Halliburton Energy Services, Inc.

Gary Wayne Kainer

Chung Lung Chang

Nam Nguyen

Arthur Cheng

David Orlando Torres

Michael S Bittar

Jing Li

Marvin Rourke

Batakrishna Mandal

Baris Guner

Ruijia Wang

Abbas Arian

Paul G Junghans

Muralidhar Seshadri

Randall Bennett Jones

Burkay Donderici

Luis Emilio San Martin

Otto N Fanini

Wei Zhang

Jing Jin

David R Beard

Clovis Satyro Bonavides

Haoshi Song

Laurence T Wisniewski

John Philip Granville

Philip William Tracadas

Gary Lee Fickert

Tianrun Chen

Joonshik Kim

Jean G Saint Germain

Lesley Allison Fessler

Michael Simmons

Gennady Koscheev

Marvin Batres

Hong Li Hou

A downhole sensor position adjustment device on a downhole sensor assembly comprising a set of centralizers and a sensor array coupled to an adjustable framework radially positionable by an actuator. The actuator includes an extend-retract mechanism to radially position the sensor array a predetermined radial distance to an inner surface of a casing. A controller communicatively coupled to the extend-retract mechanism is configured to actuate the extend-retract mechanism. A positioning sensor provides feedback of the predetermined radial distance of the sensor array to the inner surface of the casing.

Adaptive control of rotating or non-rotating transducer and sensors casing stand-off supported by casing centralizers

An acoustic isolator and methods to the same. The acoustic isolator may comprise a body, one or more annular chambers formed inside the body of the acoustic isolator and positioned along a longitudinal axis of the acoustic isolator, an annular groove formed on an outer surface of the body of the acoustic isolator, and a passage disposed between the one or more annular chambers and the annular groove. The method may comprise transmitting an acoustic wave from a transmitter disposed on an acoustic logging tool into a subterranean formation, receiving an acoustic signal from the subterranean formation with a receiver disposed on the acoustic logging tool, and attenuating a second acoustic wave that moves between the transmitter and the receiver and through an acoustic isolator.

Short and wideband isolator for acoustic tools

A method for identifying an operating frequency may comprise performing a frequency sweep using one or more injector electrodes disposed on a downhole tool, recording one or more measurements from the frequency sweep, identifying one or more stable frequencies from the frequency sweep, and identifying one or more operating frequencies from the one or more stable frequencies. A system for electrical isolation may comprise a downhole tool, a pad, an arm, wherein the arm is attached to the mounting bracket and the mandrel, and an information handling system connected to the pad through the first set of electronics and the second set of electronics. The downhole tool may comprise a mandrel, a chassis disposed in the mandrel, and a first set of electronics disposed in the chassis.

Electromagnetic imager design

A method includes deploying a logging tool in a borehole formed in a subsurface formation, the logging tool having a transmitter and a receiver, wherein a condition that is present during logging comprises at least one of a shape of the borehole is non-circular and the logging tool is off-center within the borehole. The method includes emitting, by the transmitter, a signal into subsurface formation and detecting, by the receiver, a response to the signal being propagated through the subsurface formation. The method includes creating, from the response, a borehole image that includes features in the subsurface formation and correcting the features, wherein correcting the features comprises mapping points of a non-circular shape in the borehole image into a plane substantially perpendicular to an axis of the borehole.

Dip correction for non-circular borehole and off-center logging

A method and system for estimating a resistivity of a formation. A method for estimating a resistivity of a formation may comprise disposing a downhole tool into a borehole, wherein the downhole tool comprises a pad, an injector electrode, and a return electrode, injecting a current signal into the formation from the injector electrode, measuring a voltage signal between the injector electrode and the return electrode; and determining a formation resistivity and a formation dielectric constant from at least one of the voltage signal, at least one property of the downhole tool, and at least one property of the borehole. A system for estimating a resistivity of a formation may comprise a downhole tool. The downhole tool may comprise a pad, wherein the pad comprises an injector electrode and a return electrode. The system may further comprise a conveyance for disposing the downhole tool in a borehole and an information handling system.

Method to estimate formation resistivity

A method for imaging a downhole formation. The method includes combining the captured images to generate a partial image of the formation, wherein the partial image includes captured images separated by gaps representing portions of the formation not captured with sensors what were disposed downhole. The method includes locating dips in the formation within the partial image and interpolating the partial image using the located dips within the partial image.

Dip detection in logging image processing

Disclosed are systems and methods for processing acoustic logging information with automatic dispersion matching. The method comprises obtaining, from an acoustic logging tool, acoustic waveforms from within a borehole, applying dispersion analysis to the acoustic data to extract a slowness-frequency response, calculating a slowness density log of the slowness-frequency response, obtaining an initial shear slowness estimate based on the slowness density, generating a dispersion model comprising model parameters, and performing a dispersion response auto match inversion to minimize the difference between the slowness-frequency response and the dispersion model in order to obtain a final shear slowness estimate.

