Abstract: A system for wireline service planning and advising includes a receiver, one or more computing system processors, and a transmitter. The receiver is configured to receive, from a user of the system, an objective parameter for interpreting a state of a well barrier. The one or more computing system processors is in communication with the receiver and configured to generate a plurality of candidate services based on the objective parameter and a model of the well barrier, each candidate service specifying sensor data to be acquired using wireline tools, select at least one wireline service from the wireline candidate services based on a selection logic or input by the user, and generate an execution plan specifying operational parameters of the selected wireline service. The transmitter is in communication with the one or more computing system processors and configured to transmit the execution plan to execute the selected wireline service at a wellsite.

Abstract: A system for wireline service planning and advising includes a receiver, one or more computing system processors, and a transmitter. The receiver is configured to receive, from a user of the system, an objective parameter for interpreting a state of a well barrier. The one or more computing system processors is in communication with the receiver and configured to generate a plurality of candidate services based on the objective parameter and a model of the well barrier, each candidate service specifying sensor data to be acquired using wireline tools, select at least one wireline service from the wireline candidate services based on a selection logic or input by the user, and generate an execution plan specifying operational parameters of the selected wireline service. The transmitter is in communication with the one or more computing system processors and configured to transmit the execution plan to execute the selected wireline service at a wellsite.

Abstract: Embodiments of the disclosure can include systems and methods for removing in-situ noise from well logging data. In one embodiment, a method can include acquiring noise-calibration data for a logging tool, (the noise-calibration data including data obtained by the logging tool operating under one or more calibration conditions), generating a noise-signature waveform for the logging tool based at least in part on the noise-calibration data, acquiring logging data from the logging tool (the logging data including data obtained by the logging tool operating in a wellbore under one or more operating conditions), generating, based at least in part on the logging data, an uncorrected logging waveform for the logging tool operating in the wellbore under the one or more operating conditions, and modifying the uncorrected logging waveform based at least in part on the noise-signature waveform to generate a corrected logging waveform for the wellbore.

Abstract: A system includes an acoustic logging tool including a transducer configured to: emit a first acoustic pulse in a first direction toward a first acoustic surface; measure a first acoustic signal, wherein the first acoustic signal includes a coherent noise component and a first echo component, wherein the first echo component is due at least in part to an interaction of the first acoustic pulse with the first acoustic surface; emit a second acoustic pulse in a second direction, wherein the second direction is at least partly directed away from the first acoustic surface; and measure a second acoustic signal, wherein the second acoustic signal includes substantially only the coherent noise component. The system also includes a data processing system that includes a processor configured to remove the measurement of the second acoustic signal from the measurement of the first acoustic signal to reduce coherent noise.

Abstract: Methods and devices for obtaining well log data with reduced coherent noise are provided. One such method may include placing a downhole tool into a well to obtain a set of unfiltered well log data that includes individual measurements obtained at various azimuthal angles within the well. Some of the unfiltered well log data may represent eccentered well log data obtained while the downhole tool is eccentered in the well. The individual measurements of the eccentered well log data may have delays that vary as a function of the azimuthal angle at which they were obtained. By comparing the measurements of the eccentered well log data, a common pattern independent of delay, representing coherent noise, may be identified. The common pattern may be subtracted from the well log data to produce filtered well log data that is less noisy than the unfiltered well log data.

Abstract: A system includes an acoustic logging tool including a transducer configured to: emit a first acoustic pulse in a first direction toward a first acoustic surface; measure a first acoustic signal, wherein the first acoustic signal includes a coherent noise component and a first echo component, wherein the first echo component is due at least in part to an interaction of the first acoustic pulse with the first acoustic surface; emit a second acoustic pulse in a second direction, wherein the second direction is at least partly directed away from the first acoustic surface; and measure a second acoustic signal, wherein the second acoustic signal includes substantially only the coherent noise component. The system also includes a data processing system that includes a processor configured to remove the measurement of the second acoustic signal from the measurement of the first acoustic signal to reduce coherent noise.

Abstract: Embodiments of the disclosure can include systems and methods for removing in-situ noise from well logging data. In one embodiment, a method can include acquiring noise-calibration data for a logging tool, (the noise-calibration data including data obtained by the logging tool operating under one or more calibration conditions), generating a noise-signature waveform for the logging tool based at least in part on the noise-calibration data, acquiring logging data from the logging tool (the logging data including data obtained by the logging tool operating in a wellbore under one or more operating conditions), generating, based at least in part on the logging data, an uncorrected logging waveform for the logging tool operating in the wellbore under the one or more operating conditions, and modifying the uncorrected logging waveform based at least in part on the noise-signature waveform to generate a corrected logging waveform for the wellbore.

Abstract: Improved equipment and methods for determining the waiting-on-cement time after a cementing operation involve an optic-fiber coil that immersed in the cement slurry downhole. The intensity of a reflected light signal from the coil is monitored versus time. Attenuation of the reflected-light intensity corresponds to the development of gel strength, allowing operators to unambiguously determine when wellbore operations may recommence after a cement job.

Abstract: Improved equipment and methods for determining the waiting-on-cement time after a cementing operation involve an optic-fiber coil that immersed in the cement slurry downhole. The intensity of a reflected light signal from the coil is monitored versus time. Attenuation of the reflected-light intensity corresponds to the development of gel strength, allowing operators to unambiguously determine when well-bore operations may recommence after a cement job. The optic-fiber coil is wound around a spool such that there is at least one coil crossing on the spool.

Abstract: Methods and devices for obtaining well log data with reduced coherent noise are provided. One such method may include placing a downhole tool into a well to obtain a set of unfiltered well log data that includes individual measurements obtained at various azimuthal angles within the well. Some of the unfiltered well log data may represent eccentered well log data obtained while the downhole tool is eccentered in the well. The individual measurements of the eccentered well log data may have delays that vary as a function of the azimuthal angle at which they were obtained. By comparing the measurements of the eccentered well log data, a common pattern independent of delay, representing coherent noise, may be identified. The common pattern may be subtracted from the well log data to produce filtered well log data that is less noisy than the unfiltered well log data.

Abstract: A flow sensing apparatus includes a light source, at least one fiber Bragg grating and at least one optical fiber. The apparatus may be inserted into a flowing fluid stream, and the fiber Bragg grating detects the vortices of the Von Karman street in the wake of the apparatus. The fiber Bragg grating reflects light emitted from the light source, and the spectral nature of the reflected light provides information concerning the fluid velocity in the flowing stream.

Abstract: Improved equipment and methods for determining the waiting-on-cement time after a cementing operation involve an optic-fiber coil that immersed in the cement slurry downhole. The intensity of a reflected light signal from the coil is monitored versus time. Attenuation of the reflected-light intensity corresponds to the development of gel strength, allowing operators to unambiguously determine when well-bore operations may recommence after a cement job. The optic-fibre coil is wound around a spool such that there is at least one coil crossing on the spool.

Abstract: An avalanche photodiode having an absorption zone, a multiplication zone, and a transition zone disposed between the absorption zone and the multiplication zone, the transition zone being doped and being constituted at least in part by a material of composition that is graded such that the energy bands of the structure are substantially continuous when it is biased, wherein said doping is distributed non-uniformly in said graded composition zone so as to compensate, at least in part, the reverse electric field due to the composition grading of the material in the transition zone.