Abstract: An oilwell choke can include a choke body having an inlet and an outlet, a seat, a gate configured to optionally sealingly engage the seat, and an at least partially curved choke profile. A gate can include an at least partially curved gate profile and a seat can include an at least partially curved seat profile. A choke profile can have one or more radiuses of curvature. At least a portion of a choke profile can be elliptical. An oilwell choke can include a secondary closure, which can include an annular tongue configured to sealingly engage an annular groove.

Abstract: The present disclosure provides a valve assembly comprising a valve section, a power section, and an electronics section. The valve assembly is configured to mate with a tubing sub (and/or mandrel) inserted in-line with a tubing string inserted into a wellbore. The valve allows for injection into or production from the tubing string. The valve assembly comprises an electric motor and a motor controller permitting fine control over the valve, as well as sensors which measure various parameters, such as fluid flow, valve position, pressure, temperature, and/or water cut. A cable connects the valve assembly to the surface and provides power and data telemetry and allows control of the valve assembly with a remote electronic signal. Multiple valve assemblies may be provided at spaced intervals along the tubing string and individually monitored and/or controlled by a remote location. Also disclosed is a method for operation of such valve assemblies.

Abstract: A mechanical seal arrangement includes a first mechanical seal with a rotating slide ring and a stationary slide ring, which define a sealing gap in between them. The mechanical seal arrangement includes a first sealing space that is filled with a sealing liquid. The first mechanical seal seals off the sealing space against a surrounding area, a first piston arrangement with a piston element and flexible wall areas that define a first piston interior space, wherein the first piston interior space is in fluid connection with the first sealing space. A piston outer surface of the piston element is in fluid connection with the surrounding area, and a first pre-stressing appliance that exerts a first preload force (F1) on the piston element of the first piston arrangement.

Abstract: A drill bit that serves to remove mineral materials and that consecutively has on a longitudinal axis (6) a drill head (2), a helix (3), an insertion end (4) and an impact surface (7) on the end face of the insertion end (4) that faces away from the drill head (2) and that serves to absorb impact along a direction of impact (8), is provided. The drill head (2) has at least two cutting edges (13) and at least two blades (20). The cutting edges (13) each have a cutting face (16) and a free face (17). The blades (20) run parallel to the longitudinal axis (6) and adjoin the cutting edges (13). The blades (20) each have a radially projecting tooth (24) that adjoins the cutting face (16), whereas it adjoins the free face (17) either only partially or not at all. The axial dimension (29) of the tooth (24) is smaller than the axial dimension (25) of the blade (20).

Abstract: Examples of the present disclosure relate to systems and methods for an encapsulated heating cable within a wellbore. Embodiments may have the durability required for the hazardous and harsh environment of a wellbore, and to provide sufficient heat within the production string to reduce and/or eliminate deposits.

Abstract: A method and apparatus for removing dissolved gas from multiple levels of a coal bed or other type of gas bearing formations is provided.

Abstract: Embodiments include an energizing ring for setting a downhole seal includes a body having a varied cross-section along at least a portion of an axial length. The energizing ring also includes a plurality of peaks forming at least a portion of the varied cross-section having a first diameter. The energizing ring also includes a plurality of valleys forming at least a portion of the varied cross-section having a second diameter, the first diameter being larger than the second diameter, and respective valleys of the plurality of valleys being arranged proximate respective peaks of the plurality of peaks.

Abstract: A system includes a turbine, a valve, and an electronics package. The turbine is configured to generate electricity from a fluid flow through the turbine and the electronics package is configured to selectively actuate the valve between an open configuration and a closed configuration.

Abstract: Disclosed herein are embodiments of engineered geothermal systems (EGS). Also disclosed are methods and devices for the construction and use of planar artificial fractures in EGS wells, including wells that contain both an injection and extraction points.

Abstract: A pressure regulator is configured to manage a pressure downstream of a pump discharge during operation. A hydraulic piston is exposed to pressure upstream of the pressure regulator during operation. The hydraulic piston extends into a first fluid reservoir. The first fluid reservoir is defined by an inner surface of an outer housing of a subsurface safety valve. A subsurface safety valve is fluidically couple to the hydraulic piston.

