a more rough cut of the formation. Accordingly, the present description provides a method and an apparatus for controlling vibrations in the drill string. Brief Description
    [003] In one aspect, the present description provides a method of reducing vibrations from a drilling column in a well bore, including: taking one or more measurements of a parameter of the drilling column vibration, and applying at least one force against a well hole wall in response to one or more measures taken to reduce the drill string vibration.
    [004] In another aspect, the present description provides an apparatus for controlling a vibration of a drilling column in a well bore, the apparatus including: a sensor configured to obtain one or more measurements of a vibration parameter, a processor configured to determine at least one force for controlling the measured vibration from the measured parameter; and at least one driver configured to apply at least one force against the well hole wall to control the vibration of the drill string.
    [005] In yet another aspect, the present description provides an apparatus for drilling a well hole, which includes a drilling column; a sensor configured to measure a parameter of a drill string vibration; a first driver configured to apply a first force component to drive a drill column control block; a second driver configured to apply a second force component to drive the command block; and a processor configured to: determine one or more forces to reduce the vibration of the drill string, and operate the first driver and the second driver cooperatively to apply one or more forces to the control block.
    [006] In yet another aspect, the present invention provides a computer-readable medium having a set of instructions stored therein and accessible to a processor to perform a method of vibration control of a drill string, the method comprising: receiving a measurement obtained related to a vibration of the drilling column; determine at least one force to control the detected vibration of the drilling column from the measurement obtained, and operate at least one drill column driver to apply at least one force against the well hole wall. Brief Description of Drawings
    [007] The following descriptions should not be considered as limiting in any way. With reference to the accompanying drawings, similar elements are numbered in the same way: Figure 1 is a schematic diagram of an exemplary drilling system that includes a drilling column having a drilling assembly connected to its lower end, which can be operated in a similar way. according to the exemplary methods described here; figure 2 shows an exemplary section of the downhole assembly of figure 1, to control the vibrations of the drilling column in an exemplary embodiment of the present invention; figure 3A shows an exemplary system for driving a control block of the exemplary drilling system to apply a force against the well wall, in an exemplary embodiment of the present invention; figure 3B shows an alternative system for activating a control block of the drilling system to apply a force against the well wall; figure 4A shows an exemplary vibration mode of a drill string; figure 4B shows an exemplary force sequence to compensate for the vibration mode of figure 4A; and figure 4C shows an exemplary amplitude of vibration resulting from the application of the force sequence of figure 4B to the vibration mode of figure 4A. Detailed Description
    [008] A detailed description of one or more modalities of the apparatus and method described are presented here by way of example and not of limitation with reference to the figures.
    [009] Figure 1 is a schematic diagram of an exemplary drilling system 100 that includes a drilling column having a drilling assembly connected to its lower end, which can be operated according to the exemplary apparatus and methods described herein. Figure 1 shows a drilling column 120 that includes a drilling set or downhole assembly ("BHA") 190 conducted in a well 126. The drilling system 100 comprises a conventional tower 111 erected on a platform or floor 112 which supports a rotary table 114, which is rotated by a main motor, such as an electric motor (not shown), at a desired rotation speed. A tube (such as a joined drill pipe) 122 having the drill assembly 190 attached at its lower end extends from the surface to the bottom 151 of well 126. A drill bit 150, connected to the drill assembly 190, disintegrates the geological formations when it is rotated to drill well 126. Drill column 120 is coupled to a winch 130 through a Kelly 121, ball joint 128 and line 129 through a pulley. Winch 130 is operated to control the weight on the bit ("WOB"). The drill column 120 can be rotated by an upper unit (not shown), instead of the primary motor and the rotary table 114. The operation of the winch 130 is known in the art and is therefore not described in detail here.
    [0010] In one aspect, an appropriate drilling fluid 131 (also referred to as "mud") from a source 132, such as a puddle of mud, is distributed under pressure through the drill column 120 by a mud pump 134 The drilling fluid 131 passes from the mud pump 134 in the drilling column 120 through a suction device 136 and the fluid line 138. The drilling fluid 131a from the tubular drilling discharges at the bottom of the well 151 through of openings in drill 150. The return of drilling fluid 131b circulates above the hole through the annular space 127 between drill column 120 and well 126 and returns to mud puddle 132 through a return line 135 and the screen drilling cutter 185 that removes drilling cuts 186 from the return drilling fluid 131b. An S1 sensor on line 138 provides information about the fluid flow rate. The surface torque sensor S2 and a sensor S3 associated with the drill column 120 provide information on the torque and rotation speed of the drill column 120. Penetration rate of the drill column 120 can be determined from the sensor S5, while the S6 sensor can provide the load for the drill string rope hook 120.
