Abstract: The invention relates to a rotary drive arrangement for a drill rod having an outer pipe and an inner rod running at least in sections inside the outer pipe, in particular for double-head and/or overburden drilling, with a first gearbox for driving the inner rod in a rotating manner and a second gearbox for driving the outer pipe in a rotating manner, wherein the first gearbox and the second gearbox are independent of each other. According to the invention provision is made in that the first gearbox and the second gearbox are supported in a common gearbox housing and are surrounded by the same.

Abstract: A method for protecting an electrical interface in an oil well environment, the method providing the deposition/application of a metallic layer onto a thermoplastic substrate of a conductor of the electrical interface to create an impermeable barrier between a metallic encapsulating material and the thermoplastic substrate.

Abstract: A vibration damping device for use with a downhole tool having a tool axis may comprise a body coupled to a drill string component. The body may include a longitudinal bore therethrough and at least one lateral bore, the lateral bore having a bore opening and an end wall; an inertial mass slidably disposed in the lateral bore; and a cap mechanically coupled to the lateral bore. The lateral bore may be orthogonal to a radius of the body and may lie in a plane normal to the tool axis. The body may include a plurality of lateral bores, which may be in a co-planar arrangement. Each lateral bore may be blind hole positioned in the body so that it does not intersect the longitudinal bore or another lateral bore. A cap may enclose a lateral bore and fluid may be contained in the bore by the cap.

Abstract: Systems and methods of the present disclosure relate to dampening downhole vibrations with an electroactive polymer (EAP). A downhole tool comprises a collar; an electronic control unit (ECU); a vibration sensor in communication with the ECU; a voltage source in communication with the ECU; and the EAP disposed along portions of the collar, the EAP in communication with the ECU, wherein the ECU is configured to apply voltage to the EAP based on signals received from the vibration sensor.

Abstract: A pressure generating device for use in downhole drilling operations includes a rotating valve portion having a first body with at least one first flow channel, and a stationary valve portion having a second body with at least one second flow channels and at least one bypass channel. A flow restrictor is positioned within the at least one bypass channel for adjusting a total flow area of the at least one bypass channel. During rotation of the rotating valve portion relative to the stationary valve portion, a total flow area of a passage defined by the first flow channel(s), the second flow channel(s), and the at least one bypass channel varies according to a uniform closure pattern to provide uniform pressure pulses within a single revolution of the rotating valve portion. A method of generating uniform pressure pulses in downhole drilling operations is also disclosed.

Abstract: A method comprising determining a property of a first section of drill pipe that is to connect a first agitator to a second agitator in a bottom hole assembly of a drill string, determining a distance between the first agitator and the second agitator based, at least in part, on the property of the first section of drill pipe, positioning the first agitator in the bottom hole assembly of the drill string, and positioning the second agitator in the bottom hole assembly of the drill string relative to the first agitator based, at least in part, on the distance.

Abstract: A system and method for reducing noise from a signal during drilling of a well. A system for generating mechanical vibrations may generate acoustic signals for communicating information, and may induce pressure signals in a drilling mud communicating information. A noise reduction system may receive both the acoustic and pressure signals and phase shift one set of signals to adjust for a time difference between the two. The system may also sample the signals and may overlay the signals or the sampled signals and cancel the noise from the received signals.

Abstract: Systems and methods for producing controlled vibrations within a borehole. In one example, the system includes a movement mechanism and a controller. The movement mechanism is configured to enable translational movement of a first surface relative to a second surface to allow the first surface to impact the second surface to produce a plurality of beats. The frequency and amplitude of the beats may be selectively controlled by suppressing or dampening the beats. The controller is configured to selectively control an amplitude or frequency of the beats to encode information therein, where the amplitude of a beat may be selectively controlled by dampening or suppressing the impact of the first surface and the second surface.

Abstract: A method and system for use in an ocular surgical procedure is provided. The design includes a handpiece having an ultrasonically vibrating tip operational within a plurality of operating modes including a first operating mode and a sensing device, such as a vacuum pressure sensor. A controller is connected to the handpiece and sensing device and is configured to receive data from the sensing device and adjust at least one operational parameter (time/duty cycle of operation, power during operation) associated with the first operating mode and adjust at least one parameter associated with another operating mode based on the data received from the sensing device. Operational modes may include multiple longitudinal or non-longitudinal modes (torsional, transversal, etc.) or combinations of longitudinal and/or non-longitudinal modes.

