Abstract: A downhole tool includes a tool body and an actuator coupled to and selectively extendible relative to the tool body. The actuator has a working face that contacts a downhole formation, and which includes an upper portion and a lower portion. The lower portion has a tapered surface that is directed radially inwardly and axially downwardly relative to the first portion, with at least a portion of the tapered surface including an ultrahard material having a different coefficient of friction as compared to a first material of the upper portion.

Abstract: Pad force is one of the major parameters in some drilling systems, such as a RSS, that affect steering decisions during drilling. The disclosure recognizes that the pad force can change during drilling due to, for example, unintentional leaking through a pad seal that has been damaged due to the wear and tear of drilling. With a decrease in the pad force, the steering capability of the drilling tool can be compromised. As such, the disclosure provides a method and system that determines pad force information in real time for controlling drilling. The pad force information can be determined based on sensor data, component data, and drilling data. An estimated pad force is one example of the pad force information that can be calculated and used to direct a drilling operation.

Abstract: A drilling system includes a drill string for connecting with a drill bit for drilling a borehole, a fixed stabilizer fixed on the drill string, and an active stabilizer including a body and actuators connecting the body and the drill string. The actuators are capable of driving the drill string away from a center of the borehole with a displacement. The body has an outer surface for contacting a wall of the borehole, an inner surface facing the drill string, and at least one guiding portion projecting from the inner surface and each defining at least one groove. The drill string includes at least one sliding portion slidable within the at least one groove respectively to constrain movement between the drill string and the active stabilizer along an axial direction of the drill string and guide movement between the drill string and the active stabilizer perpendicular to the axial direction.

Abstract: A downhole tool includes a tool body and an actuator coupled to and selectively extendible relative to the tool body. The actuator has a working face that contacts a downhole formation, and which includes an upper portion and a lower portion. The lower portion has a tapered surface that is directed radially inwardly and axially downwardly relative to the first portion, with at least a portion of the tapered surface including an ultrahard material having a different coefficient of friction as compared to a first material of the upper portion.

Abstract: Directional drilling is an extremely important area of technology for the extraction of oil and gas from earthen formations. The technology of the present application relates to improved positioning elements for directional drilling assemblies. It also relates to drilling directional wellbores using the guidance positioning members of the present technology.

Abstract: A drilling system includes a rotatable string for connecting with a bit for drilling a borehole, and an active stabilizer which includes a body having an outer surface for contacting a wall of the borehole, and a plurality of actuators connecting the body and the string and capable of driving the string to deviate away from a center of the borehole with a displacement to change a drilling direction. The drilling system further includes a module for measuring direction parameters including at least one of a declination angle and an azimuth angle of the borehole, a module for measuring imbalance parameters including at least one of a lateral force, a bending moment and a torque near the drill bit, and a controller including a calculator for calculating an adjustment needed for the displacement, based on the measured parameters and expected values of these parameters.

Abstract: An apparatus for transferring rotational torque from a work string to a subsea infrastructure, said apparatus comprising a first connection (1) for receiving the work string; a second connection (6) for receiving the subsea infrastructure tooling; a joint seat (5) located between the first connection (1) and the second connection (6); a joint body (3) provided on the joint seat (5), wherein the joint body (3) is connected to the second connection (8) and wherein the joint body (3) can articulate freely within the joint seat (5); and means for transferring rotational torque from the first connection (1) to the joint body (3) and subsequently to the second connection (6).

Abstract: Control valves can allow for a steering assembly of a drill string. An exemplary control valve can include a first valve element including a first orifice, the first valve element being movable by actuation by a motor, and a second valve element including an orifice, wherein flow passing through the first valve element orifice passes through the second orifice and into a flow channel to be in fluid communication with a piston bore to exert pressure against a piston movable within the piston bore, the piston being coupled to a steering pad for applying force against the wellbore wall to steer a direction of the drill string. The first valve element is movable with respect to the second valve element to change flow through the first valve element orifice and the second valve element orifice to modify fluid pressure within the flow channel that is exerted against the piston.

