Halliburton Energy Services, Inc.

Mississippi State University

General Electric Company

Baker Hughes, a Ge Compnay, LLC

Baker Hughes Oilfield Operations LLC

Ge Oil Gas Pressure Control LP

Ahlliburton Energy Services, Inc.

Vimal Vinod Shah

Wallace R Gardner

Donald Kyle

Paul F Rodney

James Robert Birchak

Eugene J Linyaev

Jeffrey Lee Moore

Wei Han

Mark Windsor Roberson

Bruce H Storm, Jr

Scott Goodwin

John W Minear

Rajnikant M Amin

Batakrishna Mandal

Carl A Robbins

Fouad Fleyfel

Bayram Kalpakci

Michael Linley Fripp

Neal Gregory Skinner

Krishna M Ravi

Mark Anton Proett

Thomas Jules Frosell

Zachary R Murphree

Randal Thomas Beste

Jesse Kevin Hensarling

Don Herrick Johnson

Jagdish P Singh

Frederic Nicolas Felten

Sergei Sharonov

Robert L Malloy

Malcolm Douglas McGregor

R Daniel Costley

Kenny L McConnell

Krishnan Balasubramaniam

Burkay Donderici

Craig Wayne Roddy

Li Gao

Otto N Fanini

Glenn Andrew Wilson

Stanislav W Forgang

Clark E Robison

Lembit Salasoo

Douglas J Patterson

Mohamed Yousef Soliman

Leonard R Case

Adam Davis Wright

James H Dudley

Thomas E Ritter

Abbas Arian

Marc Stephen Ramirez

Harold Wayne Nivens

Roderick Mark Lusted

John R Dennis

Stewart Blake Brazil

Babak Kouchmeshky

Ali Mese

Joakim Oscar Blanch

Fredrick D Curtis

Gary Lee Fickert

Xiaochu Yao

Jinfeng Zhang

Christopher Winstead

Rebecca A McConnell

Victor Jose Acacio

David J Young

Pawel J Matuszyk

Walter Chapman

Wilson Chun-Ling Chin

Sinan Sinanovic

M Douglas McGregor

George S Reagan

Eric H Van Empelen

Hampton Fowler, Jr

Lily Jiang

Paul Spriggs

Jewell Cope

Crispin L Richards

Curtis M Vickery

Malcolm Douglas Mcgregor

M Douglas Mcgregor

Eugene R Linyaev

Sergei A Sharonov

Donald G Kyle

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

Embodiments of the present disclosure include a method including receiving first impact data. The method includes receiving second impact data. The method includes applying a first filter to both the first impact data and the second impact data. The method includes applying a second filter to both the first impact data and the second impact data. Filtering includes time and frequency based discriminating filter to isolate specific signatures that representatively indicate impact signatures generated by the sand on the interrogator. The method includes comparing the first impact data and the second impact data for corresponding signatures. The method includes identifying a corresponding signature in both the first impact data and the second impact data. The method includes determining the corresponding signature meets a threshold criterion. The method includes determining one or more particulate properties based at least in part on the corresponding peak.

System and method for assessing sand flow rate

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

A production well includes a casing and encapsulated tubing positioned within the casing. The encapsulated tubing includes a conductive sidewall defining a channel for an injection fluid. The production well further includes an insulative layer surrounding the conductive sidewall. The production well also includes a controller configured to regulate flow of an electrical current through the conductive sidewall. The production well further includes production tubing positioned within the casing and configured to channel a production fluid through the casing. The insulative layer is configured to inhibit transmission of the electrical current between the conductive sidewall and the production tubing. The production well also includes at least one sensor positioned within the casing to detect downhole conditions of the production well. The conductive sidewall is configured to conduct electrical current toward the at least one sensor.

Methods and systems for downhole sensing and communications in wells

Systems, devices, and methods for estimating a value of a downhole parameter of interest. Aspects include an apparatus for evaluating a tubular. The apparatus may include a sensor including an electromagnetic acoustic transducer (EMAT) device configured to be conveyed into the tubular. The EMAT device may include measurement circuitry comprising at least one conductive coil; and a magnet array comprising magnets arranged with a corresponding direction of magnetization of each magnet oriented according to a configuration producing a greater magnetic flux on a first side of the array than on a second side opposing the first side. The magnetic flux produced from the second side may be substantially zero. In embodiments, the configuration of magnets comprises at least a first set of permanent magnets in a linear Halbach configuration.

