Halliburton Energy Services, Inc.

Christopher A Golla

Paul F Rodney

Hsu-Hsiang Wu

Randal Thomas Beste

Laban M Marsh

Matthew Chase Griffing

Imran Sharif Vehra

Burkay Donderici

Michael S Bittar

Adan Hernandez Herrera

James H Dudley

James Joseph Freeman

Bipin Kumar Pillai

Svetozar Dimitrov Simeonov

Cili Sun

Paul D Beene

Roger Lynn Schultz

Richard Thomas Hay

Daniel Winslow

James E Masino

Zinovy B Krugliak

Joe Marzouk

Luis Emilio San Martin

Mark Anton Proett

Michael Dewayne Finke

Jin Ma

Neelesh V Deolalikar

James M Lin

Kennedy John Kirkhope

John Ransford Hardin, Jr

Jonathan Peter Zacharko

Clint Paul Lozinsky

John R Hardin

Weixin Dong

Sergei Sharonov

Ron Dirksen

Preston N Weintraub

David Yan Lap Wong

Mac Upshall

William David Bethancourt

Ranganathan Sridharan

Wenhao Chen

Blaine C Comeaux

Andre Krisna

Bhargav Patel

Rameez Balagamwala

Daniel M Winslow

Clint P Lozinsky

David Yan Wong

Jonathan P Zacharko

Randal T Beste

Luis E San Martin

Svetozar Simeonov

An apparatus, method, and system for determining the propagation delay for a downhole wire and/or for monitoring the integrity of a downhole wire. The apparatus includes a first tool component and a second tool component spaced apart from the first tool component and communicatively coupled by a wire. The tool components include impedance altering devices configured to alter, for a predetermined period of time, either the source impedance at a first termination point of the wire and/or the load impedance at a second termination point of the wire sufficient to generate a characteristic signal reflection upon the transmission of a signal along a length of the wire between the first tool component and the second tool component.

Downhole wire integrity and propagation delay determination by signal reflection

A method for calibrating a downhole tool may comprise disposing a downhole tool in a borehole, transmitting a signal from a master module disposed on the first device to a module disposed on the second device, transmitting a return signal from the module to the master module, receiving the return signal with the master module, measuring a tone enabled delay for the signal to travel from the master module to the module, and determining a time delay of a return signal to travel from the module to the master module. A well measurement system may comprise a downhole tool. The downhole tool may further comprise a first device and a master module disposed on the first device, wherein the master module may comprise a master transmitter and a master receiver. In examples, the downhole tool may further comprise a second device and a module disposed on the second device.

Clock calibration of remote systems by roundtrip time

A method and system for detecting a conductive member in a formation. The method may comprise disposing an electromagnetic induction tool into a wellbore, transmitting the electromagnetic field from the at least one electromagnetic source, energizing the conductive member in a second wellbore, wherein an eddy current is induced in the conductive member, transmitting a second electromagnetic field from the conductive member, wherein the second electromagnetic field is formed by the eddy current, sensing the second electromagnetic field with the receiver, recording an amplitude of the second electromagnetic field as data, and transmitting the data to an information handling system. A system for detecting a conductive member in a formation may comprise an electromagnetic induction tool. The electromagnetic induction tool may comprise at least one electromagnetic source and at least one receiver. The system may further comprise an information handling system.

Determination on casing and formation properties using electromagnetic measurements

A modular downhole logging system includes a transmitter module having a local frequency, wherein the transmitter module transmits interrogation signals into a formation based on the local frequency. The downhole system also includes a receiver module axially-spaced from the transmitter module and that receives response signals corresponding to the interrogation signals, wherein the receiver module includes sampling logic and sync estimation logic. The sync estimation logic is configured to perform sync estimation operations including estimating the local frequency of the transmitter module based on analysis of response signal Fourier transform results corresponding to different frequencies. The sampling logic/clock is configured to sample the response signals based on the estimated local frequency of the transmitter module, wherein a processor derives formation property values using the sampled response signals.

Methods and systems with estimated synchronization between modular downhole logging system modules

A method for synchronizing signals among transmitters and receivers of a logging tool positioned in a borehole is provided. Measurement signals generated from operating a transmitter in the borehole are acquired by a receiver. An operating frequency of the receiver is determined by a processing unit. The operating frequency of the receiver is different from an operating frequency of the transmitter. A sampling frequency of the receiver is determined based on the determined operating frequency. A phase delay of the receiver is determined by the processing unit. The acquired measurement signals are adjusted by the processing unit based on the determined sampling frequency and the phase delay of the receiver.

Methods to synchronize signals among antennas with different clock systems

An example slip-ring interface may include a first section and a second section rotationally independent from the first section. At least one conductor path between the first section and the second section may be selectively associated with and dedicated to the transmission of signals with a first signal type. At least one conductor path between the first section and the second section may be selectively associated with and dedicated to the transmission of signals with a second signal type. If error conditions occur, the signal types associated with one or more of the conductor paths may be changed so that signals of both the first and second signal types are transmitted across the interface.

