Abstract: Systems and a method for efficient downhole separation of gas and liquids. An exemplary system provides a downhole gas separator for an artificial lift system. The downhole gas separator includes a separation section. The separation section includes a number of openings over an extended length, and wherein a size of each of the openings, a number openings, or both, is increased as a distance from a production tubing is increased.

Abstract: An apparatus and method are used in conjunction with a system for performing horizontal directional drilling, the system including a drill string extending from a drill rig to a boring tool such that the boring tool is steerable based on a roll orientation. The system also includes an arrangement for generating steering commands for guiding the boring tool to a target position. Responsive at least in part to the steering commands, a display is configured to selectively indicate each of a rotate command, a push command and a spin command. A steering indicator is described which indicates a current roll orientation of the boring tool. A 3-D grid can be animated and centered on either a steering or target indicator. Rounding of a steering command ratio can limit the display of target roll orientations to only those that a given boring tool transmitter is capable of sensing and indicating.

Abstract: The present invention comprises a drill cuttings composite core apparatus, system, and method that may utilize sieve shaker equipped with a solvent wash system to separate, clean, and size cuttings; a centrifugal mill equipped with a 12 tooth rotor and 1.0 mm ring sieve; a compactor mold that may be 1.5 inches in diameter and up to 6 inches long; dual piston compactor with independent air control valves; and a spacer on top of a bottom piston that may allow compacted core to be pushed up through top of mold for easy removal with no special tools or handling and so forth.

Abstract: A system and method for wireless load position sensor is disclosed.

Abstract: This application relates to systems and methods for stimulating hydrocarbon bearing formations using a downhole laser tool.

Abstract: A low cost, disposable, molded reinforcing insert which has a metal ring or a circular arrangement of threaded metal inserts encased therein, a low cost disposable stripper rubber for drill pipes or other tubulars which includes the molded reinforcing insert, and molding methods for forming the reinforcing insert and the stripper rubber.

Abstract: A composite material comprising a plurality of hard particles surrounded by a matrix material comprising a plurality of nanoparticles. Earth boring tools including the composite material and methods of forming the composite material are also disclosed. A polycrystalline material having a catalyst material including nanoparticles in interstitial spaces between inter-bonded crystals of the polycrystalline material and methods of forming the polycrystalline material are also disclosed.

Abstract: A system for operating a downhole system in a wellbore having pressure inlet ports formed in the production tubing, the one or more pressure inlet ports extending through the production tubing between the annular area and the outer surface of the conduit, the one or more pressure inlet ports being situated below a first top sealing device relative to the conduit. The system includes an annular pressure control valve coupled to a metal conduit below the one or more pressure inlet ports in the wellbore, the annular pressure control valve being configurable in an open position and in a closed position, where the annular pressure control valve transitions between the closed position and the open position responsive to the annular pressure. The system includes a second bottom sealing device coupled to a bottom portion of the conduit below the annular pressure control valve.

Abstract: A method and apparatus according to which a flow control device includes a housing and a flapper valve. The housing defines an internal passage in which the flapper valve extends. The flapper valve includes a seat and a flapper pivotably coupled to the seat. The seat includes an internal passage and an external surface. The internal passage of the seat extends along a longitudinal central axis that is offset from a longitudinal central axis along which the external surface of the seat extends and a longitudinal central axis along which the internal passage of the housing extends. This offset allows an internal annular recess of the housing to accommodate the flapper pivoting away from the longitudinal central axis of the internal passage of the seat by a distance of equal to or greater than a radius of the internal passage of the seat.

Abstract: A completion section includes a base pipe defining a central flow passage, an injection port, and a production port. A fracturing assembly includes a frac sleeve positioned within the central flow passage adjacent the injection port, a sensor that detects a wireless signal, a first frac actuator actuatable in response to the wireless signal to move the frac sleeve and expose the injection port, and a second frac actuator actuatable based on the wireless signal to move the frac sleeve to occlude the injection port. A production assembly is axially offset from the fracturing assembly and includes a production sleeve positioned within the central flow passage adjacent the production port, a filtration device arranged about the base pipe, and a production actuator actuatable based on the wireless signal or an additional wireless signal to move the production sleeve to an open position where the production ports are exposed.

Abstract: A method of reducing erosional peak velocity includes arranging a sand control screen assembly in an open hole section of a wellbore, the sand control screen assembly including a base pipe defining a plurality of flow ports, a sand screen arranged about the base pipe, and a wellbore isolation device deployed within an annulus defined between the sand control screen assembly and an inner wall of the wellbore. A fluid from a surrounding subterranean formation is circulated within the annulus, and the fluid within the annulus is diverted through the sand screen and into the base pipe upon approaching the wellbore isolation device. A peak velocity of the fluid flowing through the sand screen is reduced with a peak flux reducing assembly arranged axially adjacent the wellbore isolation device.