Abstract: A steering collar for deflecting a drill string in a borehole to cause the borehole to be drilled in a different direction. The steering collar surrounds a hollow drive shaft which is driven by the drill string. During normal drilling operations, the steering collar does not rotate with the drive shaft. The steering collar has three sets of pistons operated by the pressure of the drilling fluid, one set of which is pressure relieved. Drill fluid that is pumped down the drill string flows into the hollow drive shaft and through ports to activate the pistons which thereby force corresponding pads outwardly into contact with the sidewall of the borehole. Since the one set of pistons is pressure relieved, it does not force its pad against the borehole sidewall with as much pressure as the other two sets of pistons force their pads against the sidewall of the borehole.

Abstract: Systems and methods for adjusting a drilling operation, the methods and systems include obtaining, at a control system, a first drilling characteristic associated with a first drilling operation device that is part of a drilling system on a drill string; obtaining, at the control system, a second drilling characteristic associated with a second drilling operation device located apart from the first drilling operation device along the drill string; and controlling, with the control system, at least one adjustable element of the first drilling operation device in response to at least one of the obtained first drilling characteristic and the second drilling characteristic, wherein adjustment of the at least one adjustable element causes a change in at least one of the first drilling characteristic and the second drilling characteristic.

Abstract: An assembly for use in subsurface drilling includes a downhole probe supported by a centralizer. The centralizer comprises a tubular member that extends around the downhole probe. A wall of the centralizer is fluted to provide inward contact points that support the downhole probe and outward contact points that bear against a bore wall of a section of drill string. The downhole probe may be supported for substantially its entire length.

Abstract: Systems and methods of counteracting downhole reactive forces within a directional drilling tool are disclosed. The directional drilling tool includes a steering mechanism for selectively pivoting a bit shaft with respect to an elongate housing. A preloaded flexible member may be provided between an upper end of the bit shaft and an elongate housing to counteract reactive forces applied by a geological formation on a drill bit at a lower end of the bit shaft. Where sufficient reactive forces are transmitted through the bit shaft to overcome the preload, the flexible member will be induced to flex, permitting some movement of the upper end of the bit shaft. This movement limits the force that may be applied by the steering mechanism, which can extend the useful life of the directional drilling tool and may permit the power required to drive the drill bit to be maintained at a consistent value.

Abstract: A steering head for use with a casing, the steering head having a body with a first body end with a lead edge, a second body end with a rear edge, and a body surface extending from the lead edge to the rear edge, an outer tube with an internal side generally facing the body surface, the outer tube extending from the first body end to the second body end, and a steering flap disposed on an external side of the outer tube having a first flap face facing radially inwardly and a second flap face facing radially outwardly. A fluid dispenser is disposed in a void defined between the outer tube and the body.

Abstract: A system for steering a drilling device comprising a drill pipe, is provided therein, the system comprising: a hoop sleeved on the drill pipe of the drilling device and having an outer diameter substantially equal to an inner diameter of a hole to be drilled; and a steering driving mechanism provided between the hoop and the drill pipe, for controlling a radial displacement of the drill pipe relative to a center axis of the hole to be drilled while drilling. The steering driving mechanism comprises one or more sub-mechanisms for connecting the hoop and the drill pipe and driving the drill pipe to move inside the hole, wherein each of the sub-mechanisms comprises an actuator adjustable in length, and a link element with one end rotatably coupled to the actuator and the other end rotatably coupled to hoop.

Abstract: A steerable drilling apparatus includes a control system inside a cylindrical housing connected to a drill bit having radially-extendable pistons. A fluid-metering assembly directs a piston actuating fluid into fluid channels in the drill bit leading to respective pistons. The control system controls the fluid-metering assembly to selectively allow fluid flow through the fluid channels to the pistons and to exit through orifices in the fluid channels. The selective fluid flow causes the actuated piston to temporarily extend in the opposite direction to a desired wellbore deviation, thereby deflecting the drill bit away from the borehole centerline. An upper member in the fluid-metering assembly can be moved to stabilize, steer, and change TFA within the drill bit. The control system and drill bit are connected so as to facilitate removal to change the drill bit's steering section and cutting structure configuration or gauge simultaneously.