Downhole electromagnetic acoustic transducer sensors

An example method includes providing fluid communication between an internal bore of a drill string and an annulus between the drill string and a borehole through a fluid channel in a side of a collar coupled to the drill string. Fluid may be circulated through the internal bore of the drill string. A fluid telemetry signal may be generated by selectively generating a vortex within the fluid channel. Providing fluid communication between the internal bore and the annulus through the fluid channel may include providing fluid communication between the internal bore and a vortex basin at least partially defining the fluid channel, through at least one of a first fluid flow path and a second fluid flow path between the vortex basin and the internal bore; and providing fluid communication between the vortex basin and the annulus through a fluid outlet of the vortex basin.

Fluidic pulser for downhole telemetry

A sensing and communication system for a gas lift well is provided. The gas lift well includes a casing, production tubing positioned within the casing, and a gas lift valve coupled to the production tubing. The sensing and communication system includes a turbine configured to rotate in response to an injected gas stream flowing through the turbine, wherein the turbine is positioned one of i) within an annulus defined between the production tubing and the casing and ii) within the gas lift valve, an alternator coupled to the turbine and configured to generate electrical power from rotation of the turbine, and at least one sensor coupled to the alternator and configured to operate using the generated electrical power.

Methods and systems for downhole sensing and communications in gas lift wells

An apparatus and method may operate to mount one or more communication assemblies relative to the exterior of a casing being placed in a borehole. Two communication assemblies can be placed in longitudinally spaced relation to one another along the casing, wherein each communication assembly is configured to obtain excitation responses from electrodes of a fluid sensing component, where the excitation responses vary based on properties of fluids in one or more regions of the annulus surrounding the casing. Additional apparatus, systems, and methods are disclosed.

Methods and apparatus for evaluating downhole conditions through fluid sensing

The resonant frequency of an example transducer can be adjusted by changing the effective mass of a backing mass using a tuning module. The tuning module includes a electrical source, a switch, and an electromagnetic coil connected in series as an electrical circuit. The electromagnetic coil is mechanically attached to the backing mass, and is disposed within a reservoir of a magneto-rheological fluid enclosed within a casing. When the switch is closed, the electrical source applies a voltage and current to the electromagnetic coil, and induces a localized magnetic field within the magneto-rheological fluid. In response to this localized magnetic field, the magneto-rheological fluid increases in viscosity, assumes properties comparable to a viscoelastic solid, and become affixed to the electromagnetic coil. As the electromagnetic coil is mechanically attached to the backing mass, the solidified magneto-rheological fluid increases the effective mass of the backing mass. As a result, the resonant frequency of the transducer is altered.

Tunable acoustic transmitter for downhole use

An embodiment includes an apparatus for wireless communications in a drilling operations environment. In an embodiment, the apparatus includes an instrument hub that is inline with drill pipe of a drill string. The instrument hub includes a sensor to receive downhole communications from downhole. The instrument hub also includes a transmitter to wireless transmit data representative of the downhole communications to a data processor unit.

Wireless communications in a drilling operations environment

One embodiment includes a method comprising receiving an acoustic signal that is propagated along a drill string. The method also includes correlating the acoustic signal to a first stored acoustic signal representing a first symbol, wherein the first stored acoustic signal is acquired from a propagation along the drill string in an approximately noise free environment.

Receiver for an acoustic telemetry system

An embodiment includes a method comprising transmitting and receiving an acoustic signal that is modulated along a jointed tubing. The acoustic signal may be transmitted in multiple passbands of the jointed tubing and may be modulated differently in different passbands. A swept frequency signal may be used to determine transmission characteristics of the jointed tubing and to select the multiple passbands. Additional embodiments are disclosed.

Acoustic telemetry system using passband equalization

An apparatus for wireless communications in a drilling operations environment can include an instrument hub that is inline with drill pipe of a drill string. The instrument hub includes a sensor to receive downhole communications from downhole. The instrument hub also includes a transmitter to wireless transmit data representative of the downhole communications to a data processor unit.

Growing community of inventors

Sugar Land, TX, United States of America

Vimal Vinod Shah