Halliburton Energy Services, Inc.

Thomas Jules Frosell

Michael Linley Fripp

William Mark Richards

Zachary R Murphree

Stephen Michael Greci

Richard Decena Ornelaz

Gary John Geoffroy

Zachary Ryan Murphree

John C Gano

Zahed Kabir

Colby M Ross

Syed Hamid

Aswin Balasubramanian

Clint Adam Brown

Tyson Harvey Eiman

Gregory William Garrison

Suzi Marie Marcuccio

Luke William Holderman

Vimal Vinod Shah

Brandon Thomas Least

Xiaoguang Allan Zhong

Emile Edmund Sevadjian

Caleb Thomas Warren

Frederic Nicolas Felten

Gireesh K Bhat

Maxime P M Coffin

Mark Douglas Macek

Ralph H Echols

Donald Kyle

Larry Steven Eoff

Zachary William Walton

Liang Zhao

Matthew James Merron

Ryan Wesley McChesney

Andrew Penno

Thomas Owen Roane

Ryan Michael Novelen

Peter D W Inglis

Maxime Philippe Coffin

Geir Gjelstad

Jason Earl Davis

James Flygare

Jacob Zachariah

Keith Wayne Scott

Colin E Kappe

Man Yee Leong

Maxime Pm Coffin

Karla Sechere

Phil Terry Thomas

Ryan Wesley Mcchesney

Stephen Michael Grecci

A variable flow resistance system for use with a subterranean well includes a first flow path configured to receive a fluid, a sensor configured to measure a property of the fluid received into the first flow path, and an actuator configured to control an inflow rate of the fluid received into the first flow path based upon the property of the fluid measured by the sensor.

Variable flow resistance system for use with a subterranean well

A valve useful in an inflow control device for downhole use in an oil and gas well completion equipment is disclosed. The valve may have a flexible canopy that prevents fluid flow between the base pipe and the formation when flow travels in a first direction and permits fluid flow between the base pipe and the formation when flow travels in a second direction.

Valve apparatus for inflow control devices

A float equipment assembly includes an inner string that provides a fluid flow path through the float equipment assembly. The float equipment assembly also includes an opening through which a fluid flowing through the inner string exits the float equipment assembly. The float equipment assembly further includes a moveable member, which when repositioned, isolates the inner string. The float equipment assembly further includes a dissolvable material that initially prevents repositioning of the moveable member, where the moveable member is repositioned after a threshold portion of the dissolvable material has dissolved.

Float equipment assemblies and methods to isolate downhole strings

A first completion system with electrical isolation, electronics, and a first side of a coupler is installed in a borehole drilled in a geological formation. A second completion system is installed in the borehole after installation of the first completion system. The second completion system has a second side of the coupler aligned with the first side of the coupler and an umbilical which carries power from a surface of the geological formation to the second side of the coupler. Power is sent from the second side of the coupler to the first side of the coupler, from the first side of the coupler to a first side of the electrical isolation, and from the first side of the electrical isolation to a second side of the electrical isolation via an isolation barrier. The power at the second side of the electrical isolation is provided to the electronics.

Electrical isolation in transferring power and data signals between completion systems in a downhole environment

A tubular string formed by one or more tubulars with a central flow passage for an internal fluid therethrough and an external surface. The tubular having a wall thickness defined between external surface and the central flow passage and at least one sensor port disposed along a longitudinal length of the tubular. At least one sensor includes a main body and=nipple extending from the main body and inserted into the sensor port of the tubular. The nipple extends through the wall thickness sufficient to detect a property of an internal fluid within the central flow passage.

Sensor nipple and port for downhole production tubing

Example systems and methods are described that operate to open screen joints using mechanically-generated perforations for beginning fluid production. In an example system, a screen joint is deployed in a production tubing within a wellbore. The screen joint includes a screen element and a blank housing that are coupled to an exterior surface of a non]perforated base pipe. Further, the screen joint includes a locator profile positioned along an interior surface of the non]perforated base pipe. A perforator is deployed within the screen joint that includes a mechanical perforator and a locator for engaging with the locator profile to position the mechanical perforator under the blank housing.

Systems and methods for opening screen joints

A spoolable array of sensors may be deployed within a wellbore and external a tubular string for measuring properties of a fluid in the central flow passage of the tubular string. A flow port may be made in the tubular string passing from the central flow passage to the external surface. Sensors of the spoolable array of sensors may be covered with a shroud and placed proximate the flow port, or such sensors may be isolated in a zone with packers along with the flow port. The spoolable array of sensors may additionally obtain pressure data to calculate a flow rate from a production zone. The spoolable array of sensors may also be employed in a non-flowing wellbore for monitoring nearby wellbores.