    [0011] In some applications, drill bit 150 is rotated by rotating drill pipe 122. However, in other applications, a downhole motor 155 (mud motor) disposed in drilling set 190 also rotates drill bit 150 The penetration rate ("ROP") for a given drill bit and BHA depends largely on WOB or the thrust force on the drill bit 150 and its speed of rotation.
    [0012] A surface control unit or controller 140 receives signals from sensors and downhole devices through a sensor 143 placed in fluid line 138 and signals from sensors S1 to S6 and other sensors used in system 100 and processes such signals according to programmed instructions provided from a program for the surface control unit 140. The surface control unit 140 displays the desired drilling parameters and other information on a screen / monitor 141 that is used by an operator to control drilling operations. The surface control unit 140 may be a computer-based unit, which may include a processor 142 (such as a microprocessor), a storage device 144, such as a solid-state, tape, or hard disk memory, and one or more computer programs 146 on storage device 144, which are accessible to processor 142 to execute the instructions contained in such programs for carrying out the methods described herein. Surface control unit 140 can communicate with more than one remote control unit 148. Surface control unit 140 can process data related to drilling operations, data from sensors and devices on the surface, and data received from the bottom of the well and can control one or more of the operations of the devices in the bottom of the well and on the surface. Alternatively, the methods described here can be performed on a downhole processor 172.
    [0013] The drilling set 190 also contains a section 165 having control blocks formed on it. The control blocks can be pivoted from the downhole assembly 190 to provide a stabilizing force for the downhole assembly within the downhole and / or drill column control during drilling. As discussed below, in an exemplary mode, the control blocks can be activated to dampen, control, reduce and / or improve vibration in the drill string. The drilling set 190 may further include a variety of sensors 158 to determine one or more functions and properties of the drilling set (such as speed, vibration, bending moment, acceleration, oscillations, turning, friction, etc.) and operating parameters drill bits, such as bit weight, fluid flow rate, pressure, temperature, penetration rate, azimuth, tool face, drill bit rotation, etc. In addition, drilling set 190 may also include one or more accelerometers 169 or equivalent devices to determine an orientation of the drill string in the well. The drilling set may further include communication devices for sending signals from and / or receiving signals from a surface location. The signals can include, in one aspect, the information obtained from the sensors 158 and the signals for the control of various operations at the bottom of the well. A suitable subtelemetry 180, using, for example, two-way telemetry, is also provided as illustrated in drilling set 190 and provides information from the various sensors and to the surface control unit 140.
    [0014] Still referring to figure 1, the drilling column 120 also includes energy conversion device 160. In one aspect, the energy conversion device 160 is located on BHA 190 to supply an electric current or energy, such as as current for sensors 158. The energy conversion device 160 may include a battery or an energy conversion device that can, for example, convert or harvest energy from drilling mud pressure waves that are received by and flow through drilling column 120 and BHA 190. Alternatively, a surface energy source can be used to power the various equipment at the bottom.
    [0015] Figure 2 shows an exemplary section 165 of the downhole assembly 190 to control the vibrations of the drill string in an exemplary embodiment of the present invention. Exemplary section 165 includes control blocks 202 arranged at one or more circumferential locations on BHA 190. Control blocks 202 are operated to apply a substantially radial force to a well wall. In one aspect, control blocks 202 apply a stabilizing force to maintain the drill string in a selected position within the well. In another aspect, the control blocks 202 can be driven independently to move the BHA longitudinal axis of the drill 190 out of a central position inside the well, thus providing the ability to orient the drill string during drilling. The control blocks 202 are coupled to the actuators of the control blocks 204A that actuate the control blocks to apply a first component of force against the well wall to carry out the stabilization and / or control aspects of the drilling column. The control blocks 202 are also coupled to the impulse actuators 204b that drive the control blocks 202 to apply a second force component against the well hole wall to control a vibration of the drill column using various methods discussed herein. In one embodiment, the control block actuators 204a and pulse actuators 204b can be used together to apply a force to control the vibration of the drill string. The applied force can be a combination or overlap of the first force and the second force. In this embodiment, one driver (i.e., 204a) can be operated at a first frequency (i.e., low) and the other driver (i.e., 204b) can be operated at a second frequency (i.e., high).