Abstract: A system for controlling a first module, a second module, and a third module. The system includes: an inlet configured to receive fluid from a fluid source; a first double-stage valve; and a second double-stage valve. The first double-stage valve is actuatable to a first position wherein fluid from the inlet flows through the first double-stage valve to the second double-stage valve and a second position wherein fluid from the inlet flows through the first double-stage valve to the third module. The second double-stage valve is actuatable to a first position wherein fluid flows from the first double-stage valve to the first module and a second position wherein fluid flows from the first double-stage valve to the second module.

Abstract: Downhole tools and techniques acquire information regarding nearby conductors such as pipes, well casing, and conductive formations. At least some method embodiments provide a current flow along a drill string in a borehole. The current flow disperses into the surrounding formation and causes a secondary current flow in the nearby conductor. The magnetic field from the secondary current flow can be detected using one or more azimuthally-sensitive antennas. Direction and distance estimates may be obtainable from the azimuthally-sensitive measurements, and can be used as the basis for steering the drillstring relative to the distant conductor. Possible techniques for providing current flow in the drillstring include imposing a voltage across an insulated gap or using a toroid around the drillstring to induce the current flow.

Abstract: A steerable system comprises a fluid powered motor 10 having a rotor 16 and a stator 18, and a bias arrangement having a plurality of bias pads 34 connected to the stator 18 so as to be rotatable therewith, the bias pads 34 being moveable to allow the application of a side load to the steerable system.

Abstract: A steerable drilling apparatus includes a control system inside a cylindrical housing connected to a drill bit having radially-extendable pistons. A fluid-metering assembly directs a piston-actuating fluid into fluid channels leading to respective pistons. The control system controls the fluid-metering assembly to allow fluid flow to selected pistons, causing the actuated pistons to temporarily extend in the opposite direction to a desired wellbore deviation, thereby deflecting the drill bit away from the borehole centerline. An upper member in the fluid-metering assembly can be moved to stabilize, steer, and change TFA within the drill bit. The control system and drill bit are connected so as to facilitate removal to change the drill bit's steering section and cutting structure configuration or gauge simultaneously. The apparatus may incorporate a fluid filter module mounted to the control system. The pistons may incorporate auxiliary cutting elements to provide near-bit reaming capability.

Abstract: A downhole stabiliser (5), such as a drill motor stabiliser, comprises at least one reaming means and/or reinforcing means (10). The present invention also relates to an assembly (30), such as a downhole drilling assembly (31), comprising at least one such stabiliser (5) and/or a drill bit (40,41) comprising a gauge bit (42) at or near a drilling end (45) thereof, and a connection means (46) for connecting the drill bit (40,41) to a drill motor assembly (60), wherein the drill bit gauge (42) comprises a substantially cylindrical portion having a length less than or equal to approximately 1.0 times the nominal bit diameter. The present invention also relates to a novel locking mechanism (80), such as a lock and key mechanism, to allow locking of a shaft (70?), e.g. a motor drive shaft (71?), through or together with a stabiliser (5?).

Abstract: A downhole tool assembly for use in directional drilling operations. The assembly has a housing, a chuck, a cutting tool, a hub, and an elongate drive member. The housing has a spindle for supporting the hub and chuck for rotation thereon. The chuck is connected to the hub and has a non-circular interior surface and a box for supporting a cutting tool for rotation with the chuck. The elongate drive member is disposed within the housing, the hub, and the chuck. The drive member is operatively connected to the inner member of a dual-member drill string for rotation independently of the housing. The drive member has a non-circular external surface corresponding to the non-circular interior surface of the chuck. The pin end of the drive is slidably receivable in connector free torque-transmitting engagement with the interior surface of the chuck to drive rotation of the cutting tool, chuck, and hub independently of the housing.

Abstract: The present invention provides a method and apparatus for increasing the drift diameter and improving the well path of the well bore, accomplished in one embodiment by cutting away material primarily forming surfaces nearer the center of the drift, thereby reducing applied power, applied torque and resulting drag compared to conventional reamers that cut into all surfaces of the well bore.

