Abstract: A conveyor apparatus (2), so-called injector head, to enable feeding of e.g. continuous tubing (7) or coiled tubing through the conveyor apparatus (2) to or from a wellhead and a well below and related to use of well tools. A pair of oppositely located, co-operatively movable, segmented continuous belts (28; 29) are installed in an apparatus frame (21), each belt comprising a plurality of interconnected gripper shoe carriers (30) carried and movable by means of a pair of continuous belt drive chains (31; 32), wherein the carrier (30) has roller means (35) configured roll against an elongate counter-force member (37), a so-called skate, associated with the frame (21), wherein a gripper shoe (38; 52) is co-operative with each carrier (30) to positively engage the tubing (7), and wherein a pair of said counter-force members (37) being adapted to interact with a respective belt (28; 29).

Abstract: A gripping device for a drill string component handling device in a rock drill rig. Gripper element pairs are supported by a body and include at least one gripper element, being pivotally movable around a pivot joint, between a closed position, including a gripping position, and an open position. The pivotally movable gripper element is pivotal in a respective gripper plane forming a right angle to an axial direction. Each movable gripper element includes an actuation portion, which co-operates with a wedge device being movable in directions parallel to the axial direction for pivoting said movable gripper element. A method, a drill string component handling device for a rock drill rig and a rock drill rig including a drill string component handling device.

Abstract: A layer of matrix powder is deposited within a mold opening. A layer of super-abrasive particles is then deposited over the matrix powder layer. The super-abrasive particles have a non-random distribution, such as being positioned at locations set by a regular and repeating distribution pattern. A layer of matrix powder is then deposited over the super-abrasive particles. The particle and matrix powder layer deposition process steps are repeated to produce a cell having alternating layers of matrix powder and non-randomly distributed super-abrasive particles. The cell is then fused, for example using an infiltration, hot isostatic pressing or sintering process, to produce an impregnated structure. A working surface of the impregnated structure that is oriented non-parallel (and, in particular, perpendicular) to the super-abrasive particle layers is used as an abrading surface for a tool.

Abstract: It is sometimes desirable to differentially regulate fluid flow in a subterranean formation using autonomous inflow control devices (AICDs), but they are not readily configurable in the field at present. Wellbore systems providing adjustable flow control may comprise: a wellbore pipe having a flow control assembly fixedly coupled thereto, the wellbore pipe having an interior space, an outer surface, and one or more AICDs establishing a fluid connection between the interior space and the outer surface of the wellbore pipe, and the flow control assembly comprising one or more flow chambers defined on the outer surface about the one or more AICDs, one or more inlets being fluidly connected to the one or more flow chambers; wherein the one or more inlets are configured to accept a plug for occluding fluid flow therethrough, so as to limit access of a fluid to an entry location of the AICDs.

Abstract: A zonal isolation and treatment tool having a reversible fluid booster pump with a reversible motor, both an upper isolation and a lower isolation packer having an elastic surface, a treatment fluid distributor that provides selective fluid access and an electronics control package that couples to the reversible motor. The method includes introducing the tool into the well bore, inflating the upper and lower isolation packers using well bore fluid, introducing the treatment fluid into the well bore such that it is positioned proximate to the tool, operating the tool such that the treatment fluid is introduced into the isolated well bore volume, and maintaining the isolated well bore volume such that the targeted stratum forms a treated stratum.

Abstract: An apparatus for use downhole is disclosed that, in one configuration includes a downhole tool configured to operate in an active position and an inactive position and an actuation device, which may include a control unit. The apparatus includes a telemetry unit that sends a first pattern recognition signal to the control unit to move the tool into the active position and a second pattern recognition signal to move the tool into the inactive position. The apparatus may be used for drilling a subterranean formation and include a tubular body and one or more extendable features, each positionally coupled to a track of the tubular body, and a drilling fluid flow path extending through a bore of the tubular body for conducting drilling fluid therethrough. A push sleeve is disposed within the tubular body and coupled to the one or more features.