Redundant, adaptable slip ring

In at least some embodiments, a high-voltage drilling system includes a a power supply to output high-voltage power to an electrical conductor, a bit that extends a borehole based on the high-voltage power, and a hybrid drillstring that transports a fluid flow from the bit to convey detached formation material out of the borehole. At least part of the electrical conductor resides within the hybrid drillstring to convey power to the bit. The hybrid drillstring includes a coiled tubing section and a jointed pipe section.

High-voltage drilling methods and systems using hybrid drillstring conveyance

According to aspects of the present disclosure, systems and methods for controlling the speed of a fluid-controlled drive mechanism are described herein. An example system may include a housing, a variable flow fluid pathway disposed within the housing, an electromagnet coupled to the housing, a fluid-controlled drive mechanism in fluid communication with the variable flow fluid pathway, and a load-generating assembly coupled to the fluid-controlled drive mechanism. An example method may include altering a variable flow fluid pathway disposed within a housing, wherein the variable flow fluid pathway is in fluid communication with a fluid-controlled drive mechanism, and generating an electrical current through an electromagnet, wherein the electromagnet is coupled to the housing.

Dual-type speed control mechanism for a turbine

A method for performing ranging measurements within a formation includes transmitting an asymmetric time-varying signal from a transmitter () disposed within a borehole () in the formation. The asymmetric time-varying signal may have a signal characteristic that is based at least in part on a downhole characteristic. A (receiver) disposed within the borehole () may measure a magnetic field induced on an object () within the formation by the asymmetric time-varying signal. A direction to the object () from the borehole () may be determined based at least in part on the measurement of the induced magnetic field.

Ranging measurements using modulated signals

In some embodiments, an apparatus and a system, as well as a method and an article, may operate to retrieve a parsing instructions file and a binary configuration file stored in a housing, parse the binary configuration file according to the parsing instructions file to determine configuration information, display at least some of the configuration information as part of a graphical user interface, receive a selection of some of the configuration information and corresponding changed parameter values of the configuration information, transform the binary configuration file into a transformed version of the binary configuration file, and transmit the transformed version of the binary configuration file to the housing as a replacement for the binary configuration file. Additional apparatus, systems, and methods are described.

Self-defining configuration apparatus, methods, and systems

In one example of rotational ranging in a wellbore in which a wellbore component having an axis of rotation is disposed, a wellbore ranging sensor is disposed on a circumferential area surrounding the axis of rotation. The sensor is moved on the circumferential area to multiple distinct sensing positions. At each sensing position, a magnetic field from another wellbore that is apart from the wellbore is measured resulting in multiple magnetic field measurements at the multiple distinct sensing positions. The multiple magnetic field measurements are provided to determine a position of the wellbore relative to the other wellbore using at least a subset of the multiple magnetic field measurements.

Rotational wellbore ranging

A rotationally independent wellbore ranging system includes a housing which is attached to a rotary component positioned in a first wellbore and remains substantially stationary relative to the first wellbore when the rotary component rotates in the first wellbore. Multiple sensors affixed to the housing are operable to receive multiple ranging signals from a second wellbore while the rotary component rotates in the first wellbore, and provide the multiple ranging signals to a processor to determine a position of the first wellbore relative to the second wellbore.

Rotationally-independent wellbore ranging

Methods and systems that compensate for magnetic interference in azimuthal tool measurements. At least some method embodiments include a downhole logging method that includes taking measurements as a function of orientation from inside a borehole. The measurements are associated with different azimuthal bins, and an azimuthal direction is determined for each azimuthal bin. Because the tool rotates at a constant rate, the relative number of measurements associated which the different bins can be used to measure the effective sizes of the different bins and to redetermine the effective angles of the bins in the presence of magnetic interference. The tool measurements may include, but are not limited to, formation resistivity, magnetic field, and formation density.

Correcting for magnetic interference in azimuthal tool measurements

A measurement system for collecting data. The measurement system includes a tubular suspended downhole, the tubular having an outer surface and a flowbore extending therethrough, the flowbore conveying a fluid, a first recess formed in the outer surface of the tubular, a first detection system mounted in the first recess, a second recess formed in the outer surface of the tubular, and a second detection system mounted in the second recess. The second recess is offset relative to the first recess by at least one of an axial distance and a circumferential distance. The first detection system is operable to measure a portion of the data, and the second detection system operable to measure another portion of the data.

Drill string tubular with a detection system mounted therein

A string of subs includes a controller sub. The controller sub includes a first end, a second end, a controller, a first controller bus coupled to the controller, the first controller bus exiting at the first end of the controller sub, and a second controller bus coupled to the controller, the second controller bus being separate from the first controller bus, the second controller bus exiting at the second end of the controller sub. The string of subs also includes a first measuring sub and a second measuring sub. A process, running on a computer, discovers that the first measuring sub is connected to the first controller bus, discovers that the second measuring sub is connected to the first controller bus, determines that the first measuring sub is physically closer to the controller sub than the second measuring sub, and use the fact that the first measuring sub is physically closer to the controller sub than the second measuring sub in controlling the operation of the string of subs.

Determining the order of devices in a downhole string

Growing community of inventors

Houston, TX, United States of America

Christopher A Golla