    [0016] BHA 190 includes a downhole sensor 158a, which is typically close to the drill bit (not shown) and which is configured to measure a parameter of a vibration in the drill column, such as a force or pressure . Although only one sensor 158a is shown in figure 2 for illustrative purposes, it is understood that more than one sensor can be used, as well as sensors that respond to different vibration parameters. The force or vibration can include vibrations, bends, acceleration, oscillations and vibrations due to turning, friction, etc. BHA 190 also includes a downhole control unit or controller 210 that receives signals from the downhole sensor and 206 processes such signals according to the instructions provided from a program for the downhole control unit. 210. The control unit along the bottom of the shaft 210 may be a computer-based unit, which may include a processor 212 (such as a microprocessor), a storage device 214, such as a solid-state memory, tape or hard disk, and one or more computer programs 216 on storage device 214, which are accessible to processor 212 to execute instructions contained in such programs for carrying out the methods described herein. The downhole control unit 210 communicates with actuators 204a and 204b to operate the control blocks 202. In one aspect, the downhole control unit 210 receives one or more measurement parameters related to the force and / or the drilling column vibration from sensor 158a and applies a signal to drive devices 204a and / or 204b to activate command block 202. Processor 212 receives one or more measurements obtained and determines a force that can be applied to a well wall in order to neutralize or decrease vibration. The downhole control unit 210 can communicate more signals to and receive signals from a surface location.
    [0017] In another mode, processor 212 determines a vibration mode of the drill string. The vibration mode can be determined using one or more measurements received from sensor 158a. For example, processor 212 can determine from one or more measurements that the drill string is vibrating in a lateral vibration mode. The processor 212 can then determine a sequence of forces that can be applied to the control block to counteract the vibrations of the side vibration mode. The processor can also determine various characteristics of the applied force, such as frequency, duration and magnitude. The processor can also determine a time interval associated with, for example, actuators, command blocks, and various other devices used for applying the force sequence. The time interval can be associated with the rotation of the drill string and can be selected to apply a force to a selected circumferential location of the borehole hole during the rotation of the drill string. The time interval can also include an inherent or calculated time interval for devices that apply at least one force. The time interval can also be a time interval calculated by a selected vibration mode. The processor can use the given time interval so that forces are applied at appropriate times. In one mode, the processor uses a forward model to determine the sequence of forces that will dampen a selected vibration mode. The forward model can use one or more sensor measurements and time intervals.
    [0018] Figure 3A shows an exemplary system 300 for activating the control block 202 to apply a force against the well wall, in an exemplary embodiment of the present invention. The exemplary system 300 in one embodiment is a hydraulic system, which includes a reservoir 302 of hydraulic fluid and a hydraulic drive circuit 304 to circulate the hydraulic fluid. The exemplary system 300 further includes a nozzle 306, a pressure sensor 314 and a pressure control valve 308. The nozzle 306 regulates the pressure of the hydraulic fluid in the system. The nozzle 306 can be a flow resistance nozzle in one embodiment. The hydraulic fluid coming from the nozzle 306 is directed to a control actuator 204a and / or impulse actuator 204b that is coupled to the control block 202. The actuators 204a and 204b move the control block 202 in response to changes in the pressure of the hydraulic fluid. The hydraulic fluid is returned from actuators 204a and 204b through pressure control valve 308. Pressure sensor 314 can be used to measure the pressure of the hydraulic fluid.
