Halliburton Energy Services, Inc.

Peng Li

Chung Lung Chang

Rodney Allen Marlow

Yu Weng

Batakrishna Mandal

Jing Jin

Richard Timothy Coates

Ziyang Li

Xiang Wu

Yao Ge

Boguslaw Wiecek

Zheng Chen

Haoshi Song

William Joseph Schaecher

Wei Sun

Joni Lie

Lianhe Guo

Xiang Tian

Wesley N Ludwing

Michael Shaun Spencer

Jose Sanchez

A system for high voltage protection may comprise a high voltage protection module electrically connected to a transmitter module and a receiver module and a muting module connected to the high voltage protection module and the receiver module. A method for high voltage protection may comprise disposing a downhole tool into a wellbore, transmitting an excitation signal from the transmitter module to transceiver as a high voltage pulse signal to the high voltage protection module, reducing the high voltage pulse signal with the high voltage protection module, and preventing saturation of the receiver with a low impedance interface from the muting module.

High voltage protection and receiver saturation prevention apparatus with high voltage peeking functions for downhole logging

Disclosed herein is a method for eccentricity correction. This method may dispose a downhole tool into a borehole. The downhole tool may comprise a measuring assembly that has at least one transducer, determining a beam pattern from the at least one transducer, determining a center of the measurement assembly in the borehole with the beam pattern, calculating a beam pattern factor with at least the beam pattern, calculating an angle factor with at least the beam pattern, calculating an eccentricity factor with at least the beam pattern factor and the angle factor, and creating an eccentricity corrected image with at least the eccentricity factor.

Downhole ultrasound image correction in oil based mud

The disclosure provides an acoustic logging device comprising a first tubular member comprising a plurality of grooves disposed on an exterior of the first tubular member. The acoustic logging device further comprises a ring transmitter module disposed around an exterior of the first tubular member, which comprises a piezoelectric (PZT) ring transmitter, a transmitter sleeve, wherein the PZT ring transmitter is disposed within the transmitter sleeve, and a cage, wherein the transmitter sleeve is disposed between the cage and the exterior of the first tubular member, wherein the transmitter sleeve is disposed over the plurality of grooves. The acoustic logging device further comprises a plurality of dual bender transmitters, wherein there is a gap disposed the plurality of dual bender transmitters in the exterior of the first tubular member, wherein there is an array of holes connecting each of the gaps together and providing fluid communication between the gaps.

Robust logging-while-drilling sonic transmitters with improved strength and bandwidth

A method and system method for determining motion of a downhole tool and feeding back drilling performance. The method may comprise taking a synchronous tool face measurement of the downhole tool, taking a synchronous pulse-echo acquisition to estimate a shape of a borehole, inputting at least the shape of the borehole, the center trajectory of the downhole tool, the rotational time of the downhole tool, the position of the downhole tool, and the one or more measurements of the downhole tool into an information fusion for drilling dynamics, identifying at least one of a whirl, a vibration, or a stick-slip of the downhole tool, and identifying one or more borehole condition and a drilling efficiency. A system may comprise a downhole tool, at least two transducers, and an information handling system.

Downhole tool dynamic and motion measurement with multiple ultrasound transducer

A method for generating acoustic images corrected for distortions caused by attenuation of the ultrasonic signal by the mud may comprise disposing a downhole tool into a borehole, transmitting a pressure pulse from at least one transducer into the borehole, recording an echo with the at least one transducer, measuring a travel time, measuring an amplitude, determining a geometry of the borehole, determining a location of the downhole tool in the borehole, calculating an incident angle, mapping a mud attenuation, and correcting an image. A system for generating acoustic images corrected for distortions caused by attenuation of the ultrasonic signal by the mud comprising a downhole tool that may comprise a measuring assembly, wherein the measuring assembly comprises at least one transducer and wherein the at least one transducer is configured to emit a pressure pulse and record an echo. The system may further comprise an information handling system.

A method for echo detection may comprise recording one or more reflected waveforms, segmenting the one or more reflected waveforms based at least in part on a firing pulse length, applying a shaped filter to each segment of the one or more reflected waveforms, decoupling the one or more reflected waveforms into a time-frequency energy map, extracting a firing frequency band time domain plot from the decoupled time-frequency map, identifying a maximum amplitude in the extracted firing frequency band of the one or more reflected waveforms as an excitation, and identifying a second maximum amplitude in the extracted firing frequency band of the one or more reflected waveforms as an echo. A system for echo detection may comprise a digital signal processor, a transmitter, a transducer, a receiver, an analog to digital converter configured to digitize the measurement, and an information handling system.

