Halliburton Energy Services, Inc.

The University of Texas System

Michael Linley Fripp

Stephen Michael Greci

Zachary William Walton

Zachary R Murphree

Jason Daniel Dykstra

John C Gano

Thomas Jules Frosell

Donald Kyle

Luke William Holderman

Richard Decena Ornelaz

Roger Lynn Schultz

Gregory Thomas Werkheiser

Jean-Marc Lopez

James Dan Vick, Jr

Adam Davis Wright

Matthew James Merron

Syed Hamid

Liang Zhao

Neal Gregory Skinner

John Patrick Rodgers

Brandon Thomas Least

Xiaoguang Allan Zhong

Matthew Todd Howell

Mark Christopher Glaser

Ibrahim El Mallawany

Aaron James Bonner

Jean Marc Lopez

Ryan Wesley McChesney

Wei Zhang

John Hudson Hales

Adan Hernandez Herrera

Ronald Glen Dusterhoft

Lonnie Carl Helms

Cyrus A Irani

Bruce H Storm, Jr

Andrew Penno

Brock Wayne Watson

Paul David Ringgenberg

Jimmie Robert Williamson

Daniel David Gleitman

Kenneth L Schwendemann

Paul Gregory James

Walter E Voit

Gregory Scott Cunningham

Scott Cunningham

Donald H Perkins

Christopher Michael Jones

Michael Thomas Pelletier

Larry Steven Eoff

David Joe Steele

Ashok K Santra

Feng Liang

Aaron Michael Beuterbaugh

Batakrishna Mandal

Paul Joseph Jones

Vimal Vinod Shah

Bruce Edward Scott

Frank Vinicio Acosta

James R Longbottom

Nicholas Frederick Budler

Christopher C Hoelscher

Timothy Rather Tips

Sean Gregory Thomas

Juanita M Cassidy

Mark D Kalman

Sudhir Kumar Gupta

Dwight David Fulton

Darrin N Towers

Ricky Layne Covington

Philip D Nguyen

Paul F Rodney

William Mark Richards

Enrique Antonio Reyes

Donn Jason Brown

John Laureto Maida, Jr

Etienne M Samson

Darren George Gascooke

Mathew Dennis Rowe

Xiang Wu

Jack Gammill Clemens

Dipti Singh

James Marshall Barker

Sean Carroll

Eric James Davis

YiJing Fan

Chad Adam Fisher

Andy Cheng Chang

Ian Bradford Mitchell

James C Tucker

Wesley Neil Ludwig

Marthinus Van Schoor

Tommy Frank Grigsby

Richard Ellis Robey

Marco Serra

Timothy S Glenn

Simon David Turton

Daniel Keith Moeller

John P Singh

Determining one or more of a fluid composition, a cement state, or a cement quality of a material located downhole a borehole by using a capacitive sensor or an inductive sensor. The sensors can be located on a pipe positioned downhole or within a swell packer. More than one sensor can be used, for example, as a set of sensor systems. The sensors can be of different sizes, utilize different frequencies, or be spaced unevenly to analyze different shaped areas and depths from the sensors. More than one set of sensors can be employed, such as axially or circumferentially spaced along the pipe or swell packer. The relative dielectric permittivity of the various downhole material can be used to determine when pumped cement has displaced the borehole fluid and when the cement has cured. The process can determine if a micro annulus or crack exists in the cement.

Monitoring fluid/cement type/quality outside of casing of a borehole

A wet mate connection system can be provided for suppling power to a wellbore tool. For example, the wet mate connection system can be positioned downhole in the wellbore. The wet mate connection system can further be electrically coupled with a valve. The wet mate connection system can include a first wet mate connector and a second wet mate connector. The second wet mate connector can be coupled with the first wet mate connector and with the valve. Additionally, the wet mate connection system can include one or more electrical contacts between the first wet mate connector and the second wet mate connector.

Downhole wet mate connection system for wellbore tools

Provided is a slip ring for use with a sealing assembly, a sealing tool, and a method for sealing an annulus within a wellbore. The slip ring, in at least one aspect, includes an expandable metal ring member having a width (w), a wall thickness (t), an inside diameter (d) and an outside diameter (d), the expandable metal ring member comprising a metal configured to expand in response to hydrolysis. The slip ring, in at least one aspect, further includes one or more cuts located in the wall thickness (t) and spaced around a circumference of the expandable metal ring member, the one or more cuts configured to allow the expandable metal ring member to move between a radially reduced state and a radially enlarged state.

Expandable metal slip ring for use with a sealing assembly

Provided is a float for use with a fluid flow control device, a fluid flow control device, a method for manufacturing a float, and a well system. The float, in one aspect, includes a fluid tight enclosure. The float, according to this aspect, further includes density specific material located within the fluid tight enclosure, the fluid tight enclosure and the density specific material creating a net density for the float that is between a first density of a desired fluid and a second density of an undesired fluid, such that the float may control fluid flow through a flow control device when encountering the desired fluid or the undesired fluid.

Fluid tight float for use in a downhole environment

A hydraulic ratcheting device that includes an activation chamber, a valve chamber disposed adjacent to the activation chamber, and an activation piston that includes a first piston area exposed to a fluid source, and a second piston area exposed to the valve chamber, where the activation piston is configured to translate forward, in response to a pressure increase on the first piston area, and push a liquid from the valve chamber into the activation chamber using the second piston area.

