Abstract: Multi-phase measurements of a fluid in a wellbore can be received and stored by a memory tool for determining flow characteristics of fluid flowing in the wellbore. A system can include a flow meter device, one or more sensors, and a memory tool The flow meter device can include one or more acoustic devices that can be positioned to generate acoustic signals in a wellbore. The one or more sensors can be positioned to detect the acoustic signals from the flow meter device for making multi-phase measurements of fluid with respect to the wellbore. The memory tool can be communicatively coupled to the one or more sensors to receive and store the multi-phase measurements for a predetermined amount of time for determining flow characteristics of the fluid.

Abstract: Aspects of the subject technology relate to systems, methods, and computer-readable media for machine learning analysis of low-frequency signal data in fracturing operations. The present technology can receive strain data associated with a monitoring well that is proximate to a treatment well. The strain data can comprise information representing a fracturing operation associated with the treatment well. Further, the present technology can convert the strain data into image data where a color scale corresponds to a degree of strain observed by a fiber optic cable deployed in the monitoring well. As follows, the present technology can provide the image data to a machine-learning model, which is configured to identify one or more features in the image data.

Abstract: A method for tuning a distributed acoustic sensing (DAS) system. The method may include determining a signal strength from a first Raman Pump in the DAS system, sweeping a laser pulse output from a transmitter; wherein the sweeping is an incremental increase of a power of the laser pulse output from a minimum pulse power to a maximum pulse power, and measuring a first signal-to-noise-ratio (SNR) for each of the incremental increase of the power of the laser pulse output. The method may further comprise selecting a maximum SNR from the first SNR for each of the incremental increase of the power of the laser pulse output and configuring the first Raman Pump and the laser pulse output based at least in part on the maximum SNR.

Abstract: An asymmetric fluidic oscillator can generate acoustic signals in a wellbore. The asymmetric fluidic oscillator can include an inlet housing defining an inlet channel, a feedback system, and an outlet housing defining an outlet channel. The inlet channel can be sized to receive fluid from the wellbore. The feedback system can be coupled to the inlet channel to oscillate the fluid from the wellbore. The outlet channel can be coupled to the feedback system and can be sized to receive the oscillated fluid from the feedback system. The outlet channel can include an asymmetric feature to generate acoustic signals detectable in the wellbore.

Abstract: A downhole tool having a downhole end and an uphole end, including: an anchor assembly positioned proximate to the downhole end; at least one flowmeter assembly selectively positionable from the downhole tool wherein the at least one flowmeter assembly includes a flowmeter having a throughbore generally aligned with an axis of the flowmeter; and a waveguide positioned proximate to the uphole end, wherein the at least one flowmeter assembly is positioned proximate to the anchor, wherein the waveguide extends through the throughbore and is secured at the anchor assembly.

Abstract: A method includes deploying an optical fiber attached to a distributed acoustic sensing (DAS) interrogator in a wellbore, pre-setting gauge length of the DAS interrogator based on an expected measurement signal, interrogating the optical fiber using the DAS interrogator, receiving reflected DAS signals along a length of the optical fiber using the pre-set gauge length, performing an analysis to estimate a location and a magnitude of a strain source associated with the reflected DAS signals, and dynamically adjusting the gauge length for at least a portion of the optical fiber within a pre-defined limit of the DAS interrogator as a function of the estimated location and magnitude of the strain source to enhance sensitivity and to optimize signal-to-noise ratio.

Abstract: A system and method for deploying a fiber optic sensing (FOS) system. The system may include a deployment package that is marinized. The deployment package may include a connection housing for connecting the deployment package to a subsea tree, a valve disposed on the connection housing, and a chamber connected to the valve. The deployment package may also include a cap attached to an end of the chamber opposite the valve and one or more optical connections disposed within the cap. Additionally, the deployment package may include a self-propelling vehicle that is disposed within the chamber and a downhole sensing fiber connected to the self-propelling vehicle.

Abstract: A fiber optic sensing (FOS) system may include a Brillouin Optical Time Domain Analyzer (BOTDA) unit, a first fiber optical cable optically connected to the BOTDA interrogator unit at a first end, and an optical feedthrough system (OFS) optically connected the first fiber optical cable at a second end of the first fiber optical cable. The FOS system may further comprise a fiber optic cable forming a loop within a wellbore that is optically connected to the first fiber optical cable at the OFS and a second fiber optical cable optically connected to the loop at the OFS and wherein the second fiber optical cable is optically connected to the BOTDA interrogator unit.

Abstract: A downhole energy harvesting apparatus comprising a fluidic oscillator comprising: an inlet channel configured to receive fluid from a wellbore, a feedback system coupled to the inlet channel to oscillate the fluid, and an outlet channel coupled to the feedback system and configured to receive the oscillated fluid from the feedback system, and at least one piezoelectric element disposed on at least one side of the outlet channel and configured to generate an electric signal in response to variations in pressure of the oscillated fluid.

Abstract: A method, includes: detecting one or more properties of a waveguide having a downhole end and an uphole end; and responsive to the detected one or more properties, positioning into a passage of a wellbore the waveguide to minimize tension thereof.

