Halliburton Energy Services, Inc.

Cgg Services Sas

Halliburton Services

Xiang Wu

Yao Ge

Jing Jin

Ruijia Wang

Mark Elliott Willis

Andreas Ellmauthaler

Christopher Michael Jones

Yadong Wang

Ho Yin Ma

Chung Lung Chang

Brenno Caetano Troca Cabella

Glenn Andrew Wilson

Xusong Wang

Michel Joseph LeBlanc

Wei Li

David Andrew Barfoot

Dinesh Ananda Shetty

Richard Timothy Coates

Junwen Dai

Peng Li

Amit Padhi

Srividhya Sridhar

Rodney Allen Marlow

Yu Weng

Pablo Vieira Rego

Marco Aurelio Luzio

Jichun Sun

Michael Linley Fripp

Ahmed Elsayed Fouda

Bin Dai

Wei Zhang

James Martin Price

YiJing Fan

Simon Shaw

Imran Sharif Vehra

Henry Clifford Bland

Wei-Bin Ewe

Yi Yang Ang

Philip William Tracadas

Qingtao Sun

Zhonghuan Chen

Oscar Augusto Barrios

Mark Elliot Willis

João Vicente Gonçalves Rocha

Luke William Holderman

Federico Combis Lucas

Ning Tu

Victor King Hong Leung

Michel Joseph Leblanc

In some embodiments, a downhole logging tool configured for placement in a wellbore comprises a first magnet configured to activate a first volume of ferromagnetic fluid disposed between the downhole logging tool and the wellbore to achieve a first seal between a primary analysis region of the downhole logging tool and a wellbore fluid.

Wellbore exclusion fluid method and apparatus for downhole logging

A method for identifying guided waves in a measurement set. The method may comprise disposing an acoustic logging tool into a wellbore, performing a measurement operation with the acoustic logging too in the wellbore to form a data set which comprises one or more guided waves, measuring a speed of the one or more guided waves, and identifying a fluid phase interface using the speed of the one or more guided waves. The method may further comprise estimating an acoustic velocity of a wellbore fluid using a database and interpreting the fluid phase based at least in part on the acoustic velocity of the wellbore fluid.

Fluid phase discrimination and acoustic velocity estimation by measuring guided-wave speed

A method for acoustic noise source detection. The method may comprise disposing an acoustic logging tool into a wellbore, performing an acoustic logging operations in the wellbore with the acoustic logging tool, forming a data set form the acoustic logging operation, and performing a cross-correlation function between pairs of hydrophones using the data set. The method may further comprise construction a cost function using at least in part the cross-correlation function to find a noise source distribution and identifying a location of the acoustic noise source by inverting the noise source distribution.

Acoustic noise source localization based on cross-correlation functions across a hydrophone array

Described herein are systems and techniques for monitoring for monitoring and evaluating conditions associated with a wellbore and wellbore operations that use neural operators instead of computationally intensive iterative differential equations. Such systems and techniques allow for determinations to be made as operations associated with a wellbore are performed. Instead of having to wait for computationally intensive tasks to be performed or take risks of proceeding with a wellbore operation without real-time evaluations being performed, these wellbore operations may be continued while determinations are timely made, thus improving operation of computing systems that perform evaluations and that make decisions regarding safely and efficiently performing wellbore operations such as drilling a wellbore, cementing wellbore casings in place, or injecting fluids into formations of the Earth.

Three-dimensional inversion of multi-component electromagnetic measurements using a fast proxy model

The present disclosure relates to determining a location of a noise source where the location includes azimuth information and determining cement-bond integrity. A downhole tool disposed in a borehole may comprise one or more receivers (such as a monopole receiver and any one or more of one or more multi-pole receivers) and in certain embodiments one or more transmitters that fire one or more shots may provide azimuthal estimate of the location of a noise source, a location of a leak in one or more layers of a casing, cement-bond integrity any combination thereof based, at least in part, on one or more measurements or data for received signals at any one or more receivers. Accurate and efficient identification of a leak or integrity of a cement-bond reduces overall inefficiencies and costs associated with a downhole operation.

Azimuthal scanning of a wellbore for determination of a cement-bond condition and for detecting/locating a leak source

Aspects of the subject technology relate to systems and methods for configuring links or switches that connect analog circuit elements. These analog circuit elements may be connected to a plurality of sensors that may sense different types of data. For example, these sensors may sense acoustic data, electromagnetic (EM) data, temperature, pressure, and possibly other metrics that may be located in a wellbore of an oil or gas well. These analog circuits may be configured as needed (e.g., on-the-fly) to perform optimized types of computations that may include the solving of differential equations. Examples of analog circuits that may be incorporated into a sensing system include yet are not limited to operational amplifier circuits or memcomputing devices, other components, or combinations thereof. Configured analog circuits may be coupled to digital electronics that perform other functions.

Digitally reconfigurable analog computations for solving optimization problems

A system for leak detection. The system may comprise an acoustic logging tool that includes a hydrophone array with a plurality of hydrophones. The system may further include an information handling system communicatively connected to the acoustic logging tool and wherein the information handling system chooses three or more hydrophones from the plurality of hydrophones to operate during measurement operations.

