A method, system and apparatus of optimizing operation of one or more tubing strings in a hydrocarbon well are provided. Each tubing string is located in a hydrocarbon well and has a plurality of valves. Each valve is actuatable between a fully open position and a fully closed position and is in communication with a respective zone of a formation defining a reservoir containing hydrocarbon material. The method includes characterizing an injectivity of one or more zones of the formation and determining an optimal operating schedule in accordance with the characterization. The optimal operating schedule comprises one or more valve configurations and an operating duration for each of the one or more valve configurations.

A mud pulse telemetry valve assembly and method including a mud valve sub and a mud pulse telemetry valve. The mud pulse telemetry valve having a flow tube positioned within the mud valve sub in a way that at least a portion of an outer surface of the flow tube is spaced a distance from at least a portion of an inner surface of the mud valve sub to form a hydraulic passageway having an upstream end and a downstream end. The mud pulse telemetry valve further having a control valve assembly and a pilot valve assembly.

A system and method for hydraulic isolation of a downhole powered system. The system and method include a sliding sleeve, venting assemblies with venting ports, and check valves associated with a vent body, and an isolation sleeve, isolation valve, and integral packer for controlling fluid flow through the motor and pump assembly of the powered system. Also disclosed is a wet connect mandrel modified to receive the isolation sleeve, the isolation sleeve preferably capable of permitting the passage of tools therethrough and capable of preventing fluid through the inlet of the mandrel. The mandrel may also be outfitted with a built in sliding sleeve. The sleeves, valves and packer can be actuated mechanically, hydraulically or electrically. Electrical actuation can be facilitated using the power from an adjacent wet connect mandrel.

A downhole connection includes a rotating member and an independently rotating member. A solenoid is connected to the independently rotating member and a moving member is connected to the rotating member. The moving member is movable by the solenoid and connected to an actuation valve of a downhole tool on the rotating member.

A downhole device and method to trigger, shift, and/or operate a downhole device of a drilling string in a wellbore is disclosed. At a high level, the disclosed device causes a portion of drilling fluids to bypass the drill bit and into the annulus. The bypass may be triggered upon certain conditions related to the rotation speeds of the drill string or other conditions such as the pressure of the drilling fluids. For example, the drill string may be rotated in some protocol of operation (e.g., stop at certain rpm, and/or stop at certain other rpm) to describe a recognizable series of signals to an accelerometer and/or microprocessor that will communicate to pumps or valves to operate or pause/stop operations.

Control valves can allow a well operator to steer a drill string. An exemplary control valve can include a valve body with an axial bore and a radial orifice in fluid communication with the axial bore, wherein flow passing through the axial bore passes through the radial orifice and into a piston 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 a steering pad for applying force against the wellbore wall. A rotary valve element is disposed within the axial bore and including an actuation flow channel, wherein the rotary valve element is rotatable with respect to the axial bore to change flow through the actuation channel and the radial orifice to modify fluid pressure within the piston flow channel that is exerted against the piston.

The present disclosure provides a gullet mandrel for fluid flow optimization in a wellbore. The gullet mandrel may be coupled to a downhole valve, such that a tubing string in a wellbore will have a plurality of valves coupled to a plurality of mandrels. Each gullet mandrel may have a valve recess and one or more gullets (or grooves) located in an exterior portion of the mandrel body. The gullets may have a wide variety of configurations, and may be formed in a portion, a majority, or substantially all of the mandrel. The gullets may direct movement of fluid exterior to the tubing string and help force fluid into a laminar or linear flow pattern and prevent the formation of slug flows and/or lessen the problems encountered by slug flows. The disclosed gullet mandrel may be used in any fluid injection or production operation, such as gas-lift operations.

A completion assembly having a wireless adjustable electronic flow control node disposed along the sand screen base pipe to control flow of a fluid through a shunt tube assembly adjacent a sand screen. Each electronic flow control node includes a valve that can be adjusted by an electric actuator powered by a power harvesting mechanism disposed in a flow path of the completion assembly. A wireless transmitter receives a control signal to control the electric actuator. The control signal may be transmitted to open or close a packing tube or a transport tube of the shunt tube assembly.

Embodiments of systems and methods for generating power in the vicinity of a drilling rig are disclosed. During a drilling operation, heat generated by drilling fluid flowing from a borehole, exhaust from an engine, and/or fluid from an engine's water (or other fluid) jacket, for example, may be utilized by corresponding heat exchangers to facilitate heat transfer to a working fluid. The heated working fluid may cause an ORC unit to generate electrical power.

The disclosure describes hydrocarbon flowline corrosion inhibitor overpressure protection. Such a protection system includes a fluid flow pathway fluidically coupled to a corrosion inhibitor injection pump that injections corrosion inhibitor into a hydrocarbon carrying flowline. When the injection pump pressure exceeds a threshold flow pressure, the corrosion inhibitor is flowed through a first branch of the fluid flow pathway to relieve the excess pressure. The first branch is fluidically isolated from a second branch. When a rupture disc in the first branch fails, then the corrosion inhibitor is diverted to flow through the second branch and the first branch is isolated from the corrosion inhibitor flow.