Abstract: A method of recognizing obstacles on operation of a vibratory pile driver of a work machine includes monitoring an acceleration signal of the vibratory pile driver during operation of the vibratory pile operator and analyzing the acceleration signal to determine the presence of an obstacle. The acceleration signal may be monitored over a time period which is determined based on an excitation frequency of the vibratory pile driver. The analysis may include comparing negative and positive half-waves of the acceleration signal. Responsive to the analysis indicating an obstacle, a system operator may be alerted, and/or operation of the vibratory pile driver may be adjusted via controller intervention.

Abstract: A method for configuring transmission signals is disclosed. The method includes receiving a signal from a downhole tool in a wellbore. The signal may include a telemetry portion and a noise portion. The method also includes reproducing the telemetry portion based at least partially on the signal. Further, the method includes subtracting the telemetry portion from the signal. The method includes estimating, based at least partially on the subtraction, the noise portion of the signal. The method also includes altering a transmission configuration of the downhole tool based at least partially on the noise portion of the signal.

Abstract: Systems and methods for analyzing physical characteristics of a battery include arrangements of two or more transducers coupled to the battery. A control module controls one or more of the two or more transducers to transmit acoustic signals through at least a portion of the battery, and one or more of the two or more transducers to receive response acoustic signals. Distribution of physical properties of the battery is determined based at least on the transmitted acoustic signals and the response acoustic signals.

Abstract: A rheological lock apparatus includes a fluid chamber formed within a housing between a pair of seals. The fluid chamber contains a rheological fluid. An inner surface of the housing has a first plurality of splines projecting into the fluid chamber and extending longitudinally along a longitudinal dimension of the chamber. A driveshaft extends axially through the chamber such that the pair of seals are sealed against the driveshaft. The driveshaft includes a second plurality of splines. A field generator is coupled to one of the driveshaft or the housing to generate a field through the rheological fluid during times when the housing is substantially immobile in a borehole.

Abstract: A foundation pile end piece is provided that includes a ring-shape connection housing, where a proximal end of the ring-shape connection housing is configured to secure to a bottom end of a foundation pile, a moveable tip, where a distal end of the ring-shape connection housing is configured to fixedly hold the moveable tip, where the moveable tip is disposed to oscillate transversely with respect to a central axis of the ring-shape connection housing, where the moveable tip is configured to displace soil from the bottom end of the foundation pile according to actuation of the oscillation.

Abstract: The applicator includes a housing and a motor contained therewithin which includes an output member, such as a shaft, which in operation moves in a reciprocating manner. A contact member is mounted for operation and moves in response to the action of the output shaft, such that the contact element in operation repeatedly contacts a selected skin area, moving toward and away from the skin area, substantially perpendicularly thereto. The contact member moves at a frequency within the range of 50 Hz to 200 Hz and with an amplitude of 0.010 to 0.075 inches. The repeated tapping action of the contact member against the skin increases the absorption of a skin formulation into the skin area being contacted.

Abstract: A method for configuring transmission signals is disclosed. The method includes receiving a signal from a downhole tool in a wellbore. The signal may include a telemetry portion and a noise portion. The method also includes reproducing the telemetry portion based at least partially on the signal. Further, the method includes subtracting the telemetry portion from the signal. The method includes estimating, based at least partially on the subtraction, the noise portion of the signal. The method also includes altering a transmission configuration of the downhole tool based at least partially on the noise portion of the signal.

Abstract: A flow rate sensing system can include an optical waveguide, an optical interrogator that detects optical scatter in the optical waveguide, and an emitter that produces vibration in response to flow, the optical scatter being influenced by the vibration. A method of measuring flow rate can include detecting optical scattering in an optical waveguide, the optical scattering varying in response to changes in vibration produced by an emitter, and the vibration changing in response to the flow rate changing. A well system can include at least one tubular string positioned in a wellbore, multiple locations at which fluid flows between an interior and an exterior of the tubular string, multiple emitters, each of which produces vibration in response to the flow between the interior and the exterior of the tubular string, and an optical waveguide in which optical scatter varies in response to changes in the vibration.

Abstract: A method for selecting drilling parameters for drilling a borehole penetrating the earth with a drill string. The method includes: measuring vibration-related amplitudes of the drill string during operation using one or more vibrations sensor to provide amplitude measurements; determining with a downhole processor one or more modal properties comprising one or more eigenfrequencies of the drill string using the amplitude measurements, the determination being made by including any excitation force in a white noise term of a model of the drillstring; and selecting drilling parameters that apply an excitation force at a frequency that avoids a selected range of frequencies that bound the one or more eigenfrequencies using the processor.

