A system and method for fracturing multiple zones along a length of a wellbore during a single run are provided. A single magnetic shifter device may be lowered on coiled tubing to shift open multiple sleeve assemblies set along the wellbore to expose different fracture zones for desired fracturing treatments. The sleeve assemblies may each include a magnetic sensing system designed to detect a magnetic field output from the shifter device. The magnetic sensing system may output a control signal to an electro-hydraulic lock to collapse a baffle component of the sleeve assembly. Once the baffle is collapsed, an isolation component of the shifter device may engage the collapsed baffle to form a plug through the wellbore. Pressure applied from the surface may push the baffle and a sliding sleeve of the sleeve assembly downward, thereby exposing fracturing ports through the casing of the wellbore.

An apparatus has been described, including a tubular housing including opposing first and second end portions and defining an interior surface, an exterior surface, and an internal flow passage; an open inflow area extending radially through the tobular housing and adapted to distribute the radial flow of a fluid from the internal flow passage to the wellbore; a closure member extending within the tubular housing and adapted to cover the open inflow area; and a filter defining a plurality of gaps, the filter concentrically disposed about the exterior surface of the tubular housing and extending axially along at least the open inflow area. In an exemplary embodiment, the open inflow area includes a plurality of openings formed radially through the tubular housing and defining a tubular injection interval extending axially along the tubular housing. A system and assembly have also been described, each incorporating elements of the above described apparatus.

An apparatus has been described, including a tubular housing including opposing first and second end portions and defining an interior surface, an exterior surface, and an internal flow passage; an open inflow area extending radially through the tobular housing and adapted to distribute the radial flow of a fluid from the internal flow passage to the wellbore; a closure member extending within the tubular housing and adapted to cover the open inflow area; and a filter defining a plurality of gaps, the filter concentrically disposed about the exterior surface of the tubular housing and extending axially along at least the open inflow area. In an exemplary embodiment, the open inflow area includes a plurality of openings formed radially through the tubular housing and defining a tubular injection interval extending axially along the tubular housing. A system and assembly have also been described, each incorporating elements of the above described apparatus.

In some embodiments, an apparatus and a system, as well as a method and article, may operate to identify one or more multiphase fluid flow regimes as an output of fuzzy logic processing, with inputs to the fuzzy logic processing comprising a set of physical parameter values as attributes at a location in a fluid flow that are determined by at least one of measurement or simulation, and to operate a controlled device based on the output. Additional apparatus, systems, and methods are disclosed.

In some embodiments, an apparatus and a system, as well as a method and article, may operate to identify one or more multiphase fluid flow regimes as an output of fuzzy logic processing, with inputs to the fuzzy logic processing comprising a set of physical parameter values as attributes at a location in a fluid flow that are determined by at least one of measurement or simulation, and to operate a controlled device based on the output. Additional apparatus, systems, and methods are disclosed.

A ball launcher for launching a plurality of balls into a well, including an endless conveyor belt, the conveyor belt forming a plurality of ball retainers, each operable to contain one of the plurality of balls, a drive motor for selectively driving the conveyor belt, and a brake for braking the conveyor belt.

A method of using a downhole tool that includes the step of operating a workstring to run the downhole tool into a wellbore to a desired position. The downhole tool includes a mandrel having a proximate end with a first outer diameter; a distal end with a second outer diameter; a flowbore; and an inner set of shear threads disposed in the flowbore at the proximate end.

A corrodible downhole article includes a magnesium alloy. The magnesium alloy includes: 1-9 wt % Zn; 1-2 wt % Cu; 0.5-1.0 wt % Mn; and 0.1-5 wt % of a corrosion promoting element (e.g., Ni). The alloy can have a 0.2% proof strength of at least 150 MPa when tested using standard tensile test method ASTM B557-10.

Injection of CO.sub.2 may be controlled and optimized, and CO.sub.2 plume leaks monitored in real time, using a controlled sleeve system deployed into a well, where the controlled sleeve system comprises a predetermined set of ports extending from an outer surface of a substantially tubular housing through to an inner annulus of the housing and one or more selectively actuated sliding sleeves configured to selectively open, occlude, and close the predetermined set of ports. One or more sensors configured to be deployed in the well may be present. A wireless remotely actuated flow controller disposed at least partially within the housing and operatively in communication with the sensor comprises a sleeve actuator controller operatively connected to the selectively actuated sliding sleeve and a sensor data acquisition module operatively in communication with the sensor. A communications module is operatively in communication with the wireless remote actuated flow controller. Power may be supplied via a power supply operatively in communication with the wireless remote actuated flow controller, the communications module, and the sensor. The controlled sleeve system is placed into communication with a surface control system disposed proximate a surface location of the well and CO.sub.2 injected into a geological formation of the well, at least partially through the controlled sleeve system. The surface system is used to selectively actuate the selectively actuated sleeve to selectively choke, occlude, and permit the flow of CO.sub.2.

A wellbore lining system that puts liners into place immediately behind the drill head tool is used in drilling and for preparing natural gas hydrate (NGH) deposits for production of its natural gas. The system overcomes the requirement of setting casing from the wellhead, which controls well bore diameter with depth and allows for flexibility in well bore size at any depth. Wellbore liners stabilize the well walls by being very tightly fitting against bounding rocks and sediments, which overcomes the requirement for cementing, which commonly accompanies conventional well casing. In addition, liners can be emplaced with designed impermeability, permeability, and complex flow-through patterns so that production processes, such as sand flow, can be put in place as part of a liner section.