Abstract: A downhole tool includes a sand control device, a tubular member coupled to and positioned below the sand control device, a shifting device coupled to the tubular member, and a load-monitoring sensor coupled to the tubular member and positioned between the sand control device and the shifting device.

Abstract: Shaped charge slitting devices for control line disruption in a hydrocarbon well and related methods for sealing the hydrocarbon well. The shaped charge slitting devices include a plurality of shaped charges. Each shaped charge is configured to, upon actuation, transform a corresponding liner into a high-speed sheet portion, which is configured to form a circumferential slit within production tubing, and a low-speed slug portion, which is configured to at least partially seal the circumferential slit. The methods include positioning a shaped charge slitting device within a selected region of a tubing conduit, actuating the shaped charge slitting device to form a plurality of circumferential slits within the production tubing and also to sever a control line, pumping a sealing material into an annular space via a sealing material injection opening that extends between the tubing conduit and the annular space, and curing the sealing material to form a fluid seal.

Abstract: A shaped charge assembly for selectively expanding a wall of a tubular includes a housing comprising an outer surface facing away from the housing and an opposing inner surface facing an interior of the housing. First and second explosive units are each symmetrical about an axis of revolution. Each explosive unit includes an explosive material formed adjacent to a backing plate and includes an exterior surface facing and being exposed to the inner surface of the housing. An aperture extends along the axis from one backing plate to the other backing plate. An explosive detonator is positioned along the axis adjacent to, and externally of, the one backing plate. The first and second explosive units comprise a predetermined amount of explosive sufficient to expand, without puncturing, at least a portion of the wall of the tubular into a protrusion extending outward into an annulus adjacent the wall of the tubular.

Abstract: A drilling rig site may include at least one tubular configured to be inserted into a wellbore at the drilling rig, at least one imaging device configured to detect a location of an end of the at least one tubular or a feature of the at least one tubular, and a processor receiving an input from the at least one imaging device and configured to calculate a distance between the end of the at least one tubular and another element, a diameter of the at least one tubular, or movement of the at least one tubular. A method for completing a drilling operation at a rig site, may include capturing an image of a tubular at a rig site, the tubular configured to be inserted into a wellbore at the rig site, detecting a location of an end of the tubular or a feature of the tubular from the image, and determining a diameter of the tubular, a distance between the detected end of the tubular and another element, or movement of the tubular.

Abstract: A rod centralizer and solids control assembly can be mounted on a rod string. The assembly allows well fluid containing high solids to pass through the pump while eliminating the solids from being swept back into the pump barrel or accumulating in the tubing. The assembly can include a body portion coupled to a bristle positioned helically around the body portion. The bristle can be coupled to a piston, allowing the bristle to extend during upward fluid movement and retract when rod rotation stops. The bristle can trap solids, leaving the solids higher and away from a pump intake. This can allow the solids to be lifted out of the pump, preventing solids from collecting on a bottom portion of the pump or tubing. The assembly can include centralizer components that center the rod, preventing it from rubbing against the tubing. Multiple assemblies can be incorporated into the rod string.

Abstract: An electric submersible pump (ESP) is described. The ESP includes a stator chamber, a stator within the stator chamber, a rotor, and an electrical connection. The stator chamber is configured to reside in a wellbore. The stator chamber is configured to attach to a tubing of a well. The stator chamber defines an inner bore having an inner bore wall that, when the stator chamber is attached to the tubing, is continuous with an inner wall of the tubing. The rotor is positioned within the inner bore of the stator chamber. The rotor includes an impeller. The rotor is configured to be retrievable from the well while the stator remains in the well. The stator is configured to drive the rotor to rotate the impeller and induce well fluid flow in response to receiving power through the electrical connection.

Abstract: A sheave wheel includes a housing; a wheel attached to the housing and configured to rotate relative to the housing; a depth and tension measurement system attached to the housing and configured to measure a parameter associated with the wheel; and a local control system attached to the housing and configured to exchange information associated with the measured parameter in a wireless manner with a ground control system.

Abstract: A sheave wheel assembly includes a housing; a wheel attached to the housing and configured to rotate relative to the housing; an imaging system attached to the housing and configured to obtain images of a surrounding of the sheave wheel assembly; and a transceiver attached to the housing and configured to send the images in a wireless manner to a ground control system.

Abstract: There is provided a wellhead assembly that includes a production well, a first valve, process equipment, a transport pipe for transporting fluid away from the wellhead assembly, and piping fluidly connecting the production well to the first valve, process equipment, and the transport pipe. The first valve is located between the production well and the process equipment, and there is a fall in the piping between the first valve and the transport pipe such that when the first valve is closed liquid will drain from the first valve into the transport pipe under the action of gravity. There is also provided a method of draining the wellhead assembly, an arrangement for depressurising the wellhead assembly using a service line and a method of depressurising the wellhead assembly.