Abstract: An opto-acoustic flowmeter can include an optical waveguide and an emitter that emits acoustic energy in response to flow, the acoustic energy comprising a flow rate dependent parameter. A flow rate measuring method can include configuring an emitter so that flow into or out of a tubular string causes the emitter to emit acoustic energy, arranging an optical line so that the acoustic energy is received by an optical waveguide of the optical line, and detecting optical scatter in the optical waveguide. A well system can include multiple locations where fluid is flowed between an earth formation and a tubular string in a wellbore, multiple emitters that produce an acoustic vibration corresponding to a flow rate of the fluid, an optical line that receives the vibrations, and an optical interrogator that detects optical scatter in an optical waveguide of the line, the scatter being indicative of the vibrations.

Abstract: A method for estimating downhole speed and force variables at an arbitrary location of a moving drill string based on surface measurements of the same variables. The method includes a) using properties of said drill string to calculate transfer functions describing frequency-dependent amplitude and phase relations between cross combinations of said speed and force variables at the surface and downhole; b) selecting a base time period; c) measuring surface speed and force variables, conditioning the measured data by applying anti-aliasing and/or decimation filters, and storing the conditioned data, and d) calculating the downhole variables in the frequency domain by applying an integral transform, such as Fourier transform, of the surface variables, multiplying the results with said transfer functions, applying the inverse integral transform to sums of coherent terms and picking points in said base time periods to get time-delayed estimates of the dynamic speed and force variables.

Abstract: A noisemaker system includes: a node of an infrastructure system; and a noisemaker including a vibrating plate, the vibrating plate including a top surface and a bottom surface, the bottom surface of the vibrating plate in contact with an exterior surface of the node, and an actuator configured to engage the top surface of the vibrating plate and generate an acoustic signal.

Abstract: Embodiments relate to an apparatus and method for performing a split-lateral load test. Embodiments use a double hydraulic jack to apply two lateral loads, having equal magnitudes and opposite directions, to the soil layer of an excavation for a deep foundation element. Data such as the magnitude of the lateral load and magnitude of the displacement of the loading mechanism upon application of the lateral load can be measured and/or recorded. Embodiments can yield soil modulus (Es) information in a form analogous to a p-y curve, which can be used to design a pile structure and pile placement, and model a pile response to lateral loading using computer software. Embodiments do not require the casting of concrete, and allow the split lateral loading mechanism to be sequentially positioned, and apply lateral loads, at multiple depths in an excavation. Embodiments simultaneously apply bi-directional lateral loads at multiple depths in an excavation.

Abstract: A downhole tool for increasing a diameter of a wellbore disposed within a subterranean formation. The downhole tool includes an underreamer having a plurality of cutter blocks moveably coupled thereto that move radially-outward from a refracted state to an expanded state. The cutter blocks cut the subterranean formation to increase the diameter of the wellbore from a first diameter to a second diameter when in the expanded state. A formation weakening tool may be coupled to the underreamer. The formation weakening tool weakens a portion of the subterranean formation positioned radially-outward therefrom.

Abstract: A method for configuring transmission signals is disclosed. The method includes receiving a signal from a downhole tool in a wellbore. The signal may include a telemetry portion and a noise portion. The method also includes reproducing the telemetry portion based at least partially on the signal. Further, the method includes subtracting the telemetry portion from the signal. The method includes estimating, based at least partially on the subtraction, the noise portion of the signal. The method also includes altering a transmission configuration of the downhole tool based at least partially on the noise portion of the signal.

Abstract: An underground directional drilling system can comprise a plurality of elongated dual-shaft segments coupled together end-to-end and forming an inner shaft assembly independently rotatable relative to an annular outer shaft assembly. The dual-shaft drilling system can include a communication segment that comprises an outer shaft having first longitudinal portion, a second longitudinal, and a gap portion that provides electrical insulation therebetween. The communication segment can generate voltage differences between the longitudinal portions that cause electrical pulses to periodically transfer across the gap portion to wirelessly communicate drilling related data to the surface. An inner shaft of the communication segment can comprise electrical insulation to avoid creating an electrical short between the first and second longitudinal portions of the outer shaft.