Abstract: A polycrystalline compact comprises a plurality of grains of hard material and a plurality of nanoparticles disposed in interstitial spaces between the plurality of grains of hard material. The nanoparticles have cores of a first material and at least one oxide material on the cores. An earth-boring tool comprises such a polycrystalline compact. A method of forming a polycrystalline compact comprises combining a plurality of hard particles with a plurality of nanoparticles to form a mixture and sintering the mixture to form a polycrystalline hard material comprising a plurality of interbonded grains of hard material. A method of forming a cutting element comprises infiltrating interstitial spaces between interbonded grains of hard material in a polycrystalline material with a plurality of nanoparticles.

Abstract: The present invention relates to a millable plugging device for use in a well pipe. The device includes an inner mandrel and an outer housing provided radially outside at least parts of the inner mandrel. A sealing assembly is provided radially outside the inner mandrel, where the sealing assembly is configured to be brought from a run state to a set state by a relative axial displacement between the inner mandrel and the outer housing. The millable plugging device has a first center axis and the second mandrel section has a second center axis which is displaced parallel in relation to the first center axis. Rotation of the inner mandrel in the set state is bringing a third mandrel section of the mandrel to a locked state, in which further rotation of the inner mandrel is prevented.

Abstract: A pulling tool for latching onto an object, such as a plug, downhole in a wellbore includes a base element extending in a longitudinal direction from a proximal end for being connected to a wireline tool to a distal end adapted to engage the object, and a latching mechanism encircling the base element and being movable in the longitudinal direction between a deactivated position and an activated position, having a piston sleeve, a key element for latching onto the downhole object, the key element being slidably received inside the piston sleeve and extending from an end of the piston sleeve towards the distal end of the base element, and a piston spring forcing the piston sleeve in the longitudinal direction towards the proximal end of the base element.

Abstract: An electro-mechanical indicator system for signaling when a droppable object (such as, for example, a dart, plug or ball) is released during well cementing operations. A body section has first and second chambers divided by a fluid and pressure sealing barrier. A mechanical trigger mechanism is situated in the first chamber, which is exposed to elevated pressures and harsh wellbore fluids. Less robust components, such as sensor(s), power source(s), and signal device(s) located in the second chamber, remain isolated from the wellbore environment and elevated pressures.

Abstract: A flow control assembly includes a cylindrical body that defines an interior and openings provided through a wall of the body. An inner sleeve is positioned within the interior of the body and defines recessed pockets on an outer radial surface that coincide with the openings, and sleeve orifices are defined in the inner sleeve at each recessed pocket. A cartridge choke assembly is received within each opening and operatively coupled to the inner sleeve at one of the recessed pocket. The cartridge choke assembly includes a choking module that defines choke orifices alignable with the sleeve orifices. A flow control device is movably disposed within the body between a fully open position, where the one or more sleeve orifices are exposed, and a fully closed position, where the one or more sleeve orifices are occluded.

Abstract: A slip assembly for a downhole tool, such as a bridge plug, has a slip body and at least one insert unit with a base and one or more inserts. The slip body has an incline at one end that interfaces with an inclined surface of a cone. As this occurs, the slip body is pushed away from the tool's mandrel against a surrounding casing wall. The insert unit is disposed in the slip body with the base oriented at an angle relative to the incline, and with the one or more inerts extending from the base. In particular, the base can be disposed at or parallel to the incline, and the one or more inserts with less surface area than the base can extend perpendicular to the inline for the insert's distal ends to engage a surrounding wall of casing or the like.