Intervention-less method of setting open hole packers

A subsurface safety valve for a wellbore for production of fluids from a subsurface formation comprises a drive portion and an actuator portion. The drive portion comprises a first magnet assembly and the actuator portion comprises a second magnet assembly that is magnetically coupled to the first magnet assembly. At least one of the first magnet assembly or the second magnet assembly comprises a spatially rotated array of magnets arranged such that a magnetic field emitted from an operative side of the spatially rotated array of magnets facing a magnetic coupling is non-zero and such that the magnetic field emitted from a non-operative side of the spatially rotated array of magnets that is opposite the operative side is about zero.

Wellbore subsurface safety valve using a magnetic coupling

Systems and methods of the present disclosure relate to storing carbon dioxide (CO) underground. A method includes contacting a metal tool with the COand forming hydrated metal carbonates (HMCs) on the tool due to contact of the COwith the metal of the tool. Expansion of the tool occurs due to formation of the HMCs.

Hydrated metal carbonate for carbon capture and underground storage

Provided is a fluid flow control system, a well system, and a method. The fluid flow control system, in one aspect, includes a flow restrictor operable to receive production fluid having a pressure (P3) and discharge control fluid having a control pressure (P2), and a fluidic diode placed between the flow restrictor and the tubing, the fluidic diode configured to increase the control pressure (P2) to a higher control pressure (P2) when the fluidic diode encounters lower viscosity fluids and is configured to increase the control pressure (P2) to a lower control pressure (P2) when the fluidic diode encounters higher viscosity fluids. The fluid flow control system, in one aspect, further includes an inflow control device having a production fluid inlet, a control inlet operable to receive control fluid having the higher control pressure (P2) or the lower control pressure (P2), and a production fluid outlet.

Fluid flow control system employing a fluidic diode for control pressure

A ratcheting setting tool can use wellbore fluid to inflate expandable seals positioned downhole in a wellbore. For example, the ratcheting setting tool can include a piston within a first chamber. The piston can move from a first position to a second position in the first chamber when a pressure is applied to the piston. The ratcheting setting tool can include a first check valve in a second chamber. The first check valve can transmit wellbore fluid from the wellbore into the second chamber. The ratcheting setting tool can include a second check valve. The second check valve can transmit the wellbore fluid in the second chamber into an inflatable valve when the piston moves from the first position to the second position. In some examples, the ratcheting setting tool may be a hydraulic ratchet.

Ratcheting setting tool for an expandable seal in a wellbore

Systems and methods for wireless downhole telemetry are provided. The system includes a tubular located in a wellbore; a pressure controller located at or near a surface of the wellbore to send a digital command via a change in a pressure applied to the tubular; and a receiver disposed in the wellbore, wherein the receiver includes a mechanical pressure switch to detect the change in the pressure applied to the tubular.

Wireless telemetry using a pressure switch and mechanical thresholding of the signal

Disclosed herein are an apparatus, system, and method directed for an autonomous wellbore cleaner. In one embodiment, an apparatus for cleaning a wellbore, the apparatus comprising: an autonomous robot, wherein the robot is self-propelled; a power source for the robot; a motor for propelling the robot axially within the wellbore; at least one cleaning tool positioned on the robot; at least one sensor to detect an initiate-cleaning attribute downhole in the wellbore; and a processor to direct the robot to initiate a cleaning operation in response to the initiate-cleaning attribute exceeding a threshold.

Autonomous wellbore cleaning system

Mobile downhole tools with fairings and methods of using the same. A mobile downhole tool is introduced into a wellbore. The mobile downhole tool has a housing with a thickness sufficient to support a pressure differential between an interior surface of the housing and an exterior surface of the housing when the mobile downhole tool is disposed in the wellbore, and a fairing coupled to the exterior surface of the housing. The fairing is structurally distinct from the housing and is not connected to the interior surface of the housing. The fairing curves in a first direction that is away from the housing. The mobile downhole tool is propelled in the wellbore as the wellbore is produced such that the mobile downhole tool descends downhole against the upstream flow of a wellbore fluid.

Fairings for mobile downhole tools in producing wells

Provided is a subsurface safety valve. The subsurface safety valve, in one aspect, includes a tubular housing having a longitudinal opening, and one or more openings extending into the tubular housing. The subsurface safety valve, in one aspect, further includes a longitudinal valve positioned within the longitudinal opening. In accordance with one aspect, the longitudinal valve includes a first piston having a first piston surface area (SA) and a second piston having a second piston surface area (SA), the first piston surface area (SA) and the second piston surface area (SA) being substantially identical, as well as a fluid flow path extending within and along the longitudinal valve, the fluid flow path entering the longitudinal valve between a first longitudinal valve end and the first piston and exiting the longitudinal valve between a second longitudinal valve end and the second piston.

Tubing pressure insensitive subsurface safety valve

A curved flow tube can be positioned in a tubing string deployed downhole in a wellbore to slow a closure of a flow valve in the tubing string. The tubing string can be deployed in the wellbore to transport wellbore fluid. The flow valve can be coupled to the tubing string. Additionally, the flow valve can include a flapper and the flow tube. The flapper can be positioned to control the wellbore fluid transported through the tubing string. The flapper may be adjusted between an open position and a closed position. The flow tube can include a downhole end that has a curvature to slow a closure rate corresponding to adjusting the flapper from the open position to the closed position.

Curved flow tube to slow a closure of a flow valve

Method of manufacturing a wellbore downhole tool, including providing a pre-polymer resin and processing the pre-polymer resin. Processing the pre-polymer resin includes applying directed energy from a directed energy source such that the pre-polymer resin is at least partially polymerized to form a polymer seal of the wellbore downhole tool, the polymer seal having one of more mechanical properties that differ along one or more dimensions of the polymer seal.

Manufacture of a polymer seal for a wellbore downhole tool with dimensional mechanical property grading

Growing community of inventors

Singapore, Singapore

Michael Linley Fripp