Halliburton Energy Services, Inc.

Other

William Mark Richards

Thomas Jules Frosell

William David Henderson

Timothy Rather Tips

Syed Hamid

Tommy Frank Grigsby

Timothy Edward Harms

Christopher Robert Delzell

Bryon David Mullen

Ronald Glen Dusterhoft

Gregory William Garrison

Colby M Ross

Andy Cheng Chang

Floyd Randolph Simonds

Tyson Harvey Eiman

Kim Vance Thornton

Luke William Holderman

Thomas Owen Roane

Charles Timothy Smith

Eddie Eddieberto Perez

Carl Bismarck Ferguson

Paul F Rodney

Ralph Harvey Echols

Jean Marc Lopez

Travis Thomas Hailey, Jr

Phillip Terry Thomas

Scott Wendorf

Joshua Max Hornsby

Jason Earl Davis

James Ho

Ralph Harvey Echols, Iii

William Germany

Michael Linley Fripp

Stephen Michael Greci

John C Gano

Neal Gregory Skinner

Paul David Ringgenberg

Etienne M Samson

Brandon Thomas Least

Andrew Penno

David Joseph Walker

Cynthia Strickland Tuckness

James Flygare

Chester S McVay

Karla Sechere

Cody T Krupala

Carl Bismark Ferguson

Phil Terry Thomas

Colby Munro Ross

Phillip T Thomas

A sensing assembly for use in a wellbore comprises a wellbore component disposed in a wellbore tubular string, at least one gauge configured to sense at least one parameter, and at least one sensing link coupled to the at least one gauge. The at least one gauge is disposed at a first location along the wellbore tubular string, and the sensing link is configured to provide communication of at least one parameter from a sensing point at a second location to the first location. The sensing point is radially adjacent the wellbore component.

Method of placing distributed pressure and temperature gauges across screens

A sensing system comprises at least one gauge disposed in a wellbore, a sensing link coupled to the at least one gauge, and a debris barrier coupled to the sensing link. The debris barrier comprises a housing coupled to the sensing link, and a barrier element configured to reduce the transport of particulates from the wellbore into the sensing link.

Snorkel tube with debris barrier for electronic gauges placed on sand screens

Assemblies and methods of use are disclosed for determining a position of a body within a tubing section. A signal generator coupled to the body is operable to generate a pressure wave in response to detecting a detectable portion of the tubing section when the body is moved relative to the tubing section.

Position indicator through acoustics

A system for controlling flow in a wellbore can include a down-hole control module that is hydraulically coupled to multiple components of the system. The control module can include a computer, which can be preprogrammed to operate the various components in a particular sequence, and communicate confirmation or error signals to a surface location. The control module can also include a micro-hydraulic motor and pump that can that can be instructed by the computer to selectively deliver hydraulic fluid to one or more of the components of the system. The system can include isolation members such as packers, hydraulic pressure maintenance devices (PMDs), hydraulic sheer joints, inflow control devices or valves (ICDs or ICVs) and a three-position valve that can be actuated by the control module without necessitating communication with a surface location.

Remotely operated and multi-functional down-hole control tools

An apparatus and method according to which a zone of a wellbore that traverses a subterranean formation is completed. The apparatus includes a flow joint including a first internal flow passage, and a plurality of openings formed radially therethrough, a plurality of plugs disposed within the plurality of openings to form a fluid and pressure tight seal with the flow joint, thus impeding fluid flow through the plurality of openings, and a screen disposed exteriorly about the flow joint and axially along the plurality of openings, and thus also along the plurality of plugs, wherein, when the plurality of plugs are exposed to a downhole fluid, the plurality of plugs are adapted to degrade so that fluid flow is permitted through the plurality of openings. The plurality of plugs may include protective layers adapted to be damaged or removed to expose the plurality of plugs to the downhole fluid.

High flow screen system with degradable plugs

A system for controlling flow in a wellbore can include a down-hole control module that is hydraulically coupled to multiple components of the system. The control module can include a computer, which can be preprogrammed to operate the various components in a particular sequence, and communicate confirmation or error signals to a surface location. The control module can also include a micro-hydraulic motor and pump that can that can be instructed by the computer to selectively deliver hydraulic fluid to one or more of the components of the system. The system can include isolation members such as packers, hydraulic pressure maintenance devices (PMDs), hydraulic shear joints, inflow control devices or valves (ICDs or ICVs) and a three-position valve that can be actuated by the control module without necessitating communication with a surface location.

