Abstract: A device for opening or closing a fluid flow path comprises: a fluid inlet, wherein the fluid inlet comprises one end of the fluid flow path; an inlet covering, wherein the inlet covering is adjacent to the fluid inlet; and a material, wherein the material is capable of expanding or contracting via a change in temperature; wherein the expansion or contraction of the material causes movement to the inlet covering, and wherein the movement of the inlet covering either opens or closes the fluid flow path. A method for opening or closing a fluid flow path using the device comprises: allowing or causing a change in temperature to the material.

Abstract: A technique provides a system and methodology for treating a plurality of zones, e.g. well zones. A plurality of flow control devices is located along a tubular structure, such as a well string in a wellbore. Each flow control device comprises a seat member with an annularly located recess having a unique profile relative to the annularly located recesses of the other flow control devices. Darts are designed with engagement features sized to correspond with selected annularly located recesses. Each dart may have an engagement feature of a specific length designed to engage the corresponding recess of a specific flow control device to enable actuation of that flow control device once the dart is dropped through the tubular structure.

Abstract: A controller for operating a downhole tool includes a tubular body; a seat disposed in the body for receiving first and second pump-down plugs, at least a portion of one of the seat and the plugs being radially displaceable to pass through or allow passage of the other at a first threshold pressure differential; a catcher located below the seat for receiving the plugs after passing through the seat; a toggle linked to the seat to alternate between a locked position and an unlocked position in response to seating of the plugs; and a control mandrel for engaging a piston of the downhole tool and linked to the toggle: to be longitudinally movable between a first position and a second position when the toggle is unlocked, and to be prevented from movement from the first position to the second position when the toggle is locked.

Abstract: The present disclosure is directed toward a downhole tool used to free stuck tools in a wellbore and the method of using the downhole tool. The downhole tool includes at least one packer element for engaging a casing in a wellbore. The packer works to isolate one area of the casing from another. The downhole tool also includes at least one slip element for engaging the casing to maintain the position of the downhole tool in the casing or wellbore. Further, the downhole tool includes a mandrel slidably disposed within the at least one packer element and the at least one slip. The mandrel includes at least one port disposed therein above the at least one packer element when the mandrel is in a first position.

Abstract: Present embodiments are directed toward a drilling system that includes a conduit configured to route a pressurized gas to a top drive of a drilling rig. The drilling system also includes one or more cables disposed in the conduit. The one or more cables are configured to provide communication, power, or both, to the top drive.

Abstract: A downhole apparatus is described comprising a body and a sealing arrangement located on the body. The body has a longitudinal axis and the sealing arrangement comprises at least one elongated sealing member with an axis of elongation extending around the longitudinal axis. The sealing member comprises a material selected to expand on exposure to at least one predetermined fluid, such as a hydrocarbon or aqueous fluid encountered in a wellbore. A method of forming the apparatus and methods of use are described. Embodiments of the invention relate to wellbore packers.

Abstract: Embodiments of a downhole drilling assembly generally include a rotatable lower drilling assembly, a rotatable upper drilling assembly, and a drill bit, wherein the upper drilling assembly contains a mud motor adapted for clockwise rotation of its stator and counter-clockwise rotation of its rotor, whereby the lower drilling assembly is rotatable in the opposite direction of the upper drilling assembly or maintainable in a non-rotating state. The apparatus further includes sensors adapted to continuously measure physical properties and/or drilling parameters and a mechanism for continuously transmitting information relating thereto to the surface.

Abstract: A spider and method for supporting a tubular within a well bore. Radial dogs, controlled by cylinders that extend and retract simultaneously, are operable to support the tubular by the lower lip of a box connector. When a tubular connector is set down upon the dogs so as to depress one or more triggers located thereon, an interlock in a control system is actuated to prevent movement of the dogs. However, even while the spider is thus loaded, the dogs may nevertheless be retracted via an emergency override mechanism thereby allowing the tubular to be dropped into the wellbore. When the tubular has been lifted off of the triggers, the interlock is deactivated, and the dogs of the spider can be operated once again. The triggers may actuate sensor valves located within the dogs, which in turn actuates an interlock valve isolating the flow path of the cylinders.

Abstract: Control device (100) controlling a drilling operation and methods by which the dynamics of the continuum in question can be divided into superimposed waves, of which the wave traveling in the direction of the actuator and/or drive (10) is compensated by the actuator. This prevents reflection of the energy on the actuator. By using two sensors (30, 40) the wave traveling towards the actuator (10) and the wave traveling away from the actuator (10) can be calculated separately from one another, so that both the parameters of the wave traveling toward the actuator and the parameters of the wave traveling away from the actuator can be determined in order to be able to perform a control of the driving device of the drill string (20) on this basis.

Abstract: A technique facilitates control over the orientation of a bottom hole assembly. The bottom hole assembly comprises an orienting tool having a dual-spline drive which, in turn, comprises a first lead screw portion and a second lead screw portion having threads of a first pitch and a second pitch, respectively. A motor is connected to the dual-spline drive to impart rotational motion with respect to the first threads having the first pitch. A difference in pitch between the first pitch and the second pitch enables the rotational motion imparted by the motor to be converted to a slower, higher torque, output via the second lead screw portion. As a result, the orienting tool is able to provide a selective, high torque, low-speed adjustment to the drilling orientation of the bottom hole assembly.