Abstract: An improvement to a sonic drilling system comprising a high-pressure, high-volume water pump connected to a fluid supply and a length of casing in a borehole; an elastic sonic rod string; an eductor coupling having an upwardly directed convergent nozzle; a transition rod; a sub-coupling having a laterally directed convergent nozzle; and a shoe rock bit having a downwardly directed convergent nozzle. The water pump provides fluid down the bore of the sonic rod string, the eductor, the transition rod, the sub-coupling and the rock bit whereby adjustable high-pressure, high-volume fluid is forced through the sonic rod string, the eductor, the transition rod, the sub-coupling and the rock bit to fracture, cut and agitate targeted mineral into slurry and whereby the light slurry is directed effectively upwardly through the annulus to the surface for extraction and heavy slurry gravitates into a sump trap and is recovered with a core barrel.

Abstract: A propulsion generator which employs one or more unbalanced rotors, such as fly wheels or other unbalance rotating members, which can be connected at a lower portion of a downhole coiled tubing string or other downhole tubular string for inducing propulsion of the coiled tubing. The unbalanced rotors may be oriented at different positions with respect to each other. The instantaneous fluid flow through the propulsion generator is substantially equivalent to the average fluid flow rate through the tool to provide relatively consistent fluid flow to downhole motors below the propulsion generator for operating the drill bit and/or cutters.

Abstract: An apparatus for use in a horizontal section of a drill string is disclosed. The apparatus includes a motor that is connected to the horizontal section of the drill string. The motor is adapted to impart vibrations in the horizontal section of the drill string, where the vibrations are at about the lateral resonant frequency of the horizontal section of the drill string.

Abstract: A valve for communication of a measurement while drilling system includes a first structure having a central portion and one or more elongate portions radially extending from the central portion, and a second structure having one or more portions which substantially bound a central orifice region and one or more elongate orifice regions radially extending from the central orifice region. At least one of the first structure and the second structure is configured to be rotated about a rotation axis to produce a relative rotation between the first structure and the second structure such that a flow path through which mud can flow varies as the at least one of the first structure and the second structure rotates about the rotation axis. The central portion has a maximum inscribed circle encircling the rotation axis and having a first radius and the central orifice region has a maximum inscribed circle encircling the rotation axis and having a second radius greater than the first radius.

Abstract: A logging while drilling (LWD) caliper includes a drill collar, at least one movable pad, a hinge coupler, a power transmitter and a power receiver. The hinge coupler couples the movable pad to the drill collar in such a way that the movable pad can move between an open position and a closed position. The power transmitter is coupled to the drill collar in such a way that the power transmitter receives power from the drill collar. The power receiver is coupled to the movable pad in such a way that the power receiver provides power to the movable pad. Also, the power transmitter is coupled to the drill collar and the power receiver is coupled to the movable pad is such a way that power is transmitted from the power transmitter to the power receiver.

Abstract: The present disclosure is for a vibratory downhole rotary apparatus. The apparatus includes a cylindrical hollow body, a stator disposed within the cylindrical hollow body and a rotor disposed within the stator. The apparatus also includes a flow resistance system to vary the resistance of fluid flow through the apparatus to increase and decrease backpressure across the apparatus.

Abstract: A propulsion generator which employs one or more unbalanced rotors, such as fly wheels or other unbalance rotating members, which can be connected at a lower portion of a downhole coiled tubing string or other downhole tubular string for inducing propulsion of the coiled tubing. The unbalanced rotors may be oriented at different positions with respect to each other. The instantaneous fluid flow through the propulsion generator is substantially equivalent to the average fluid flow rate through the tool to provide relatively consistent fluid flow to downhole motors below the propulsion generator for operating the drill bit and/or cutters.

Abstract: A vibration system for drill bit housing and method is disclosed, which may be utilized to assist in lowering a drill string into a wellbore through which drilling fluid is pumped. In one embodiment, a drill bit housing contains a symmetrical rotatable member positioned to rotate in response to drilling fluid pumped through the housing, whereby a mechanical interconnection connected to the rotatable member produces vibrations within the drill bit housing for advancing bottom hole assemblies.

Abstract: A system to harvest mechanical energy in a wellbore, wherein the mechanical energy comes from motion. The system uses mechanical energy coming from at least one of: motion of a drill bit, motion of a drill string, motion of flowing air or drilling mud down the drill string to the drill bit and up an annulus between the drill string and the wellbore, and motion of a bottom hole assembly connected to the drill string. The system can include a plurality of piezoelectric stand bundles, wherein each individual piezoelectric strand can vibrate as the pressure housing moves in the wellbore, thereby producing electricity.

