This identification apparatus is for identifying the degree of degradation of oil and includes a sensor that detects a substance arising from oil contained in an oil tank and a controller that determines the degree of degradation of the oil based on information related to the substance detected by the sensor and the distance from the oil tank containing the oil to the sensor.

The present invention relates to an apparatus for treating a pathology, comprising: an ultrasonic generation device (1), a remote control unit (2) to supply electricity to the device (1), electrical connection means (31, 32) between the device (1) and the control unit (2), remarkable in that the control unit (2) is programmed to assess the quality of the acoustic coupling between the ultrasonic device (1) and a tissue to be treated.

Embodiments of the disclosure relate to an ultrasonic characterization method for a flowstream to detect impurities that can include placing a first transducer and a second transducer aligned confocally to a flowstream, transmitting, from the first transducer, ultrasonic waveform signals into the flowstream, receiving, by the second transducer, the ultrasonic waveform signals, removing waveform signal reflections using a pitch-catch configuration of the first transducer and the second transducer, detecting waveform signals indicating impurities in the flowstream using induced nucleation of the impurities, detecting waveform signals indicating bubbles in the flowstream using nonlinear dynamic behaviors of the bubbles, and differentiating between the waveform signals of the impurities and the waveform signals of the bubbles using cavitation properties of the impurities and the bubbles.

A fluid flow sensing apparatus and method for detecting pressure and the presence of bubbles within a fluid tube. The flow sensor comprises a housing configured to receive a portion of the tube and to house the pressure sensor and the ultrasonic transmitter. The pressure sensor is positioned adjacent the tube and is configured to receive a pressure sensor signal, which correlates to a detected pressure differential within the tube. An internal controller transmits a drive signal to the ultrasonic transmitter, which emits ultrasonic waves through a portion of the tube and to the pressure sensor. The pressure sensor receives both the ultrasonic waves and a pressure sensor signal, and subsequently transmits an output signal to the internal controller. In the presence of a pressure differential or a bubble within the tube, the output signal will exhibit a DC shift or a distortion of its signal characteristics, respectively.

The technology of the invention relates to an ultrasonic characterization method for a flowstream to detect impurities that can include placing a first transducer and a second transducer aligned confocally to a flowstream, transmitting, from the first transducer, ultrasonic waveform signals into the flowstream, receiving, by the second transducer, the ultrasonic waveform signals, removing waveform signal reflections using a pitch-catch configuration of the first transducer and the second transducer, detecting waveform signals indicating impurities in the flowstream using induced nucleation of the impurities, detecting waveform signals indicating bubbles in the flowstream using nonlinear dynamic behaviors of the bubbles, and differentiating between the waveform signals of the impurities and the waveform signals of the bubbles using cavitation properties of the impurities and the bubbles.

Methods and apparatus for hydrocarbon monitoring are provided. An example method (e.g., performed by a monitoring system) includes receiving one or more first downhole measurements including a first speed of sound (SoS) measurement of a flowing fluid at a first location, wherein a pressure of the flowing fluid at the first location is greater than a bubble-point pressure of the flowing fluid; receiving one or more second downhole measurements including a second SoS measurement of the flowing fluid at a second location, wherein a pressure of the flowing fluid at the second location is less than the bubble-point pressure of the flowing fluid and wherein the flowing fluid is a 3-phase fluid mixture at the second location; and calculating one or more phase flow rates of the 3-phase fluid mixture, based on the first SoS measurement, the second SoS measurement, and a measurement of a bulk velocity of the flowing fluid.

Sensors, methods, and computer program products for air bubble detection and fluid composition determinations are provided. An example sensor device for use with fluid flow systems includes a force pulse generator coupled with a fluid flow system that emits a force pulse and a force pulse sensor coupled with the fluid flow system. The force pulse sensor receives the force pulse emitted by the force pulse generator and determines the fluid flow system's transient response to the force pulse. Based upon the transient response, the force pulse sensor determines an operating condition of the fluid flow system. The operating condition may be indicative of the presence of an air bubble within the fluid flow system or may be indicative of a composition of a fluid within the fluid flow system. The force pulse sensor may further determine the amplitude and rate of decay of the transient response.

A sensor apparatus is provided for measuring within a region of a conduit for guiding a flow. The apparatus includes a transducer arrangement disposed at least partially around an external surface of a wall of the conduit and having one or more driver elements for exciting in operation a helical acoustic wave propagation within the wall of the conduit for leaking acoustical energy from the helical acoustic wave propagation over an extensive area of the wall of the conduit for stimulating waves in chordal paths within the flow, wherein the waves in the choral paths within the flow reenter the wall of the conduit to propagate further as a guided helical wave. The transducer arrangement includes one or more sensors for receiving a re-entered portion of the acoustic wave propagation along the paths within the flow which interacts with the flow and includes information characterizing properties of the flow.

Methods, systems, and apparatus, including computer programs encoded on a computer storage medium, for monitoring slug flow in subterranean wells. In one aspect, a method includes at a time instant, transmitting an acoustic signal across a cross-section of a pipeline flowing multiphase fluid including gaseous fluid and liquid fluid, wherein a portion of the acoustic signal is carried through the cross-section of the pipeline by the multiphase fluid and determining, at the time instant, a first quantity of the gaseous fluid and a second quantity of the liquid fluid passing the cross-section of the pipeline based, in part, on an energy of the portion of the acoustic signal carried through the cross-section and at least a portion of a total energy of the transmitted acoustic signal.

A fluid analysis system for characterizing a multiphase fluid includes a first set of acoustic probes disposed at a first angular position about a central axis of the fluid analysis system and oriented to direct first sound waves along a first direction that is parallel to the central axis, a second set of acoustic probes disposed at a second angular position about the central axis that is opposite to the first angular position and oriented to direct second sound waves along the first direction, a third set of acoustic probes spanning the central axis and oriented to direct third sound waves along a second direction that is perpendicular to the central axis, and an analysis unit. The analysis unit is configured to determine a location of a fluid interface within the multiphase fluid based on first, second, and third parameters respectively associated with the first, second, and third sounds waves.