Hydrophone gain design for array noise tool

A method comprising: conveying a downhole tool in a tubing that is positioned in a casing that is positioned to form an annulus between the casing and a wall of a wellbore formed in a subsurface formation, wherein a cement with unknown bonding condition exists in the annulus, wherein the downhole tool includes at least one transmitter and a receiver array physically positioned in different azimuthal directions; emitting, from the at least one transmitter, a first and second acoustic transmissions in a first and second azimuthal directions; detecting, by the receiver array, a first acoustic response and a second acoustic response that is derived from the first and second acoustic transmissions, wherein the second azimuthal direction is orthogonal to the first azimuthal direction; determining a dipole wellbore resonance based on the first and acoustic responses; and evaluating a property of the cement based on the dipole wellbore resonance.

Multi-pole resonance based through tubing cement evaluation

A method comprises conveying a downhole tool in a production tubing within a casing that is around a wall of a wellbore formed in a subsurface formation, wherein cement is placed in an annulus defined between the casing and the wall of the wellbore. The downhole tool includes at least one unipole receiver and at least one of a unipole and a monopole transmitter. The transmitter and receiver are mounted on a rotatable portion of the downhole tool. The method includes performing the following operations at at least two azimuthal positions, emitting an acoustic transmission outward toward the cement and detecting an acoustic response that is in response to the acoustic transmission propagating through the production tubing and the casing and into the cement. The acoustic response includes casing extensional waves, casing non-extensional waves, and tubing waves. The method includes evaluating the cement based on the casing extensional waves.

Through tubing cement evaluation based on casing extensional waves

Apparatus and methods for measuring the oil to water ratio of a wellbore fluid. An example method includes flowing the wellbore fluid into a flow path of a fluid identification device disposed on the outside of a wellbore tubing and within a wellbore annulus. The fluid identification device comprises a shroud, the flow path disposed within the shroud that opens to the wellbore annulus and fluidically links the wellbore annulus to the wellbore tubing thereby allowing fluid flow through the flow path from the wellbore annulus to the wellbore tubing, and an alternating current electrical sensor disposed within the flow path. The method further includes measuring a property of the wellbore fluid with the alternating current electrical sensor when the wellbore fluid has flowed into the flow path and determining the oil to water ratio of the wellbore fluid that flowed through the flow path.

Fluid identification outside of wellbore tubing

A method and system for performing a velocity correction downhole. A method may include disposing a downhole tool into a borehole, taking one or more measurements of the borehole with one or more pads disposed on the downhole tool, creating one or more images from the one or more measurements to form an image log at a depth within the borehole, identifying a mismatch distance between the one or more images in the image log, and correcting the one or more images at the depth within the borehole based at least in part on the mismatch distance.

Velocity correction with joint inversion

Aspects of the subject technology relate to systems and methods for optimizing telemetry schemes with a constant insensible group delay. Systems and methods are provided for receiving an acquisition including compressed data and dummy data from a downhole logging system, determining a prior decompressor queue size based on the acquisition for a plurality of time intervals, determining a decompressor data size based on the acquisition for the plurality of time intervals, and determining a delay where the prior decompressor queue size is continuously greater than or equal to the decompressor data size for the plurality of time intervals.

Telemetry scheme with a constant insensible group delay

The disclosure presents processes to determine the direction and magnitude of tubing eccentricity along the length of a tube inserted within a borehole. The tubing can be a wireline, a drill string, a drill pipe, or tubing capable of allowing fluid or other material to flow through it. As borehole operations proceed, the tubing can move toward the side of the borehole. This eccentricity can cause excess wear and tear on the tubing, on the casing of the borehole, or on the inner surface of the subterranean formation. The eccentricity can be measured using acoustic signals that are collected downhole covering the azimuthal angles 0° to 360° at a location in the borehole. The collected signals can be filtered, transformed, and analyzed to estimate the tubing eccentricity. Other processes and systems can use the results to obtain cement bond evaluations through tubing and to determine preventative or restorative actions.

Tubing eccentricity evaluation using acoustic signals

Systems and methods generally relate to monitoring, evaluating, and controlling fracture geometry during a hydraulic fracturing operation, in real time. A method comprises measuring a signal representing a condition in a wellbore; inputting the signal into a model for estimating a dimension of a dominant fracture; determining the dimension of the dominant fracture; determining a target dimension for the dominant fracture; and minimizing a difference between the dimension of the dominant fracture and the target dimension in real time, by adjusting at least an injection pressure or flow rate of a hydraulic fracturing fluid into the wellbore.

Real-time fracture monitoring, evaluation and control

A model is used to generate corrections to mitigate ideal condition artifacts in acoustic property values of an annular material in a cased wellbore. A mathematical model that generates acoustic property values at ideal conditions introduces artifacts into the acoustic property values. Acoustic measurements of an annular material are used to generate features that represent wellbore conditions and are not accounted for in the mathematical model that generates acoustic property values. A model will generate corrections for acoustic property values of an annular material with the features to yield a more accurate acoustic property profile for the annular material of a cased hole.

Model-based corrections to acoustic property values of annular material to mitigate ideal artifacts

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Singapore, Singapore

Xiang Wu