Determining downhole properties with sensor array

The disclosure is directed to a well system environment communication system comprising of an acoustic communicator capable of communicating encoded data with a first wireless transceiver through a fluid medium and the first wireless transceiver capable of communicating encoded data with a second transceiver through a non-fluid medium. In one example, an acoustic communicator is communicatively coupled with a downhole tool allowing the downhole tool to communicate indirectly with a well system controller. In another aspect of the disclosure, a method is described wherein an acoustic communicator located in a wellbore can encode data from a downhole tool and communicate the data through a fluid medium to a first wireless transceiver and the first wireless transceiver can communicate with a second transceiver through a non-fluid medium.

Acoustics through fluid communication system

A completion assembly to aid in fluid control in a multi-lateral wellbore includes a plurality of sand screen assemblies, each sand screen assembly having a wireless adjustable electronic flow control node disposed along a sand screen base pipe to control fluid flow between the sand screen assembly and the wellbore annulus. 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, opening or closing the valve to control flow in the lateral wellbore. A wired controller in the main wellbore is disposed for transmitting wireless signals across a junction assembly in the wellbore to the sand screen assembly electronic flow control nodes.

Intelligent completion of a multilateral wellbore with a wired smart well in the main bore and with a wireless electronic flow control node in a lateral wellbore

A method includes directing a wellbore fluid into a flow control assembly coupled to a completion string positioned within a wellbore, the flow control assembly including at least a first fluidic device defining a flow passage, where the flow passage is formed of a material having a known wettability selected to correspond to a component of the wellbore fluid. The pressure change along the flow passage is measured and utilized to determine fluid cut based on a predetermined correspondence between pressure change and component cut for the first fluidic device. Multiple fluidic devices, each selected to have a wettability responsive to a different component of the wellbore fluid, may be aligned in parallel or series to determine the cut of multiple components in the fluid.

Using fluidic devices to estimate cut of wellbore fluids

An actuation system for remotely transitioning a downhole wellbore tool between distinct operational configurations includes a sensor that can detect a downhole pressure in a tubular string extending into a wellbore and an electronic decoder that monitors the pressure the tubular string until a target pressure profile is detected. When the target pressure profile is detected, the decoder issues a command to an actuation mechanism, causing the downhole wellbore tool to transition between the distinct operational configurations. The target pressure profile may be transmitted from the surface location by operating a pump to produce specific downhole pressure levels for specific time intervals. The specific downhole pressures do not need to be applied directly to the downhole wellbore tool, and thus the each of a plurality of various downhole wellbore tools may be operated independently without interfering with one another.

Remote-open barrier valve

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 lower completion assembly made up of an upper sand screen assembly and a lower sand screen assembly. Each sand screen assembly includes a shunt system. Each shunt system includes a transport tube and a packing tube extending from a junction block. Each packing tube includes a plurality of nozzles spaced apart from the junction block and from each other. The shunt system of the upper sand screen assembly has a higher pressure rating than the shunt system of the lower sand screen assembly. The wall thickness of the transport tubes of the upper sand screen assembly shunt system is greater than the wall thickness of the transport tubes of the lower sand screen assembly shunt system.

Multiple shunt pressure assembly for gravel packing

A well screen system includes upstream and downstream screen assemblies arranged along an axis. The assemblies each have first and second transport tubes. A first packing tube is connected to the first transport tube by first adapter and has an uppermost nozzle axially spaced from the first adapter by a first effective packing tube length. A second packing tube is connected to the second transport tube by a second adapter and has an uppermost nozzle axially spaced from the second adapter by a second effective packing tube length different than the first effective packing tube length. The downstream screen assembly second transport tube is connected to the upstream screen assembly first transport tube to alternate the effective packing tube lengths of packing tube uppermost nozzles along the screen system. Methods of making well screen systems and methods of gravel packing well screen systems are also disclosed.

Systems and methods for gravel packing wells

A completion system and a method for powering a downhole component of a wellbore are provided. In one example, in the completion system comprises at least three different types of power sources for powering a downhole component in a wellbore and a power distribution circuit including a power distribution node and a control circuit, wherein the control circuit is configured to select at least one power source of the at least three different types of power sources to connect to the power distribution node based on a selection priority of the power sources, and the power distribution node is configured to provide power from the at least one power source to the downhole component.

Redundant power source for increased reliability in a permanent completion

Growing community of inventors

Dallas, TX, United States of America

Thomas Jules Frosell