Abstract: The present invention provides a method and apparatus for increasing the drift diameter and improving the well path of the well bore, accomplished in one embodiment by cutting away material primarily forming surfaces nearer the center of the drift, thereby reducing applied power, applied torque and resulting drag compared to conventional reamers that cut into all surfaces of the well bore.

Abstract: A drilling system may include an outer sleeve, and a rotary steerable module including a shaft extending within the outer sleeve. The rotary steerable module may further include bearings disposed within the outer sleeve and through which the shaft extends, and cams positioned along the shaft between the bearings. Each cam may include an eccentric ring through which the shaft extends. Each extension of the shaft through one of the eccentric rings defines a bend in the shaft within the outer sleeve, the bend having a bend angle. A method of use and a drilling control apparatus are also provided.

Abstract: Disclosed are systems and methods of directional drilling with a steering sub. One steering sub includes a housing defining a central passage, a shaft extended within the central passage, bearings arranged within the central passage and configured to receive and support the shaft for rotation within the central passage, and one or more pressure chambers defined longitudinally in the housing and configured to deflect the housing upon experiencing an increased pressure, wherein deflection of the housing causes the shaft to correspondingly deflect via engagement with the bearings.

Abstract: This disclosure relates in general to a method and system for controlling a drilling system for drilling a borehole in an earth formation. More specifically, but not by way of limitation, embodiments of the present invention provide systems and methods for controlling dynamic interactions between the drilling system for drilling the borehole and an inner surface of the borehole being drilled to steer the drilling system to directionally drill the borehole. In another embodiment of the present invention, data regarding the functioning of the drilling system as it drills the borehole may be sensed and interactions between the drilling system for drilling the borehole and an inner surface of the borehole may be controlled in response to the sensed data to control the drilling system as the borehole is being drilled.

Abstract: An apparatus for keeping a down hole drilling tool vertically aligned has a tubular body having an axis, an inner bore, at least one perpendicular channel and at least one set of steering elements disposed on opposed sides of the tubular body and engaging the at least one perpendicular channel of the tubular body. The at least one perpendicular channel permits the steering elements to move perpendicularly to the axis of the tubular body and restricts movement parallel to the axis of the tubular body. The first and second steering elements are engaged such that movement of the first or second steering element toward an extended position relative to the tubular body moves the other steering element toward a retracted position relative to the tubular body. Actuators are carried by the tubular body that selectively actuate the steering elements toward the extended position to steer the down hole drilling tool.

Abstract: This disclosure relates in general to a method and a system for directionally drilling a borehole with a rotary drilling system. More specifically, but not by way of limitation, methods and system provide for controlling motion of the rotary drilling system in the borehole when a side force is applied to the drilling system to bias or focus the motion so that the drilling system directionally drills the borehole through an earth formation. In certain aspects, side cutting of a sidewall of the borehole by a drill bit under an applied side force is controlled by a geostationary element to provide for directional side cutting and, as a result, directional drilling of the borehole through the earth formation. In other aspects, a non-concentrically coupled gauge pad assembly may rotate with the drilling system and bias or focus the applied side force.

Abstract: Modular actuators, steering tools, and rotary steerable drilling systems are presented herein. A modular actuator is disclosed for use in directing a drill string, which includes a housing proximate a drive shaft. The modular actuator includes a cartridge that is configured to couple to the outer periphery of the housing. A fluid reservoir is contained within the cartridge. A hydraulically actuated actuator piston, which is slidably disposed at least partially inside the cartridge, is movable between activated and deactivated positions. A hydraulic control system is also contained within the cartridge, fluidly coupling the fluid reservoir to the actuator piston. The hydraulic control system is configured to regulate movement of the actuator piston between the activated and deactivated positions such that the actuator piston selectively presses against and moves the drive shaft and thereby changes the direction of the drill string.

Abstract: A drilling system comprising a rotatable drill pipe 12 connected to a tractor unit 10, and a steerable drilling system 18, 20, 22, connected to and movable by the tractor unit 10.