Abstract: A drilling rig transfer system includes a mobile transfer beam, a trolley assembly operatively attached to and moveable along the mobile transfer beam, and a connection mechanism suspended from the trolley assembly for connecting to and lifting a device. The mobile transfer beam is suspended from first and second traveling blocks through connections at first and second suspension positions along the mobile transfer beam. A method of transferring a device may include suspending a connection mechanism from the trolley assembly over a first location, lowering and attaching the connection mechanism to a device disposed at the first location, lifting the device with the connection mechanism, moving the trolley assembly along the mobile transfer beam to position the connection mechanism and the device over a second location, and lowering the connection mechanism and the device into the second location.

Abstract: The present disclosure describes a recovery process using injector and producer wells, each well having means for varying the axial resistance to fluid flow to provide a complementary first and second annular axial fluid flow resistance profile. The recovery mechanism includes a gravity drainage component and also includes a convective flow mechanism which operate concurrently.

Abstract: A cutting element for an earth-boring tool includes a substrate and volume of superabrasive material positioned on the substrate. The volume of superabrasive material includes a cutting face having at least one recess extending into the volume of superabrasive material and/or at least one protrusion extending outward from the volume of superabrasive material. The volume of superabrasive material includes a first chamfer surface having a peripheral edge and a radially innermost edge. The peripheral edge of the first chamfer surface is located proximate a cutting edge of the volume of superabrasive material. A radial width of the first chamfer surface is between about 0.002 inch and about 0.045 inch. The volume of superabrasive material also includes a second chamfer surface having a peripheral edge and a radially innermost edge. The peripheral edge of the second chamfer surface is located adjacent the radially innermost edge of the first chamfer surface.

Abstract: By removing material of low permeability from within and around a perforation tunnel and creating at least one fracture at the tip of a perforation tunnel, injection parameters and effects such as outflow rate and, in the case of multiple perforation tunnels benefiting from such cleanup, distribution of injected fluids along a wellbore are enhanced. Following detonation of a charge carrier, a second explosive event is triggered within a freshly made tunnel, thereby substantially eliminating a crushed zone and improving the geometry and quality (and length) of the tunnel. In addition, this action creates substantially debris-free tunnels and relieves the residual stress cage, resulting in perforation tunnels that are highly conducive to injection under fracturing conditions for disposal and stimulation purposes, and that promote even coverage of injected fluids across the perforated interval.

Abstract: A drilling tool changer apparatus for a drilling rig includes a drill tower pivotable between a drilling orientation and a change-out orientation, the drill tower supporting a drill string comprising a drill pipe coupled to a drilling tool. The drilling tool changer apparatus also includes a drilling tool storage device pivotally movable about a hinge axis between a stowed position and a deployed position. The drilling tool storage device includes a drilling tool storage cassette including a replacement drilling tool. The drilling tool storage device and the drill tower are pivotally alignable in a substantially co-planar manner when the drilling tool storage device is in the deployed position and the drill tower is in the change-out orientation.

Abstract: Embodiments of the disclosure pertain to a downhole tool useable for isolating sections of a wellbore that includes a mandrel and a slip comprising a one-piece configuration disposed around the mandrel. The mandrel further includes a body comprising an external surface, and an inner bore formed therein; a distal end; and a proximate end; wherein the mandrel is made of composite material, wherein a set of shear threads are disposed along a surface of the inner bore at the proximate end.

Abstract: A method for servicing a subterranean formation comprising providing a wellbore penetrating the subterranean formation, and placing a wellbore servicing tool in the wellbore, wherein the wellbore servicing tool comprises a baffle, wherein the baffle comprises a seat contoured to match a spherical zone of an obturator.

Abstract: A steerable drill bit may be used to drill a lateral borehole from a primary wellbore. The steerable drill bit may be part of a bottomhole assembly that also includes a directional control system. A deflection member, such as a whipstock, may be anchored in the primary wellbore. When the bottomhole assembly approaches the deflection member, the directional control system may steer the steerable drill bit to reduce and potentially eliminate contact between the steerable drill bit and a ramped surface of the deflection member. By restricting contact between the deflection member and the steerable drill bit, cutting elements of the steerable drill bit may obtain an increase in cutting efficiency and/or effective life.