Halliburton Energy Services, Inc.

Research Triangle Institute

Micross Advanced Interconnect Technology LLC

Indiana Integrated Circuits, LLC

Santa Barbara Infrared, Inc

Afa Controls LLC

Scott Goodwin

Mark Windsor Roberson

Krishna M Ravi

Craig Wayne Roddy

Paul F Rodney

Charles Bartee

Vimal Vinod Shah

David Dausch

Batakrishna Mandal

Burkay Donderici

Glenn Andrew Wilson

Dorota Temple

John Lewis

Neal Gregory Skinner

Li Gao

Ahmed Elsayed Fouda

Henry Eugene Rogers

Nicholas Frederick Budler

Jason M Kulick

William O Teach

Kevin Henry

Kevin R Douglas

Joseph Donald LaVeigne

Paul W Gibson

Donald C Harris

Alexander Stewart

Wayne D Dettloff

Christopher Brewer Sanders

Jim Carlson

John Lañnon

Ginger Rothrock

Kristopher McGuire

Kristopher Mcguire

Joseph Donald Laveigne

A method that includes deploying a casing with a multi-electrode configuration over a dielectric layer in a downhole environment. The method also includes collecting electromagnetic (EM) measurements using the multi-electrode configuration, and processing the EM measurements to obtain a characterization of fluids in an annulus between the casing and a borehole wall. A related system includes a casing deployed downhole, the casing having a multi-electrode configuration and a dielectric layer between the casing and the multi-electrode configuration. The system also includes a controller for directing collection of EM measurements using the multi-electrode configuration, and a processor that processes the EM measurements to obtain a characterization of fluids in an annulus between the casing and a borehole wall.

Downhole fluid characterization methods and systems employing a casing with a multi-electrode configuration

An assembly for use in a wellbore can include a plurality of sensors positioned external to a casing string. The plurality of sensors can be positioned for detecting an amount of a hydrocarbon that is present in a fluid in the wellbore and a pH of the fluid in the wellbore. The plurality of sensors can be positioned for wirelessly transmitting signals representing the amount of the hydrocarbon that is present in the fluid and the pH of the fluid to a receiving device.

Determining characteristics of a fluid in a wellbore

Systems and methods for detecting or monitoring treatment fluids in subterranean formations are provided. In certain embodiments, the methods comprise: providing an enhanced treatment fluid that comprises at least a base fluid and one or more contrast enhancement agents selected from the group consisting of: a magnetic material; a dispersive material; and any combination thereof, wherein the enhanced cementing fluid comprises one or more micro-electro-mechanical system (MEMS) sensors; and introducing the enhanced treatment fluid into at least a portion of a well bore penetrating a portion of a subterranean formation.

Contrast enhancement agents for subterranean treatment fluids

A sensor, method, and system for sensing corrosion. The sensor may be used to monitor the integrity of structural elements. The sensor, method, and system utilizing an inductive element formed on the substrate and having a first inductive loop and a second inductive loop. The sensor also includes a sensing element electrically connecting one end of the first inductive loop to an opposing end of the second inductive loop. Prior to dissolution of the sensing element, an inductance of the inductive element comprises a first inductance set by the first predetermined number of turns of the inductor coil having a first resonant frequency. After dissolution of the sensing element, the inductance of the inductive element comprises a second inductance reduced from the first inductance.

Corrosion sensor and method and computerized system for using the same

Methods and systems are presented in this disclosure for determining information (e.g., visual information) about locations of different fluids flowing along a casing in a wellbore. A plurality of radio frequency (RF) micro-electro-mechanical system (MEMS) tags is placed in a plurality of fluids flowing through an annulus region between a casing string in the wellbore and a reservoir formation. At a plurality of sensing nodes located along the casing string, information about the fluids is gathered by communicating with the RF MEMS tags placed in the fluids. The information about fluid locations along the casing gathered by the sensing nodes is communicated to a receiving device, and appropriate operation in relation to the wellbore is performed based on the communicated information.

