A system for measuring fluid flow in a wellbore is provided. A probe includes at least a heater. A fiber optic cable is connected to the probe. The system is programmed to perform operations including: changing an output of the heater to thereby change a temperature of drilling fluid moving over a fiber optic cable; measuring a strain on the fiber optic cable caused by changing the temperature of the drilling fluid; preliminarily determining a velocity of the drilling fluid from the measured strain; measuring at least a second parameter of the drilling fluid; adjusting the preliminary determined velocity based on the measured at least a second parameter to yield an adjusted velocity; and determining a flow rate of the drilling fluid based on the adjusted velocity.

Pressure-inducing devices and pressure transducers can be used to detect and quantify liquid pools in hydrocarbon fluid pipelines. Pressure fluctuations can be detected by a pressure transducer, where the pressure fluctuations are the response of a pressure-inducing device outputting a pressure signal in a pipe carrying hydrocarbons. Variation in a pipe diameter caused by pooling or deposition can be estimated using an inverse model. The pooling or depositions can be classified by applying a machine-learning model to the pressure fluctuations. The variation in pipe diameter can be converted to an equivalent liquid volume for pooling locations. A pooling or deposition location and volume can be output and used for determining an action on the pipe to remove the pooling or deposition.

Embodiments herein generally relate to systems and methods to determine the composition, properties, and morphology of a liquid in a liquid handling structure. Aspects disclosed include exploiting spatiotemporal constraints of zero-group-velocity modes for non-contact, non-invasive, liquid sensing applications.

Various embodiments include a method for determining the mixing ratio R of a fluid comprising a mixture of at least two different fluids for a technical process in a device comprising: irradiating an ultrasonic signal with a transmission level along a measuring distance running inside a measuring section; measuring a receiving level of the ultrasonic signal at one end of the measuring distance; determining an ultrasonic attenuation of the ultrasonic signal attenuated by the fluid based at least on the transmission and receiving levels of the ultrasonic signal; measuring a temperature of the fluid flowing through the measuring section; and determining a mixing ratio of the at least two different fluids from the determined ultrasonic attenuation and from the measured fluid temperature.

A method for determining antifreeze content in a fluid of a heating, ventilation, and air conditioning (HVAC) system includes receiving, in a processor, measurement data of the fluid, the measurement data comprising a measured temperature of the fluid and a measured speed of sound in the fluid, calculating, in the processor, for each of a plurality of antifreeze concentration values a fitting parameter, using the measurement data and one or more of previous measurement data or previous antifreeze concentration data, and determining, in the processor, an antifreeze concentration in the fluid by selecting the antifreeze concentration value with an optimal fitting parameter.

Techniques include flowing a multiphase fluid from a hydrocarbon production well through a conduit; measuring, with an ultrasonic tomographic multiphase flow meter (UMM), ultrasonic waveforms generated by the UMM from the multiphase fluid; measuring properties of the multiphase fluid with fluid measurement sensors coupled to the conduit; identifying the ultrasonic waveforms and the properties with a machine-learning control system; determining multiphase fractions of the multiphase fluid from the one or more ultrasonic waveforms with a first ML model; determining a total flow rate of the multiphase fluid from the measured properties of the multiphase fluid with a second ML model; and determining a volumetric flow rate of a liquid phase or a gas phase based on the determined multiphase fraction and the determined total flow rate.

In the present invention a controllable acoustic source (14) in connection with the process fluid (10) emits a signal (18) into the fluid (10), consisting of a suspension of particles (12), being volumes of gas, liquid or solid phase. The controllable acoustic signal (18) is allowed to interact, with the particles (12), and the acoustic (pressure) signals (22) resulting from such an interaction is measured preferably via a sensor (24). A spectrum is measured. The spectrum is used to predict properties, content and/or size of the particles (12) and/or used to control a process in which the process fluid (10) participates. The prediction is performed in the view of the control of the acoustic source (14). The used acoustic signal has preferably a frequency below 20 kHz.

An apparatus and method for multi-bounce acoustic signal material detection is provided. The apparatus includes a container containing a quantity of material therein, wherein the quantity of material has at least two segmented layers. First and second acoustic sensors are positioned on a sidewall of the container, wherein the first acoustic sensor is positioned at a different height along the sidewall than the second acoustic sensor. An acoustic signal is transmitted into the sidewall of the container from the first acoustic sensor. The acoustic signal reflects between an interior surface of the sidewall and an exterior surface of the sidewall until it is received at the second acoustic sensor. A border between the at least two segmented layers of the quantity of material is detectable based on the acoustic signal.

Systems and methods for material composition detection includes a vessel containing a quantity of a fluid composition therein which has at least a first and second fluids. At least one acoustic transducer is positioned on an exterior sidewall of the vessel. A computerized device has a processor and is in communication with the acoustic transducer. A metric of a property of the first fluid is determined based on a first signal of the acoustic transducer. A metric of a property of the second fluid is determined based on a second signal of the acoustic transducer. A metric of a property of the fluid composition at a point in time is determined based on the metrics of the first and second fluids, and at least a determinable volume of at least a portion of the vessel. A material identity of the fluid composition is determined at the point in time.

Embodiments of the invention provide a “tool-kit” of processing techniques which can be employed in different combinations depending on the circumstances. For example, flow speed can be found using eddy tracking techniques, or by using speed of sound measurements. Moreover, composition can be found by using speed of sound measurements and also by looking for turning points in the k-w curves, particularly in stratified multi-phase flows. Different combinations of the embodiments can therefore be put together to provide further embodiments, to meet particular flow sensing requirements, both on the surface and downhole. Once the flow speed is known, then at least in the case of a single phase flow, the flow speed can be multiplied by the interior cross-sectional area of the pipe to obtain the flow rate. The mass flow rate can then be obtained if the density of the fluid is known, once the composition has been determined.