Halliburton Energy Services, Inc.

Austin Lee Wright

Stephen Michael Greci

Ryan Wesley McChesney

Ryan Wesley Mcchesney

Paul Gregory James

Peter Reid Maher

Ryan Michael Novelen

Nicholas A Kuo

Liam Andrew Aitken

Matthew Ryan Gommel

Uriel Arias

Boon Yen Er

Matthew Gommel

This disclosure provides a downhole debris removal apparatus, a method for operating a downhole debris removal apparatus, and a well system including the same. The downhole debris removal apparatus, in one aspect, includes an inner pipe positioned within a tubular, and a filtration member substantially encircling the inner pipe. The downhole debris removal apparatus, in this aspect, further includes a cleaning assembly positioned radially about at least a portion of the filtration member, the cleaning assembly configured to move relative to the filtration member to dislodge particulate matter from the filtration member.

Debris removal apparatus with self cleaning filter assembly, well system, and method of use

A downhole shunt tube isolation system includes an isolation sleeve housing defining an isolation sleeve chamber and an isolation sleeve moveable within the isolation sleeve chamber between an open position and a closed position. The isolation sleeve has a slurry pathway that fluidically couples a first slurry tube segment to a second slurry tube segment with the isolation sleeve in the open position and fluidically decouples the first slurry tube segment from the second slurry tube segment in the closed position. The downhole shunt tube isolation system further includes a fluid channel in communication with the isolation sleeve chamber. The channel is initially closed to hydraulically lock the isolation sleeve in the open position. Additionally, the downhole shunt tube isolation system includes an actuation mechanism configured to open the fluid channel to hydraulically unlock the isolation sleeve and a biasing member to bias the isolation sleeve to the closed position.

Downhole shunt tube isolation system

A method and apparatus according to which a connection between first and second completion joints is made up. The first and second completion joints each include a base pipe and a shunt tube disposed along the base pipe. The respective base pipes of the first and second completion joints are threadably engaged to form a pin and box connection. The shunt tube of the first completion joint is coupled to the shunt tube of the second completion joint using a jumper tube. The jumper tube is supported at a position longitudinally between the respective shunt tubes of the first and second completion joints using a first support member. In some embodiments, the first support member is longitudinally slidable along the base pipe of the first or second completion joint to the position between the respective shunt tubes of the first and second completion joints.

Jumper tube support member

A well screen for a borehole. The well screen may include an arcuate outer shroud, a mesh layer, and a drainage layer. The arcuate outer shroud may include perforations, a first longitudinal end, and a second longitudinal end. The first and second longitudinal ends may be spaced arcuately apart such that a gap is formed between the first and the second longitudinal ends of the outer shroud. The mesh layer may restrict flow of particulate materials of a predetermined size from passing therethrough and is positioned radially inward from the outer shroud. The mesh layer may include a first and a second longitudinal end that are radially aligned with the first and the second longitudinal ends of the outer shroud to continue the gap. The drainage layer may be positioned radially inward from to the mesh layer and may include at least one of perforations or louvers.

Well screen for use with external communication lines

A method of controlling a flow of a fluid through an inflow control device comprising a tubular within which a sliding sleeve having a longitudinal fluid passageway extends, the method includes longitudinally shifting the sliding sleeve, relative to the tubular, into a first, second, or third position, with each position associated with a different pressure differential between an external pressure applied to an external surface of the tubular with an internal pressure within the longitudinal fluid passage, and selecting a first, second, or third flow setting that corresponds with the first, second, and third pressure differential, respectively, at a surface of a well in which the inflow control device is received.

Multi-position inflow control device

An adjustable fluid injection tool for use in a wellbore may be used to provide steam to a wellbore annulus. The tool may be adjusted immediately before being positioned in a well. Fluid may exit an inner space of the tool into an accumulation chamber, after which the fluid may exit the tool through one or more adjustable valves. An adjustable valve may be formed between a valve seat of a shroud and a valve plug of a plug sleeve. The plug sleeve may be positioned around a tubular of the tool and able to translate linearly with respect to the shroud by rotating the plug sleeve, thus adjusting the adjustable valve and controlling fluid flow out of the tool.

Adjustable steam injection tool

Fluid injection tools for use in a wellbore can be configured on-site prior to run-in and can be opened or closed on demand when positioned in the well. A fluid injection tool can be used to provide steam to a wellbore annulus during a steam assisted gravity drainage procedure. Nozzles in the tool through which the steam escapes can be individually plugged to enable fine-tuning of steam output to match a desired steam output for that particular tool's location within the wellbore. A sliding side door can be actuated, such as by a shifting tool inserted within the inner diameter of the fluid injection tool, to enable or disable steam output from the fluid injection tool.

Growing community of inventors

Dallas, TX, United States of America

Austin Lee Wright