    [0019] Actuator 204a includes a housing 310a, which includes a plunger 312a and various devices for displacing the plunger in order to apply force to the control block 202. Similarly, the actuator 204b includes housing 310b which includes a plunger 312b and various apparatus for moving the plunger to apply a force to the control block 202 to compensate for the vibrations of the drill string. As described herein, actuators 204a and 204b are hydraulically activated. In several alternative embodiments, actuators 204a and 204b can be of any form of linear actuator, which includes a linear actuator, a spindle actuator, a pump actuator, a piezoelectric device, a solenoid and a magneto-restrictive device, a motor, an electric drive motor, and a hydraulic pump, among others. Typically, plunger 312b has less mass than plunger 312a and has a smaller radius than plunger 312a. The plunger 312a is designed according to the parameters that allow the application of the long-lasting strong force of the control block against the well hole wall for stabilization and / or control. The plunger 312b is designed according to the parameters that allow quick movement of the plunger for the application of a short-term force for vibration control. Thus, impulse actuator 204b and plunger 312b are normally selected for applying forces at a vibration frequency of the drill string. Typically, this frequency of vibration is in the range of about 0.010 Hertz (Hz) and about 10,000 Hz. In one embodiment, the plunger 312b can be designed with a small elongated plunger in combination with a solenoid that conducts from a reciprocal way to provide high pressure at low driving force and long stroke of the piston. In another embodiment, plunger 312b may include a plunger or diaphragm of increased diameter in combination with a piezoelectric driver. In one embodiment, the spindle plunger or other activation mechanism or high dynamic drive can be used to activate and control the control blocks. Such mechanisms usually have high dynamic control suitable for vibration control.
    [0020] In the exemplary embodiment of the present description, at least one control block can be moved or propelled in the radial direction, in order to provide a force directed against the wall of the well hole. The pulse can be of a selected duration, amplitude and / or frequency. Combined with a high frequency force and vibration measurement system, the control software can check the vibration pattern and actively push the inserts out to prevent the drill bit from entering a severe vibration mode, such as a turning mode, or to return the drill bit back to smooth rotation, that is, practically free from vibrations.
    [0021] Figure 3B shows an exemplary system 350 of an alternative modality for activating the control block to apply a force against the well wall. The exemplary system 350 includes a control actuator 204a and a pulse actuator 204b connected in series. Command actuator 204a includes housing 310a and plunger 312a which can be activated at a first frequency. Plunger 312a is coupled to pulse actuator 204a so that plunger actuation 312a moves pulse actuator 204a linearly. The impulse driver includes housing 310b and plunger 312b, which can be activated at a second frequency other than the first frequency. The plunger 312b is coupled to the control block 202, so that the actuation of the plunger 312b moves the control block 202 in a radial direction from the drill string. Command actuator 204a and impulse actuator 204b can be operated cooperatively to provide a force for the command block which is a combination of a first force of command actuator 204b and a second force of impulse actuator 204b. In various modalities, these first and second forces are periodically or semi-periodically applied.
    [0022] System 350 includes a hydraulic fluid reservoir, 302, 308a from the valve and pressure sensor 314a providing hydraulic fluid to the actuator 240a. The hydraulic drive circuit 304 circulates the hydraulic fluid in the entire hydraulic line 321. The nozzle 306 regulates the pressure of the hydraulic fluid in the hydraulic line 321. The second valve 308b and the second pressure sensor 314b are arranged in a section of the hydraulic line 321 between hydraulic drive circuit 304 and impulse driver 204b. The second valve 308b and the second pressure sensor 314b can be used to control driver 204b independently of driver 204a.
    [0023] Figure 4A shows an exemplary vibration mode of a drill string. Time is along the horizontal axis and the amplitude of vibration is along the vertical axis. The vibration mode has a repeated sequence. Vibration is measured by the exemplary sensor 158a and sent to the processor, which determines a force sequence that is programmed to dampen the vibration mode. An exemplary strength sequence is shown in figure 4B. Figure 4C shows an exemplary amplitude of vibration resulting from the application of the force sequence of figure 4B to the vibration of figure 4A. The methods described here for dampening vibrations, therefore, lead to a longer service life of a drilling set and / or drill string, less wear, improved drilling efficiency and smoother cutting.
    [0024] Therefore, in one aspect, the present description provides a method of reducing the vibration of a drilling column in a well bore, including: obtaining one or more measurements of a parameter of the vibration of the drilling column, and applying at least one force against the well hole wall in response to one or more measurements obtained to reduce the drill string vibration. In one embodiment, a single force is applied in response to a single measurement obtained. In another embodiment, the method also includes determining a vibration mode of the drill string using one or more measurements, determining a sequence of forces to reduce the vibrations of the determined vibration mode, and applying the determined sequence of forces against the wall of the borehole. The method includes applying at least one force from a time interval calculated to compensate for at least one of: (i) a rotation of the drill string in relation to the well hole wall, (ii) a time interval of one device to apply to at least one force, and (iii) a determined mode of vibration. The measurement vibrations can be entered for a forward model to determine the sequence of forces. In one aspect, the application of at least one force further comprises operating a first driver to apply a first force component and a second driver to apply a second force component to a drill column control block, wherein the at least one a force is a combination of the first force component and the second force component. At least one of the first driver and the second driver can be a linear drive motor, a spindle drive, a pump driver, a piezoelectric device, a solenoid, a magneto-restrictive device, a motor, an electric motor unit , and a hydraulic pump. The vibration in the drill string can be a forward swing, a drill swing back, a lateral vibration, a vibration of a drillhole shaft set, and a vibration in the drill string above the drill string. rock bottom, for example. The control block is normally operated at a frequency of about 0.010 Hz to 10,000 Hz.