Echo detection and measurement in noisy environment for downhole logging

A communication system can include a first transceiver and a second transceiver that can communicate digital baseband data via a direct current (DC) power line bus in the wellbore. One or more of the transceivers includes a demodulator for demodulating the digital baseband data received from the DC power line bus into multiple digital data streams, and includes a digital processor for filtering and applying error correction to the digital data streams to produce a decoded digital data stream.

Digital baseband communication on power line downhole

A communication system can include a first transceiver device and a second transceiver device that can communicate digital baseband data via a direct current (DC) power line bus in the wellbore. One or more of the transceivers includes a coupler for the DC power line bus for transceiving data via the DC power line bus with the other transceiver device, modulation circuitry, demodulation circuitry, and compensator circuitry. The compensator circuitry can be communicatively coupled to the coupler for providing an operating point to the coupler in response to both the modulation circuitry and the demodulation circuitry being in an idle state, to reduce effects of low frequency drift and noise in signals.

Noise compensation for communication on power line downhole

A system for determining a borehole shape may comprise a measurement assembly, wherein the measurement assembly may comprise a housing with an outer surface, a transducer disposed flush along the outer surface of the housing, and an extruded boss that connects to the outer surface of the housing. A method may comprise disposing a downhole tool that includes an instrument section into a wellbore and transmitting an excitation from the transducer into the wellbore, wherein the excitation is reflected off a wellbore wall as an echo.

Echo velocity measurements without using recessed ultrasonic transceiver

A method and system for reducing transducer ringing. The method may comprise identifying a first set of waveforms and a second set of waveforms from recorded waveforms taken by a transducer, estimating an invariant component for each waveform in the first set of waveforms, and subtracting the invariant component from the second set of waveforms. The system may comprise a downhole tool. The downhole tool may comprise at least one transducer and wherein the at least one transducer is configured to emit an excitation and record a plurality of waveforms. The system may further comprise an information handling system configured to identify a first set of waveforms and a second set of waveforms from the plurality of waveforms from the at least one transducer, estimate an invariant component for each waveform in the first set of waveforms, and subtract the invariant component from the second set of waveforms.

Transducer ringing

A system may comprise a transmitter amplifier, a first isolation module, a first transducer, a first receiver, a second isolation module, a second transducer, wherein the second isolation module is connected to the second transducer, and a second receiver, wherein the second isolation module and the second transducer are connected to the second receiver. A method may comprise disposing a downhole tool into a wellbore, transmitting an excitation signal from the transmitter amplifier to the first transducer and the second transducer through the first isolation module and second isolation module, and creating a pressure pulse from the first transducer and the second transducer, sensing the echo with the first transducer and the second transducer, converting the echo into a received signal at the first transducer and the second transducer, and transmitting the received signal to the first receiver and the second receiver.

Transmitter and receiver interface for downhole logging

An example method may include transmitting a first acoustic signal from a downhole tool using a transmitter gain in a transmitter circuit. A first echo signal associated with the first acoustic signal may be received at the downhole tool using a receiver gain in a receiver circuit. At least one of the transmitter gain and the receiver gain may be adjusted based, at least in part, on the received first echo signal and at least one previously received echo signal.

Dynamic gain system with azimuthal averaging for downhole logging tools

An example cement and casing evaluation tool includes an amplifier and a filter coupled an output of the amplifier. A transducer may be coupled to the output of the filter. A ringing reduction system may be coupled to at least one of the amplifier, the filter, and the transducer, wherein the ringing reduction system selectively dissipates energy from at least one of the amplifier, the filter, and the transducer in response to a control signal.

Casing and cement evaluation tool with reduced transmitter ringing

Systems and methods are provided for generating a phase compensated numerically controlled signal using a fixed-point algorithm. In one example, a method includes receiving, at a downhole device, parameters including an input frequency and a compensation value. The method further includes converting, based on the parameters, the input frequency to a delta phase value. The method also includes calculating, with the downhole device, an accumulation error for a digital signal. In response to determining that the accumulation error is greater than or equal to the compensation value, the method removes the accumulation error from the digital signal to generate an output signal.

Phase compensated fixed-point numerically controlled oscillator for downhole logging

An example method includes determining a frequency response of a tuned pulse to be transmitted from a transmission element. A matching frequency envelope corresponding to a frequency envelope of the frequency response may be determined. A time domain signal corresponding to the matching frequency envelope may be determined. A series of digital pulses corresponding to the time domain signal may be determined. An analog output at a switching amplifier corresponding to the series of digital pulses may be generated. A transmission element may be excited with the analog output.

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Houston, TX, United States of America

Peng Li