Borehole dispersive wave processing with automatic dispersion matching for compressional and shear slowness

A method for identifying a shape of a borehole may comprise disposing a downhole tool into the borehole, wherein the downhole tool comprises at least one transducer, transmitting a pressure pulse from the at least one transducer, wherein the pressure pulse is reflected as an echo, recording the echo with the at least one transducer, producing data points based at least in part on the echo, each data point including a radial distance value and an azimuthal value corresponding to the radial distance value, performing a pre-selection, fitting a geometric shape to a plurality of data points within the borehole, and sorting out at least one of the plurality of data points based at least in part on the shape. A system for identifying shape of a borehole may comprise at least one transducer and an information handling system.

Iterative borehole shape estimation of cast tool

A method includes deploying a logging tool in a borehole formed in a subsurface formation. The logging tool has a transmitter and a receiver. The method includes emitting, by the transmitter, a signal into subsurface formation. The method includes detecting, by the receiver, a response to the signal being propagated through the subsurface formation. The method includes creating, from the response, a borehole image that includes distorted features representing bedding dips in the subsurface formation. The method includes correcting the distorted features, wherein correcting the distorted features comprises mapping points of a non-circular shape in the borehole image to points on a circular shape.

Techniques for estimating and visually presenting formation slowness are disclosed herein. The techniques include receiving acoustic signal responses from adjacent formations at a plurality of depths in a borehole environment, mapping a distribution of the acoustic signal responses at each depth according to slowness and a frequency values, determining at least one confidence interval to define a coherence threshold for the distribution of the acoustic signal responses at each depth, generating a variable density log for each depth based on the distribution of acoustic signals responses that satisfy the confidence interval for one or more frequency ranges, determining a formation slowness value for each depth based on the variable density log for the each depth, and presenting a semblance map that includes a slowness axis, a depth axis, the formation slowness value for each depth, and at least a portion of the distribution of acoustic signal responses at each depth.

Identifying and visually presenting formation slowness based on low-frequency dispersion asymptotes

According to embodiments of the disclosure, a downhole tool for taking acoustic measurements in a wellbore is provided. The tool may have an acoustic dipole transmitter with a piston made from a soft magnetic material, mounted on a centering spring between the first coil and the second coil, which moves the piston bi-directionally along a longitudinal axis when energized. The tool may also have a feedback winding on at least one of the first or second coils. The tool may also have a circuit for energizing the first and second coils which includes an input for receiving a signal responsive to the position of the piston relative to the coils and a processor for determining an output waveform used to generate an acoustic signal.

Acoustic dipole piston transmitter

An acoustic tool for evaluating a geologic formation includes a housing member disposed between transmitter and receiver sections of the acoustic tool. The housing member defines a change in direction in an acoustic path extending therethrough such that acoustic signals traveling through the housing member are delayed and disrupted. The delay and disruption may isolate the acoustic signals traveling through the housing member from acoustic signals traveling through the geologic formation. Thus, the acoustic tool may facilitate identification and evaluation of acoustic signals traveling through the geologic formation.

Structural element for sonic tools and acoustic isolators

A disclosed high-purity dipole transmitter has a longitudinal axis, an oscillation axis, and a side axis, each of the axes being mutually orthogonal. The transmitter includes an outer shell having external surfaces for displacing fluid along the oscillation axis. The transmitter also includes a reaction mass positioned inside the outer shell. The transmitter also includes an electromagnetic actuator that drives the outer shell relative to the reaction mass. The transmitter also includes a pair of matching springs separated along the longitudinal axis, where each spring is coupled between the outer shell and the reaction mass to enable compliant dipole motion of the outer shell along the oscillation axis while suppressing motion along other axes. Each spring includes a beam arrangement with each beam extending lengthwise in a direction parallel to the side axis and being thinnest in a direction parallel to the oscillation axis. The outer shell, the reaction mass, the electromagnetic actuator, and each spring, have mirror symmetry in a plane that includes the oscillation axis and the longitudinal axis, and have mirror symmetry in a plane that includes the side axis and the longitudinal axis.

High-performance dipole acoustic transmitter

The disclosure addresses multiple embodiments of an acoustic isolator, and an acoustic logging tool which incorporates the acoustic isolator. The acoustic isolator is configured to minimize acoustic transmissions which could otherwise adversely affect acoustical measurements being made by an acoustic receiver. The described acoustic isolators include a plurality of longitudinally arranged mass members coupled to a central supporting structure, in a configuration to reduce acoustic transmissions in at least selected frequency ranges.

Acoustic isolator for downhole tools

Various systems and methods for implementing and using a variable stiffness downhole tool housing include cylindrical segments positioned along a common axis, with a pair of segments each coupled to a bulkhead and positioned at either axial end of the tool housing. The housing also includes a flexible cylindrical sleeve, positioned along the common axis between two of the plurality of cylindrical segments, that includes a first and second region with an outer diameter no larger than a common segment inner diameter and a third region located between the first and second regions and with an outer diameter no larger than a common segment outer diameter (the first and second regions each at least partially inserted into an end of one segment). A stiffness controller controls the stiffness of the tool housing by controlling at least part of an axial force exerted between the two segments.

Growing community of inventors

Tomball, TX, United States of America

Gary Wayne Kainer