    [0025] In another aspect, the present description provides an apparatus for controlling a vibration of a drilling column in a well bore, the apparatus including: a sensor configured to obtain one or more measurements of a vibration parameter, a processor configured to determine at least one force for controlling vibration measured from the measured parameter, and at least one driver configured to apply at least one force against the drilling wall to control the vibration of the drilling column. The processor in one mode is configured to determine a single force in response to a single measurement obtained. In another embodiment, the processor is further configured to determine a vibration mode for the drill string; determine a sequence of forces to control the determined vibration mode of the drill string, and provide a trigger signal for the actuator to apply the sequence of forces. The processor is further configured to calculate an additional time interval for activating at least one driver to compensate for at least one of: (i) a rotation of the drilling column in relation to the well hole wall, (ii) an inherent time interval of at least one driver, and (iii) a determined mode of vibration. The processor is also further configured to insert one or more measurements in a forward model to determine the sequence of forces. At least one driver can include a first driver configured to apply a first force component and a second driver configured to apply a second force component to a drill column control block, where at least one force is applied against the wall of the well bore is a combination of the first strength component and the second strength component. In several embodiments, the at least one driver can be a linear drive motor, a spindle driver, a pump driver, a piezoelectric device, a solenoid, a magneto-restrictive device, a motor, an electric motor unit and a hydraulic pump, for example. The vibration in the drill string can be a drill bit forward, a drill bit backwards, a side vibration, a vibration of a downhole assembly of the drill string, and a vibration in the drill string above the downhole set. At least one trigger is configured to move the control block at a frequency of about 0.010 Hz to about 10,000 Hz.
    [0026] In yet another aspect, the present invention provides an apparatus for drilling a well bore, which includes a drill string; a sensor configured to measure a parameter of a drilling column vibration, a first driver configured to apply a first force component to drive a drill column control block, a second driver configured to apply a second force component to drive a command block, and a processor configured to: determine one or more forces to reduce the vibration of the drill string, and operate the first driver and the second driver cooperatively to apply one or more forces to the command block.
    [0027] In yet another aspect, the present disclosure provides a computer-readable medium having a set of instructions stored there and accessible to a processor to perform a method of vibration control of a drill string, the method comprising: receiving a measurement obtained in relation to a vibration of the drilling column; determine at least one force to control the detected vibration of the drill string from the measurement obtained, and perform at least one actuation of the drill string to apply at least one force against the well hole wall.
    [0028] Although the invention has been described with reference to an exemplary modality, or modalities, it should be understood by those skilled in the art that various changes can be made and equivalents can be replaced by elements of these without departing from the scope of the invention. In addition, many modifications can be made to adapt a particular situation or particular material to the teachings of the invention without departing from its essential scope. Therefore, it is intended that the invention is not limited to the particular modality described as the best mode considered for the realization of this invention, but that the invention includes all modalities that fall within the scope of the claims. In addition, in the drawings and in the description, examples of modalities of the invention have been described and, although specific terms may have been used, they are except where indicated used in a generic and descriptive sense and not for the purpose of limitation, the scope of the invention therefore, don't be so limited. In addition, the use of the terms first, second, etc. it does not denote any order of importance, but the terms first, second, etc. are used to distinguish one element from another. In addition, the use of the terms one, one, etc. it does not denote a quantity limitation, but instead denotes the presence of at least one referenced item.