Abstract: Micro-electro-mechanical systems lost circulation materials (MEMS-LCMs) of various sizes, shapes, and specific gravities may be used in a drilling fluid to determine the preferred LCMs for use in wellbore strengthening of the wellbore. For example, a method may include drilling at least a portion of a wellbore penetrating a subterranean formation with a drilling fluid that comprises a base fluid, a plurality of MEMS-LCMs, and a plurality of LCMs, wherein the MEMS-LCMs and the LCMs are substantially similar in size, shape, and specific gravity; measuring a first concentration of the MEMS-LCMs in the drilling fluid before circulating the drilling fluid through the wellbore; measuring a second concentration of the MEMS-LCMs in the drilling fluid after circulating the drilling fluid through the wellbore; performing a comparison of the first and second concentrations of the MEMS-LCMs; and changing a composition of the drilling fluid based on the comparison.

Abstract: A rotating control device can include a rotatably mounted seal which sealingly engages a drill string, and a gripping device which grips the drill string and thereby forces the seal to rotate with the drill string. A drilling method can include positioning a drill string in a rotating control device, gripping the drill string with a gripping device of the rotating control device, and rotating the drill string, gripping engagement between the gripping device and the drill string causing a seal of the rotating control device to rotate along with the drill string. A well system can include a drill string, and a rotating control device including a seal which sealingly engages the drill string and a gripping device which grippingly engages the drill string.

Abstract: A downhole apparatus connected to a workstring within a wellbore. The workstring is connected to a bit member. The apparatus includes a mandrel operatively connected to a downhole motor mechanism, an anvil member operatively formed on the bit member, the anvil member being operatively connected to the mandrel, a radial bearing housing unit operatively connected to the workstring, with the radial bearing housing unit being disposed about the mandrel, and a hammer member slidably attached to the radial bearing housing unit.

Abstract: A bottomhole assembly (BHA) coupled to a drill string includes one or more controllers, and a hole enlargement device that selectively enlarges the diameter of the wellbore formed by the drill bit. The hole enlargement device includes an actuation unit that may move extendable cutting elements of the hole enlargement device between a radially extended position and a radially retracted position. The actuation unit may be responsive to a signal that is transmitted from a downhole and/or a surface location. The hole enlargement device may also include one or more position sensors that transmit a position signal indicative of a radial position of the cutting elements. In an illustrative operating mode, one or more operating parameters of the hole enlargement device may be adjusted based on one or more measured parameters. This adjustment may be done in a closed-loop or automated fashion and/or by human personnel.

Abstract: A drilling assembly positionable in a well bore includes a turbine motor couplable to a drill string and a harmonic drive transmission coupled to the turbine motor. The harmonic drive transmission includes a circular spline, a wave generator, a flexspline, and a sealing subsystem. The sealing subsystem defines a substantially sealed volume containing the circular spline, wave generator, and flexspline, and isolates the circular spline, wave generator, and flexspline from drilling fluid exiting the turbine motor and flowing through the harmonic drive transmission.

Abstract: A device for processing hydrocarbon resources in a subterranean formation may include a radio frequency (RF) source, a dielectric cooling liquid source, and an RF applicator in the subterranean formation and coupled to the RF source to supply RF power to the hydrocarbon resources. The RF applicator may include concentric tubular conductors defining cooling passageways therebetween coupled to the dielectric cooling fluid source. At least one property of the dielectric cooling liquid, a flow rate of the dielectric cooling liquid, and a configuration of the cooling passageways may be operable together to generate a turbulent flow of the dielectric cooling liquid adjacent surfaces of the plurality of concentric tubular conductors to enhance thermal transfer.

Abstract: A system and method is provided for the controlled entry of a tubing string, and cable adjacent thereto, into a wellbore. A stationary housing is fit to a wellhead and has a bore in communication with the wellbore. The cable can be laterally displaced from the bore into a cable access formed into the side wall of the stationary housing for fitting a sealing assembly to the bore and engages a sealing surface therein. The sealing assembly seals tubulars passing therethrough. The cable access interrupts the sealing surface. A cable bypass sub is fit to the cable access and permits the cable to extend sealingly from above the sealing surface to the wellbore wherein the cable bypasses the sealing assembly and sealing surface. A seal reconstitutes the interrupted portion of the sealing surface at the cable access.

Abstract: A fluid injection device (18) for controlling injection of fluid into an oil-carrying tube in an oil well includes an inlet (20) for receiving the fluid; an outlet (28) for supplying the fluid for injection into the oil-carrying tube; an inlet valve (22) in a fluid path between the inlet and the outlet; an actuator (24) for opening and closing the valve; and a connector (36) for coupling the inlet to a fluid supply tube (32) extending between the device and a source of the fluid above the ground. A method of controlling injection of fluid using such a device is also provided.

Abstract: An electronically activated tool (50) comprising a tool body, cutter blocks and sensors with means for attachment to a drilling support and rotation so as to permit the simultaneous underreaming and measurement of the diameter of a wellbore (especially in oil and gas drilling) characterized by a means of activation using an electronic signal sent by mud-pulse, fiber-optics, wireless transmission or other means which may also communicate commands and receive data from the underreamer during drilling, at least one radially extendable cutter block (62) incorporating positional sensors adapted to measure the relative position of the cutter block to the tool, at least one calliper means (76) to measure wellbore diameter, all of which are inter-linked by a means of communication using receivers, sensors and microprocessors and a system that optimizes underreaming or expansion (22) by simultaneously comparing and correlating wellbore diameter data (22) and underreaming parameters in real-time or in memory.

Abstract: A directional drilling tool which comprises a pair of shafts with an eccentric bore to vary the radial position of a stabilizer, such tool including one or more eccentric couplings which are used to transmit torque between a pair of elements of the tool which are intended to be movable relative to each other in a direction transverse to their longitudinal axes.