Halliburton Energy Services, Inc.

Joni Lie

Alberto Quintero

Burkay Donderici

Luis Emilio San Martin

Nam Nguyen

Daniel Viassolo

Yi Yang Ang

Abdul Qadir Shabbir

Batakrishna Mandal

Yinghui Lu

Peng Li

Avinash Vinayak Taware

William Joseph Schaecher

Guosheng Jin

Xiaohong Zhang

Tools, systems, and methods may be configured for or include detecting one or more underground acoustic sources and localizing them in depth and radial distance from a wellbore using an array of at least three acoustic sensors disposed in the wellbore in conjunction with array-signal-processing that accounts for movement of the acoustic sensors and spatial aliasing by using adaptive time dependent modelled steering vector weights.

Continuous beamforming while moving: method to reduce spatial aliasing in leak detection

The disclosed embodiments include leak detection systems and methods of downhole leak detection. In one embodiment, the method includes obtaining physical signals measured by at least one physical sensor traveling along a wellbore. The method also includes performing a frame decomposition operation on the physical signals of a first of the at least one the physical sensor to obtain a plurality of virtual signals associated with an array of virtual sensors, each virtual sensor of the array of virtual sensors being located at a virtual distance relative to the first physical sensor, the virtual distance corresponding to a physical distance. The method further includes synchronizing the virtual signals of the array of virtual sensors. The method further includes computing a spatial spectrum indicative of a location of a leak based on the synchronized virtual signals.

Systems and methods to utilize a sensor to provide spatial resolution in downhole leak detection

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

A resistivity logging tool includes a plurality of excitation electrodes, at least one return electrode, and a plurality of monitor electrodes. The resistivity logging tool also includes a controller that determines a set of independent currents to be emitted by at least some of the plurality of excitation electrodes during an excitation cycle based on at least one measured downhole parameter and at least one predetermined constraint.

Resistivity logging tool with excitation current control

A resistivity logging system includes a plurality of excitation electrodes, at least one return electrode, and a plurality of monitor electrodes. The resistivity logging system also includes a controller that determines a level of excitation current to be emitted by at least one of the plurality of excitation electrodes during a subsequent excitation cycle based on a comparison of measured downhole parameter values corresponding to excitation current emitted in two previous excitation cycles.

Resistivity logging tool with excitation current control based on multi-cycle comparison

In a logging system (), multiple receiver units () are synchronized over a control area network (CAN) bus () without use of separate differential lines. A ready for synchronization command is received over the CAN bus (). In response to receiving the ready for synchronization command, a start synchronization interrupt is enabled. A start synchronization command is then received over the CAN bus (). In response to receiving the start synchronization command, the start synchronization interrupt is triggered for capturing formation signals which are produced responsive to excitation signals from a transmitter unit ().

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Singapore, Singapore

Joni Lie