Abstract: A fiber optic sensing (FOS) system may include a Brillouin Optical Time Domain Analyzer (BOTDA) unit, a first fiber optical cable optically connected to the BOTDA interrogator unit at a first end, and an optical feedthrough system (OFS) optically connected the first fiber optical cable at a second end of the first fiber optical cable. The FOS system may further comprise a fiber optic cable forming a loop within a wellbore that is optically connected to the first fiber optical cable at the OFS and a second fiber optical cable optically connected to the loop at the OFS and wherein the second fiber optical cable is optically connected to the BOTDA interrogator unit.

Abstract: Aspects of the subject technology relate to systems, methods, and computer-readable media for machine learning analysis of low-frequency signal data in fracturing operations. The present technology can receive strain data associated with a monitoring well that is proximate to a treatment well. The strain data can comprise information representing a fracturing operation associated with the treatment well. Further, the present technology can convert the strain data into image data where a color scale corresponds to a degree of strain observed by a fiber optic cable deployed in the monitoring well. As follows, the present technology can provide the image data to a machine-learning model, which is configured to identify one or more features in the image data.

Abstract: A method is provided. Sensor data regarding a wellbore is received from at least one of a distributed fiber optic sensing line positioned along the wellbore and a plurality of subsurface and surface sensors. Flow models are generated based on the sensor data to optimize production flow. Flow profiles are generated based on the flow models and the sensor data to adjust at least one gas lift valve.

Abstract: A downhole tool having a downhole end and an uphole end, including: an anchor assembly positioned proximate to the downhole end; at least one flowmeter assembly selectively positionable from the downhole tool wherein the at least one flowmeter assembly includes a flowmeter having a throughbore generally aligned with an axis of the flowmeter; and a waveguide positioned proximate to the uphole end, wherein the at least one flowmeter assembly is positioned proximate to the anchor, wherein the waveguide extends through the throughbore and is secured at the anchor assembly.

Abstract: An asymmetric fluidic oscillator can generate acoustic signals in a wellbore. The asymmetric fluidic oscillator can include an inlet housing defining an inlet channel, a feedback system, and an outlet housing defining an outlet channel. The inlet channel can be sized to receive fluid from the wellbore. The feedback system can be coupled to the inlet channel to oscillate the fluid from the wellbore. The outlet channel can be coupled to the feedback system and can be sized to receive the oscillated fluid from the feedback system. The outlet channel can include an asymmetric feature to generate acoustic signals detectable in the wellbore.

Abstract: Introduced herein are system and method for precisely determining the actual location of a standing wave created within a wellbore as well as other key properties about the created wave. The introduced system and method utilize a fiber optic sensing system, such as fiber optic Distributed Acoustic Sensing (DAS) system, that actively interrogates and monitors fiber optic sensors along the length of a wellbore. The introduced system and method generate one or more pressure pulses that combine with one another to create a standing wave within a wellbore and process the acoustic response of the standing wave using the fiber optic DAS system over a wide range of frequencies. Based on the measurements, the introduced system and method determine the actual location of the created standing wave and move it to a desired location within the wellbore by adjusting one or more properties of the pressure pulses.

Abstract: A system can determine multi-phase measurements with respect to a wellbore. The system can include a set of acoustic devices, a measurement device, and a computing device. The set of acoustic devices can be positioned at the surface of a wellbore to generate acoustic signals proportional to flow of fluid with respect to the wellbore. The measurement device can be positioned with respect to the set of acoustic devices to sense the acoustic signals. The computing device can be communicatively coupled to the measurement device to interpret the acoustic signals for determining a type of the fluid and a ratio of one or more phases of the fluid.

Abstract: A system for making multi-phase measurements of a fluid includes a flow meter device and a computing device. The flow meter device can include one or more acoustic devices that can generate acoustic signals in a wellbore. The computing device can receive acoustic signals from the flow meter device and determine an arrangement of the one or more acoustic devices with respect to the wellbore. The computing device can interpret the acoustic signals using the determined arrangement of the one or more acoustic devices to make a multi-phase measurement of fluid with respect to the wellbore.

Abstract: Multi-phase measurements of a fluid in a wellbore can be received and stored by a memory tool for determining flow characteristics of fluid flowing in the wellbore. A system can include a flow meter device, one or more sensors, and a memory tool The flow meter device can include one or more acoustic devices that can be positioned to generate acoustic signals in a wellbore. The one or more sensors can be positioned to detect the acoustic signals from the flow meter device for making multi-phase measurements of fluid with respect to the wellbore. The memory tool can be communicatively coupled to the one or more sensors to receive and store the multi-phase measurements for a predetermined amount of time for determining flow characteristics of the fluid.

Abstract: A downhole energy harvesting apparatus comprising a fluidic oscillator comprising: an inlet channel configured to receive fluid from a wellbore, a feedback system coupled to the inlet channel to oscillate the fluid, and an outlet channel coupled to the feedback system and configured to receive the oscillated fluid from the feedback system, and at least one piezoelectric element disposed on at least one side of the outlet channel and configured to generate an electric signal in response to variations in pressure of the oscillated fluid.