Abstract: A system for producing controlled vibrations within a borehole comprises a vibration mechanism an impact to produce a plurality of vibration beats. The vibration mechanism is located substantially near a bottom hole assembly within the borehole. A damping mechanism selectively damps the vibration beats to encode information therein. The damping mechanism is located remotely from the vibration mechanism along a drill string of the bottom hole assembly.

Abstract: A system for evaluating a geological formation in a bottom hole assembly (BHA) includes a vibration mechanism configured to use mechanical energy provided by a mechanical energy source to produce a plurality of vibration beats at a predetermined frequency at the BHA. At least one vibration sensor detects the plurality of vibration beats generated by the vibration mechanism. A controller generates a waveform responsive to the detected plurality of vibration beats. The waveform is generated in a first configuration when the geological formation has a first geological characteristic and the waveform is generated in a second configuration when the geological formation has a second geological characteristic.

Abstract: In some example embodiments, a system includes a drill string having a drill bit. The drill string extends through at least part of a well bore. The system also includes a first vibrational sensor, positioned on the drill bit to measure, at a first location on the drill string, an amplitude of one or more of an axial vibration and a lateral vibration. The system also includes a second vibrational sensor, positioned above the drill bit and on the drill string. The second vibration sensor is to measure, at a second location on the drill string, one or more of an axial vibration and a lateral vibration. The system includes a processor unit to determine a type of vibration based on a comparison of the amplitude at the first location to the amplitude at the second location, wherein the type of vibration is at least one of bit whirl of the drill bit and a while of a bottom hole assembly that is part of the drill string.

Abstract: Various implementations described herein are directed to a vibration tool, e.g., for use in drilling or other downhole operations. In one implementation, the vibration tool may include a housing having a bore extending therethrough. The vibration tool may also include a piston subassembly positioned inside the bore, where the piston subassembly is configured to oscillate when fluid flow inside the piston subassembly exceeds a predetermined flow rate. The vibration tool may further include a valve mechanism positioned around the piston subassembly, where the valve mechanism is configured to restrict fluid to flow inside the piston subassembly when the valve mechanism is in a closed state and configured to allow the fluid to flow from the piston subassembly to the bore when the valve mechanism is in an open state.

Abstract: A method of translating a member through a bore involving moving fluid through a tubular member such as a drill string, and generating impulses on the member by varying the passage of fluid through the member using a valve which opens at a first rate and closes at a different second rate to urge the member to advance in a selected direction. The valve may close quickly and open slowly, or may close slowly and open quickly.

Abstract: An apparatus includes a body shaped to deform a wellbore tool in a predetermined manner. A vibration device applies a vibration to the body to reduce a frictional force caused when the body deforms the wellbore tool. In one arrangement, the vibration devices imparts a resonant wave motion to a swaging apparatus that is being pushed through a passage of a wellbore tubular. A swaging body vibrates at a resonant frequency along the long axis of the wellbore tubular and/or normal to long axis of the wellbore tubular. The relative motion between the swaging body and the tubular member reduces the force required to expand the wellbore tubular. Optionally, a controller operatively connected to the vibration device adjusts the operation of the vibration device in response to the sensor measurements of the vibrations in the swage body.

Abstract: A pulse generator comprises a stator coupled to a housing and a rotor that is rotatably disposed within the housing. An annulus is formed between the rotor and the stator. An inner bore is formed through the rotor. One or more outer flow ports provide fluid communication between the annulus and the inner bore. A retrievable valve assembly is rotationally coupled to the rotor and at least partially disposed within the inner bore. The retrievable valve assembly includes a rotary valve member having one or more primary flow ports. A fluid flow path is periodically formed by the one or more outer flow ports, the annulus, and the one or more primary flow ports as the rotor rotates.

Abstract: A shock assembly for use with a motion tool deployable into a wellbore by a conveyance. The motion tool includes a mandrel operatively connectable to the conveyance or the motion tool, a housing operatively connectable to the motion tool or the conveyance (the housing having an opening to slidingly receive the mandrel and including a first and a second spring portion), a first spring slidably positionable in the first spring portion and having a first spring stiffness, and a second spring slidably positionable in the second spring portion having a second spring stiffness. The second spring stiffness being less than the first spring stiffness such that the first and second springs selectively engage as the housing slidingly moves about the mandrel in response to forces applied to the system to selectively restrict movement between the mandrel and the housing whereby the motion tool is vibrated.