A system for controlling flow in a wellbore can include a down-hole control module that is hydraulically coupled to multiple components of the system. The control module can include a computer, which can be preprogrammed to operate the various components in a particular sequence, and communicate confirmation or error signals to a surface location. The control module can also include a micro-hydraulic motor and pump that can that can be instructed by the computer to selectively deliver hydraulic fluid to one or more of the components of the system. The system can include isolation members such as packers, hydraulic pressure maintenance devices (PMDs), hydraulic sheer joints, inflow control devices or valves (ICDs or ICVs) and a multi-position valve that can be actuated by the control module without necessitating communication with a surface location.

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 tubular 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.

High flow injection screen system with sleeves

Method of placing distributed pressure gauges across screens

An erosion protection system for closing sleeve assemblies is disclosed. A closing sleeve assembly including a housing; a port formed in the housing; a sealing surface formed in the housing adjacent to the port; a closing sleeve configured to move between an open position, in which a fluid flow through the port is permitted, and a closed position, in which the fluid flow through the port is prevented, the closing sleeve including a seal configured to engage with the sealing surface to form a fluid and pressure tight seal when the closing sleeve is in the closed position; and a protective sleeve configured to extend toward the port to substantially cover the sealing surface when the closing sleeve is moved to the open position and retract away from the port when the closing sleeve is moved to the closed position.

Erosion protection for closing sleeve assemblies

A method and apparatus that includes positioning a completion string that has an internal passageway and that has an external surface that at least partially defines an external region within a wellbore; isolating a zone of the external region from a wellbore hydrostatic pressure; measuring a pressure within the external region of the isolated zone; determining whether the pressure within the external region of the isolated zone is within a predetermined pressure range; and operating a valve that controls a flow of a fluid through a flow path from the internal region to the external region of the isolated zone when the pressure within the external region is outside of the predetermined pressure range.

Downhole pressure maintenance system using a controller

A method and apparatus that includes an elongated base pipe having an external surface at least partially defining an external region and an internal surface at least partially defining an internal region; and a pressure maintenance device disposed in the base pipe and comprising: a flow path that extends between the internal region and the external region; and a valve having a gas charged chamber, the valve allowing the flow of a fluid from the internal region to the external region through the first flow path when a pressure differential between a pressure associated with the internal region and a pressure associated with the gas charged chamber is less than a maximum pressure threshold and when a pressure differential between the external region and the pressure associated with the gas charged chamber is greater than a minimum pressure threshold.

Mechanical downhole pressure maintenance system

In accordance with embodiments of the present disclosure, a travel joint includes a tube disposed at one end of the travel joint and a mandrel disposed at an opposite end of the travel joint. The mandrel is partially disposed in a hollow portion of the tube, and the tube and the mandrel are axially slidable relative to each other to extend or compress the travel joint. The travel joint also may include a housing coupled to the tube and disposed around the mandrel and a locking mechanism between the housing and the mandrel disposed in a position to selectively lock the mandrel and the tube in an axial position relative to each other to partially compress the travel joint. In some embodiments, the travel joint may include a fluid brake having a fluid chamber disposed between the mandrel and the tube to dampen axial movement between the mandrel and tube.

Multiple control line travel joint with enhanced stroke position setting

A setting tool for setting a packer in a wellbore includes a housing defining a hydraulic chamber, a piston disposed in the chamber, a pump coupled to the chamber via a flowline, and a setting sleeve directly or indirectly coupled to the piston. The pump may be used to pump pressurized fluid into the hydraulic chamber for pushing the piston in a direction, and the setting sleeve may be used to apply a compressive force to a packer element of the packer in response to the piston being pushed in that direction. The setting tool may include a sensor used to collect a measurement relating to a force on the workstring, in addition to a controller designed to receive a signal from the sensor and to provide a control signal to the pump based on the sensor signal.

Packer setting tool with internal pump

Growing community of inventors

Flower Mound, TX, United States of America

William Mark Richards