    权利要求:
    Claims (9)
    [0001]
    1. A method of reducing the vibration of a drilling column (120) in a well hole, comprising: coupling a first driver (204a) and a second driver (204b) to a control block (202) of the drilling column ( 120), in which the first driver (204a) and the second driver (204b) are driven by a hydraulic fluid flowing in a hydraulic circuit (304); and obtaining one or more measurements of a parameter of the vibration of the drill string (120); the method characterized by: driving the hydraulic fluid to activate the first driver (204a) and the second driver (204b) to apply a first force and a second force, respectively, on the control block (202) against a well hole wall responsive to one or more measurements obtained, where the first driver (204a) applies the first force at a first frequency and the second driver (204b) applies the second force at a second frequency different from the first frequency and a combination of the first force and the second force reduces the vibration of the drill string (120).
    [0002]
    2. Method, according to claim 1, characterized by the fact that it still comprises applying the first force and the second force in response to a single measurement obtained.
    [0003]
    3. Method, according to claim 1, characterized by the fact that it still comprises: determining a mode of vibration of the drilling column (120) using one or more measurements; determine a sequence of forces to reduce vibrations in the determined mode of vibration; and applying the sequence of forces determined against the well hole wall.
    [0004]
    4. Method, according to claim 1, characterized by the fact that it still comprises applying the first force and the second force in a time interval calculated to compensate for at least one of: (i) a rotation of the drilling column (120 ) in relation to the well hole wall; (ii) a time interval for a device to apply at least the first force and the second force; and (iii) a determined mode of vibration.
    [0005]
    5. Method according to claim 1, characterized by the fact that at least one of the first driver (204a) and the second driver (204b) is selected from the group consisting of: (i) a linear drive motor ; (ii) a spindle unit; (iii) a pump driver; (iv) a piezoelectric device; (v) a solenoid; (vi) a magnetostrictive device; (vii) an engine; (viii) an electric motor unit; and (ix) a hydraulic pump.
    [0006]
    6. Apparatus for controlling a vibration of a drilling column (120) in a well bore, comprising: a sensor (158) configured to obtain one or more measurements of a vibration parameter; the apparatus characterized by: a processor (142) configured to determine at least one force to control the measured vibration from the measured parameter; a closed hydraulic circuit (304) having a hydraulic fluid itself which is conducted through the circuit (304); a first driver (204a) coupled to a control block (202) of the drilling column (120) configured to be activated by a pressure from the hydraulic fluid to apply a first force having a first frequency in the control block (202) against the well hole wall; a second driver (204b) coupled to the control block (202) of the drilling column (120) configured to be driven by the pressure of the hydraulic fluid to apply a second force having a second frequency different from the first frequency in the control block (202) against the borehole wall, where a combination of the first force and the second force controls the vibration of the drill string (120).
    [0007]
    Apparatus according to claim 6, characterized by the fact that the processor (142) is configured to determine the first force and the second force in response to a single measurement obtained.
    [0008]
    8. Apparatus according to claim 6, characterized by the fact that the processor (142) is further configured to: determine a mode of vibration of the drill string (120); determining a sequence of forces to control the determined vibration mode of the drill string (120); and providing a trigger signal for the first driver (204a) and the second driver (204b) to apply the sequence of forces.
    [0009]
    9. Apparatus according to claim 8, characterized by the fact that the processor (142) is further configured to calculate a time interval for the activation of the first driver (204a) and the second driver (204b) to compensate at least one of: (i) a rotation of the drilling column (120) in relation to the well hole wall; (ii) an inherent time interval of at least one between the first trigger (204a) and the second trigger (204b); and (iii) a determined mode of vibration.
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    同族专利:
    公开号 | 公开日
    NO20140137A1|2014-02-17|
    GB2510753A|2014-08-13|
    BR112014009094A2|2017-04-18|
    US9273522B2|2016-03-01|
    US20130092441A1|2013-04-18|
    GB2510753B|2019-04-03|
    GB201408300D0|2014-06-25|
    WO2013055590A4|2013-06-13|
    WO2013055590A1|2013-04-18|
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    法律状态:
    2018-12-11| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|
    2019-11-12| B06U| Preliminary requirement: requests with searches performed by other patent offices: suspension of the patent application procedure|
    2020-12-15| B09A| Decision: intention to grant|
    2021-03-02| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 05/10/2012, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US201161547433P| true| 2011-10-14|2011-10-14|
    US61/547,433|2011-10-14|
    PCT/US2012/058954|WO2013055590A1|2011-10-14|2012-10-05|Steering head with integrated drilling dynamics control|
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