Abstract: A system and method for controlling an oscillatory penetration apparatus. An embodiment is a system and method for controlling a sonic drill having a displacement and an operating range and operating at a phase difference, said sonic drill comprising a push-pull piston and eccentrics, said method comprising: operating the push-pull piston at an initial push-pull force while the eccentrics are operated at a plurality of different operating frequencies within the operating range of the sonic drill and measuring the displacement at each operating frequency; determining an efficient operating frequency for the material being drilled and operating the eccentrics at said efficient operating frequency; determining the phase difference at which the sonic drill is operating; and if the phase difference is not substantially equal to minus ninety degrees, operating the push-pull piston at another push-pull force.

Abstract: A system to harvest mechanical energy in a wellbore, wherein the mechanical energy comes from motion. The system uses mechanical energy coming from at least one of: motion of a drill bit, motion of a drill string, motion of flowing air or drilling mud down the drill string to the drill bit and up an annulus between the drill string and the wellbore, motion of a bottom hole assembly connected to the drill string. The system can include a plurality of piezoelectric stand bundles, wherein each individual piezoelectric strand can vibrate as the pressure housing moves in the wellbore, thereby producing electricity.

Abstract: A sonic drill head comprising an outer housing, an isolation system, a sine generator and a spindle. The sine generator generates a linear sinusoidal vibration force through the rotation of a plurality of eccentric masses. The sine generator is configured to translate the linear sinusoidal force to the spindle in a direction corresponding to the spindle's axis of rotation. The sine generator supports the spindle within the housing such that the spindle is free to rotate about the spindle axis. The spindle is generally a hollow tube section thereby allowing the passage of drilling fluid, mud, cuttings, and/or tooling. The isolation system generally reduces the transfer of the vibration force generated by the sine generator to the outer housing, yet is able to transfer an applied thrust force from the outer housing to the sine generator.

Abstract: A system is provided for communicating within a borehole using controlled vibrations. A movement mechanism uses mechanical energy provided by a mechanical energy source to enable translational movement of a first surface relative to a second surface to allow the first surface to repeatedly impact the second surface to produce a plurality of vibration beats. The vibration beats will occur whenever the mechanical energy is provided by the mechanical energy source at one of at least three impact levels. A vibration control mechanism selectively controls an amplitude of the plurality of vibration beats to encode information therein. The amplitude of a vibration beat is selectively controlled by regulating the impact of the first surface and the second surface to one of the at least three impact levels.

Abstract: A downhole drilling apparatus includes a drill bit, a steering tool, and an anti-oscillation sleeve deployed about a downhole end of the steering tool. The anti-oscillation sleeve is undergauge and is deployed axially between a first touch point at which the drill bit contacts the borehole wall and a second touch point at which the steering tool contacts the borehole wall.

Abstract: A drilling tool for laying a tube (3) around a buried elongated element (1), comprising a drilling head (2) guided by the buried element (1), moving under the action of a pressurized fluid, from a first free end (14) of the buried element towards a second end (13) of the buried element (1), and pulling the tube (3), characterized in that the drilling tool comprises pressurization means (4) attached to the first end (14) of the buried element (1), able to slide into the tube (3) pulled by the drilling head (2) and able to create a pushing force on the drilling head (2) by the pressurization with said pressurized fluid of a pressure chamber (42) arranged between the drilling head (2) and the pressurization means (4).

Abstract: A sonic drill head comprising an outer housing, an isolation system, a sine generator and a spindle. The sine generator generates a linear sinusoidal vibration force through the rotation of a plurality of eccentric masses. The sine generator is configured to translate the linear sinusoidal force to the spindle in a direction corresponding to the spindle's axis of rotation. The sine generator supports the spindle within the housing such that the spindle is free to rotate about the spindle axis. The spindle is generally a hollow tube section thereby allowing the passage of drilling fluid, mud, cuttings, and/or tooling. The isolation system generally reduces the transfer of the vibration force generated by the sine generator to the outer housing, yet is able to transfer an applied thrust force from the outer housing to the sine generator.

Abstract: A system and method are provided for using controlled vibrations to bias a drilling direction of a bottom hole assembly (BHA) in a borehole. In one example, the system includes a movement mechanism and a vibration control mechanism. The movement mechanism is configured to use mechanical energy provided by a mechanical energy source to enable translational movement of a first surface relative to a second surface to allow the first surface to repeatedly impact the second surface to produce a plurality of vibration beats. The vibration control mechanism is configured to influence a drilling direction in which the BHA is drilling by controlling an amplitude of the vibration beats to regulate an impact force between the first surface and the second surface, where the amplitude is controlled based on directional information corresponding to the BHA.