Abstract: The present invention is a digging auger. The digging auger comprises a shaft with a proximal end and a distal end. The digging auger also comprises a screw extending from the proximal end to the distal end of the shaft. The digging auger further comprises a paddle attachment adapted to be removably attached at the proximal end of the shaft. The paddle attachment comprises two pieces of rubber strips arranged on opposing sides of the shaft and extending generally radially outwards therefrom.

Abstract: Provided is a downhole fracturing tool assembly, and a method for fracturing an oil/gas formation. The downhole fracturing tool assembly, in one aspect, includes a tool body, and a localized fracking system located within the tool body. In accordance with this aspect, the localized fracking system is designed to create a localized initial pulse of pressure sufficient to initiate a fracture of a subterranean zone of interest.

Abstract: A wellhead connection is disclosed that includes a means for selectively clamping a nightcap or crossover to a flange assembly through selective application of hydraulic pressure to a hydraulic motor and a means for selectively positioning a nightcap through selective application of hydraulic pressure to a plurality of hydraulic cylinders.

Abstract: An apparatus for deploying one or more components of a borehole monitoring system includes a conductor assembly having one or more communication devices connected along a length of a conductor, each communication device being configured to wirelessly communicate data and/or power, the conductor configured to transmit the data and/or the power through a borehole in an earth formation. The apparatus further includes a deployment device configured to transport and support the length of the conductor having the one or more communication devices connected along the length of the conductor and deploy the length of the conductor in the borehole.

Abstract: A tubular string is cut using a severing system deployed from the rig floor inserted through the BOP into the tubular string and landed in a fit-for-purpose wellhead. The cutting operation forms an excess tubular string and a remaining tubular string. Once cut, the excess tubular string is removed through the BOP. The system and its use eliminates the need to perform a cutting operation at the wellhead by personnel under the rig floor and the need for removal of the BOP thus reducing cost, saving time, and eliminating the inherent risk attendant with these operations.

Abstract: The bypass plungers are disclosed that are configured to provide a mechanical lock between a valve face of plunger and a the valve element of the plunger. More specifically, the valve face and the valve seat are correspondingly configured to allow the valve face to wedge into the interior of the valve seat such that the valve head becomes stuck within the interior of the valve seat.

Abstract: A screen assembly, such as a downhole/sand screen assembly, comprising first and second screen portions or screens longitudinally coupled together, wherein there is provided a fluid flow path between the first and second screen portions or screen. Optionally, the first and second sleeves are coupled or connected by a centralizer or further sleeve or screen, and/or optionally by or via first and second support ring.

Abstract: A screen assembly, such as a downhole/sand screen assembly, comprising first and second screen portions or screens longitudinally coupled together, wherein there is provided a fluid flow path between the first and second screen portions or screen. Optionally, the first and second sleeves are coupled or connected by a centralizer or further sleeve or screen, and/or optionally by or via first and second support ring.

Abstract: A downhole seal includes a field responsive shape changeable material configured as a layer having a first surface and a second surface, a first field generating electrode disposed in operable communication with the first surface, and a second field generating electrode disposed in operable communication with the second surface.

Abstract: A holddown assembly is provided for axially securing a pump in a wellbore. The assembly has a mandrel having at least one resilient holding element and at least one resilient sealing element. The holding elements are made of a durable material and configured to require a pre-determined seating force to seat the assembly in a seating tubular, and a pre-determined unseating force to unseat the assembly. The holding elements are configured to elastically deform when seated, such that the pre-determined seating and unseating force does not change significantly even over many seating/unseating cycles. The sealing elements are configured to sealingly engage with the seating tubular to prevent wellbore fluid from flowing thereby. As the sealing elements are only used for forming a fluid seal, and not for securing the pump, damage to the sealing elements as a result of repeated seatings and unseatings is mitigated.