Zonal representation for flow visualization

A communication unit is situated in or on a casing collar. The casing collar has two threaded ends for joining casing joints to construct a well casing, and a communication unit is disposed in or on a central region of the tube between the two threaded ends. In an example, the communication unit has a transmitter for transmitting sensor data uphole from a sensor sensing a well bore condition. For example, the communication unit has a receiver for receiving sensor data from Micro-Electro-Mechanical Systems (MEMS) sensors, a transceiver for interrogating RFID tags, an acoustic transceiver for sensing wellbore conditions, a pressure sensor, a temperature sensor, and batteries for powering the communication unit.

Casing coupling having communication unit for evaluating downhole conditions

Downhole fluid characterization methods employing a casing with a multi-electrode configuration

A corrosion sensor system includes one or more corrosion sensors embedded in a coating material such as an anti-corrosion coating material. Each corrosion sensor may include a resonator disposed on a dielectric substrate, and has a resonant frequency in a radio frequency (RF) range or an infrared (IR) range, and is configured for interacting with an RF or IR excitation signal to produce an RF or IR measurement signal. The corrosion sensor system may be applied to an object for which corrosion is to be monitored. A corrosion detection system includes a data acquisition system that transmits the excitation signal to the corrosion sensor, and receives the measurement signal from the corrosion sensor for analysis to determine whether corrosion has occurred.

Detection of corrosion using dispersed embedded sensors

A centralizer for downhole OCTG having a storage space capable of housing downhole electronics and other downhole devices, compositions and elements is disclosed. The storage space is located within an inner cavity formed in one or more of the blades making up the centralizer. A capsule is provided for protecting the contents of the items being stored within the inner cavity. The capsule may be hermetically sealed to protect the contents from the damaging effects of downhole fluids. Ports may be provided within the capsule to allow downhole electronics to be connected to sensors and other devices and components residing outside of the capsule.

Centralizer electronics housing

Disclosed are telemetry systems and methods that employ a plurality of electromagnetic transceivers disposed outside a well casing string at a corresponding plurality of depths along the casing string. Each transceiver includes one or more toroidal inductors circumferentially surrounding the casing string and inductively coupled thereto to allow signal transmission between transceivers via currents induced in the casing. In some embodiments, signals are relayed via a chain of transceivers to facilitate indirect communication between a surface facility and other transceivers located too deep for direct communication to the surface.

Electromagnetic telemetry for sensor systems deployed in a borehole environment

A well casing is cemented in a well bore in a subterranean formation by pumping cement slurry down into the well casing so that the cement slurry flows up into an annulus surrounding the well casing. While pumping the cement slurry, the position of the top of the cement slurry in the annulus is sensed, and the rise of the sensed position of the top of the cement slurry in the annulus is recorded as a function of time. The recording is analyzed to evaluate the cement job. For example, the analysis may indicate a problem addressed by adjusting a cement plan for a future cement job, and the analysis may indicate a need to repair a location of the set cement by perforating the well casing at the location to be repaired, and pumping cement slurry down the well casing to fill the location to be repaired.

Dynamic sensing of the top of cement (TOC) during cementing of a well casing in a well bore

A communication system that is positionable in a wellbore can include a first transceiver positioned externally to a casing string. The first transceiver can be operable to detect a presence or an absence of a surface wave; determine a location of a fluid in the wellbore based on the presence or the absence of the surface wave; and transmit data indicative of the location to a second transceiver. The surface wave can include an electromagnetic wave that has a magnetic field or an electric field that is non-transverse to a direction of propagation of the surface wave. The communication system can also include the second transceiver, which can be positioned externally the casing string and operable to receive the data.

Downhole fluid detection using surface waves

In one embodiment, a system includes a casing disposed within a wellbore, one or more data collection tools coupled to the casing, and one or more sensors disposed within an annulus of the wellbore. Each of the one or more sensors include a substrate, a strain-sensitive element coupled to the substrate, and a transceiver coupled to the substrate and configured to communicate with the one or more data collection tools.

Downhole cement strain gauge

Systems and methods for detecting or monitoring treatment fluids in subterranean formations are provided. In certain embodiments, the methods comprise: providing an enhanced treatment fluid that comprises at least a base fluid and one or more contrast enhancement agents, which may include dielectric materials, magnetic materials, dispersive materials, and/or any combination thereof; and introducing the enhanced treatment fluid into at least a portion of a well bore penetrating a portion of a subterranean formation in the course of certain operations in the well bore.

Growing community of inventors

Chapel Hill, NC, United States of America

Scott Goodwin