Abstract: A bi-stable valve includes a first chamber having a first aperture and a second aperture, and a second chamber having a first aperture and a second aperture. The bi-stable valve also includes a shaft having a first valve member adjacent a first end of the shaft and a second valve member adjacent an opposite second end of the shaft. The shaft is movable between a first position, in which the first valve member closes off the second aperture of the first chamber and the second valve member closes off the second aperture of the second chamber to prevent fluid from passing through the second apertures of the first and second chambers, and a second position, in which the first valve member and the second valve member allow fluid to pass through the second aperture of the first chamber and the second aperture of the second chamber.

Abstract: A bottom hole assembly to directionally drill a subterranean formation includes a drill bit, a stabilizer assembly located proximate to and behind the drill bit, a drilling assembly comprising a drive mechanism and a directional mechanism, and a flex housing integral with the drilling assembly.

Abstract: A technique facilitates drilling of wellbores with a steerable system having a plurality of pads which may be selectively actuated in a lateral direction to apply a side force. Application of the side force is used to steer a drill bit. A valve system is positioned to control delivery of actuating fluid under pressure to individual pads in a manner that enables steering of the drill bit. The valve system allows drilling along a desired curve by controlling the flow of actuating fluid under pressure to specific steering pads at specific angular positions. The valve system also allows drilling along a desired trajectory by preventing exposure of the pads to the pressurized actuating fluid.

Abstract: A drilling assembly is disclosed that in one embodiment includes a bi-directional wireless data transfer device between a rotating and a non-rotating member of the drilling assembly. Power may be supplied to the rotating member via any suitable method, including an inductive device and direct electrical connections.

Abstract: Piston steering devices and methods for use of piston devices. One aspect as disclosed herein provides a ball piston device including: a sleeve in fluid communication with a fluid source and a ball received within the sleeve. The ball is movable within the sleeve from a recessed position and an extended position.

Abstract: A directional-control apparatus for a drilling tool, in which the direction of the drilling tool during the drilling of a borehole is controlled by means of at least one steering body which is moved radially against the wall of the borehole, the movement of the at least one steering body relative to the centre axis of the directional-control apparatus being adjustable in order to steer the drilling tool in a desired direction and at a desired deflection, and at least one electrically operated actuator being connected via at least one set of transmission elements to the at least one steering body and arranged to move the at least one steering body into a position relative to the centre axis of the directional-control apparatus, the relative position having the effect that the drilling tool is steered in the desired direction and at the desired deflection.

Abstract: A directional drilling system comprises a main drill bit 24 rotatable about a main bit axis 26, a pilot drill bit 34 rotatable about a pilot bit axis 36 substantially parallel to the main bit axis 26, and adjustment means 28 for adjusting the position of the pilot bit axis 36 relative to the main bit axis 26.

Abstract: Apparatus, systems, and methods may operate to couple a tubular member to a bottom hole assembly, dispose at least one adjustable stabilizing member on the tubular member, and control at least one of a radial extension of the adjustable stabilizing member and an axial position of the adjustable stabilizing member relative to the bottom hole assembly to adjust a borehole trajectory, wherein the adjustable stabilizing member is adjustable in both radial and axial directions. Additional apparatus, systems, and methods are disclosed.

Abstract: A drill string suitable for use in directional drilling of a borehole, comprising a rotatable shaft at the leading end of which is a drill bit, and wherein the shaft comprises a variable friction inducing member, which provides rotational friction by physical contact with an inside face of the borehole, the friction inducing member being arranged to exert a first rotational frictional force when the shaft in the vicinity of the member is substantially rotating and a second rotational frictional force when the shaft in the vicinity of the member is substantially not rotating, wherein the first rotational frictional force is less than the second rotational frictional force.

Abstract: A steering head for use with a casing, the steering head having a generally cylindrical body with a first body end with a lead edge, a second body end with a rear edge, and a body surface extending from the lead edge to the rear edge, an outer tube with an internal side generally facing the body surface, the outer tube extending from the first body end to the second body end, and a steering flap disposed on an external side of the outer tube having a first flap face facing radially inwardly and a second flap face facing radially outwardly. A biased hinge is secured to both the outer tube and the steering flap, the biased hinge being operative to retract the steering flap into a retracted position from an extending position.

