A vortex meter for measuring a flow rate of a fluid has a flowtube and a bluff body positioned in the flowtube for shedding vortices in the fluid when the fluid flows through the flowtube. The vortex meter has a sensor positioned to detect the vortices. The bluff body has a forward-facing surface and an abrasion-resistant cladding covering the forward facing surface. The bluff body suitably also has a projection extending downstream from the forward-facing surface. The bluff body suitably has an abrasion-resistant cladding covering at least a portion of the projection. In one embodiment, the entire bluff body is completely covered by the abrasion-resistant cladding. The inner surface of a segment of the flowtube can also have abrasion-resistant characteristics.

A flow meter includes a meter body and a pressure sensor. The meter body has a liquid impact surface, a sensing surface opposite to the liquid impact surface, and a mounting hole extending from the sensing surface toward the liquid impact surface. The mounting hole is a blind hole. The pressure sensor is mounted in the mounting hole, and has a resistance value that can be measured and that can be changed correspondingly with a change in liquid pressure caused by a change in flow rate. A device for producing an active hydroxyl free radical solution is also disclosed.

A passive acoustic gas wave generator of a gas pipe and a tube-in-tube construction thereof are presented. The passive acoustic gas wave generator is a component of a larger acoustic gas flow meter assembly. The tube-in-tube construction eases installation in application and use, and particularly in applications exhibiting harsh and extreme conditions such as in nuclear power reactors. In an implementation, the passive acoustic gas wave generator has a tube body and a support structure. The tube body has a tube gas flow passage and a multitude of corrugations residing at an inner surface thereof. The corrugations induce a phenomenon known-as vortex shedding within a gas flow stream passing through the tube gas flow passage. The support structure centrally locates the tube gas flow passage relative to a pipe gas flow passage of the gas pipe.

Ultrasound tomography arrays and vortex shedding devices are provided which measure average flow velocity through Doppler shift of the fluid as well as cross sectional multiphase fluid composition in pipe or tubing conduits. Multiple tomographic arrays in conjunction with correlation of sensed flow patterns in time provided determination of flow velocity as well as cross sectional multiphase fluid composition. The tomographic arrays may be arranged in a skewed or slanted plane to measure velocity fluctuations downstream of a vortex shedding device where the period and amplitude of the fluctuations is correlated with the mass flow of the fluid. Additionally, the tomographic arrays provide the relative composition of the multiphase fluid. The multiple arrays together with correlation to determine velocity fluctuations downstream of a vortex shedding device where the period and amplitude of the fluctuations is correlated with the mass flow of the fluid. Additionally the tomographic arrays output the relative composition of the multiphase fluid.

A process variable transmitter is configured as a flowmeter for measuring flow of a process fluid through a conduit. The transmitter includes a pitot tube extending into the conduit which creates a differential pressure in the process fluid due to flow of the process fluid. An upstream process variable sensor is mounted on the pitot tube and coupled to the flow of process fluid to sense an upstream process variable of the process fluid. A downstream process variable sensor is mounted on the pitot tube downstream of the upstream process variable sensor and coupled to the flow of process fluid to sense a downstream process variable of the process fluid. Measurement circuitry determines the flow of the process fluid based upon the upstream process variable and the downstream process variable.

A vortex flowmeter has first and second process connections with a meter inlet and outlet, respectively, therein. The first and second process connections are configured to connect, respectively, to upstream and downstream segments of a fluid pipeline. A fluid conveyance system conveys fluid from the inlet to the outlet and divides the fluid into separate fluid streams that flow through separate passages. Each of the passages has its own vortex metering unit configured to generate and detect vortices in the respective fluid stream. A processing system is configured to calculate a sum of the flow rates through all of the fluid streams.

A vortex flowmeter may utilize a ring-shaped bluff body as the vortex generator or shedder. The ring shape and size of the vortex ring generator may be optimized to produce linear and stable toroidal vortex outputs that may outperform the conventional shedder bar. In comparison to the conventional vortex shedder bar, the ring may have a slimmer configuration and a higher K-factor, and hence, a higher resolution.

A vortex flow meter comprises a measuring tube; a bluff body arranged in the measuring tube; a sensor device, having a paddle, a sensor main body and a piezo element, and an electronic operating circuit. The electronic operating circuit has a measuring circuit comprising an operational amplifier and a capacitor. The first capacitor forms a feedback between the output and the measurement input, wherein the reference input can be supplied with a first reference voltage. The measurement circuit has a first switch, wherein the electronic operating circuit is designed to connect the piezo element via the first switch to the measurement input of the operational amplifier and to charge it with a first charging voltage by means of a second switch position. The electronic operating circuit derives an information relating to a state of the piezo element from a discharge process of the piezo element.

A multiphase vortex flowmeter system determines the gas-to-liquid ratio (GLR) and flow rates from a well producing multiphase gas, oil and water by detecting the frequency and amplitude of vortices shed in a vortex flowmeter. In particular, the phase of the flow can be identified by detecting the change in the frequency of the vortices with respect to time, and the amplitude of the vortices. Based on the phase, the flow rates of liquid and gas can be calculated. For multiphase flow, the GLR can be determined based on changes in the magnitude of the velocity oscillations measured by the vortex flowmeter, if the changes exceed a predetermined threshold. If not, the GLR can be determined based on the average frequency and average amplitude of the vortices.