Abstract: Sleeves, stabilizers and other well tools may be formed with fluid flow paths or channels extending through one or more blades disposed on the exterior portions of such well tools. The blades and associated fluid flow paths extending therethrough may allow optimum fluid flow rates and volumes to enhance lifting of formation cuttings and downhole debris along with cleaning exterior portions of the well tool and an associated rotary drill bit. Location, configuration, orientation and/or dimensions associated with such blades and associated fluid flow paths or channels may also be modified to provide an enlarged pad or contact surface on exterior portions of one or more blades while maintaining desired fluid flow rates and volumes over exterior portions of the well tool. Such pads or contact surfaces may have optimum surface areas for contacting adjacent portions of a wellbore during directional drilling of the wellbore.

Abstract: Methods and systems may be provided simulating forming a wide variety of directional wellbores including wellbores with variable tilt rates and/or relatively constant tilt rates. The methods and systems may also be used to simulate forming a wellbore in subterranean formations having a combination of soft, medium and hard formation materials, multiple layers of formation materials and relatively hard stringers disposed throughout one or more layers of formation material. Values of bit walk rate from such simulations may be used to design and/or select drilling equipment for use in forming a directional wellbore.

Abstract: An apparatus for drilling a wellbore may include a first section, a second section, and a third section, all of which are rotatably interconnected with pivot bearings and positioned along a drill string. The second section and the third section may be configured to form a controllable bend angle in the drill string. The first section, the second section, and the third section may be configured as sleeves that surround a portion of the drill string. One or more sections may include locking pads that selectively engage a wall of the wellbore. A hydraulic locking device for controlling a direction of rotation of the second section may include one or more brake elements and a reverse spinning sleeve. A first brake element may be used engage the reverse spinning sleeve and a second brake element may be used to engage a drive shaft.

Abstract: In one aspect of the present invention, a downhole rotary steerable system comprises a fluid path defined by a bore formed within a drill string component. A valve located within a wall of the bore which hydraulically connects the bore with a fluid cavity. A steering nozzle disposed on the drill string component and in communication with the fluid cavity. The valve is configured to control flow from the bore to the fluid cavity with an azimuthal sensing mechanism configured to determine the azimuth of the steering nozzle and instrumentation configured to control the valve based off of input from the azimuthal sensing mechanism.

Abstract: A downhole steering system comprises a first full gauge stabilizer 34, a bias unit 28, a universal joint 26, and a second full gauge stabiliser 22, the bias unit 28 and universal joint 26 being located between the first and second full gauge stabilizers 34, 22. The system further comprises a drill bit 10 and a fluid powered downhole motor 14, the motor being located, at least partially, between the drill bit 10 and the second stabilizer 22.

Abstract: A technique is used to control the direction of a drill bit or bottom hole assembly via hydraulic steering utilizing a plurality of steering pads. A portion of hydraulic fluid, e.g. drilling fluid, is directed under pressure to a pad interface region proximate each pad. The hydraulic fluid provides additional force against a surrounding wall and/or reduces or eliminates contact between the pads and the surrounding wall.

Abstract: A rotary steerable tool is provided for use with a drilling apparatus. The rotary steerable tool includes at least a first portion that includes an outer housing, a rotary shaft extending through the outer housing, a drive clutch coupled to the rotary shaft, and a sensor coupled to the rotary shaft. The drive clutch is movable between an engaged configuration and a disengaged configuration. The sensor is configured to identify whether the drive clutch is in at least one of the engaged configuration and the disengaged configuration.

Abstract: A drill bit is provided that includes a force application device on a body of the drill bit. The force application device includes a floating member and a force application member configured to extend from the floating member to apply a force on a wellbore wall when the drill bit is used to drill a wellbore and an actuator configured to actuate the force application member to apply the force to a wellbore wall during drilling of the wellbore.

Abstract: In an aspect, a drill bit is provided that includes a pad on a face section. The pad extends from the bottom section upon application of a force thereon and retracts upon the removal of the force to control fluctuations of the drill bit during drilling of a wellbore.

Abstract: Disclosed herein are, among other things, piston steering devices and methods for use of piston devices. One aspect as disclosed herein provides a ball piston device including: a sleeve in fluid communication with a fluid source and a ball received within the sleeve. The ball is movable within the sleeve from a recessed position and an extended position.