Abstract: An automatic well test system (100) utilizes a two phase vortex separator 104 connected to a pair of Coriolis flowmeters (154, 166) to measure volumetric flow rates in three phase flow. Measurements are performed according to a process (P200) including an iterative convergence technique. Measurements are enhanced by the use of real time density and water-cut measurements from a water-cut meter (172) and a water density meter.

Abstract: A measurement device is disclosed for measuring the conductivity distribution in liquids or multiple phase media flowing in any direction. A grid sensor has electrodes shaped as parallel electroconductive grid bars or wires located in two or three planes and electrically insulated from each other and from their mounting. The electrodes in the individual planes are mutually offset by preferably 90°. One of the planes, the middle plane when three planes are used, forms an exciter plane connected with a pulse generator, whereas the other planes(s) form receiver plane(s) coupled to processing electronics. in the disclosed signal generation process, the electrodes of the exciter plane are successively driven with a symmetrical bipolar rectangular pulse, and all non-driven electrodes are connected with low impedance to the zero potential.

Abstract: An improved apparatus and improved method for determining the characteristics of a multi-phase fluid along a well hole having a predefined geometric profile are presented. Various state properties of the fluid, including the temperature, pressure and specific gravity are taken at the wellhead and used as starting values for calculating estimated state properties at various segments along the well hole. Once the state properties are calculated, an estimated mass flow and velocity rate for the fluid and its constituents can be calculated at specific points along the well hole by implementing computer-based programs and algorithms to extrapolate and/or iterate the known parameters and measurements in a progressively incremented manner from the locations of such given starting points at an initial segment up to other further points corresponding to a set of further sequential segments used in the geometric profile mathematical model.

Abstract: An apparatus to normalize a flow rate of a fluid in a main flow channel is provided. The apparatus uses a moveable member, such as a flexible membrane disposed for reciprocating displacement, to produce a constant dither flow of the fluid that is independent of fluid composition. This dither flow generates a signal output from a normalizing flow sensor that both represents a characteristic property of the fluid and a flow rate calibration factor. A similar apparatus to determine the characteristic property or flow rate calibration factor is also provided. The devices disclosed may be used in numerous industrial, process, and medical flow system applications for normalization of flow sensors and to derive other properties of a fluid.

Abstract: A narrow band infrared water fraction meter detects a full water cut range of a liquid hydrocarbon flow stream and a flow stream of a gas well. The water fraction meter includes a light source probe for irradiating the flow stream with a narrow band of infrared light and a light detector probe for sensing attenuation of infrared light passed through the flow stream. For a narrow band of infrared light of a predetermined wavelength, there is a substantial difference in the absorption of infrared radiation between the gas and water content of a flow stream of a gas well. At such a wavelength, the narrow band of infrared light is substantially transmitted through gas content and liquid hydrocarbon content of the flow stream and substantially absorbed by water content of the flow stream. The water fraction meter thus differentiates water by treating liquid hydrocarbon like gas.

Abstract: A multiphase flowmeter (30) is mounted on the piping via which a multiphase fluid flows out from a hydrocarbon well, so as to measure the flow rates of the various phases of the fluid. A back-pressure valve (34) is placed in the piping downstream from the flowmeter (30) so as to enable the pressure in the flowmeter to be adjusted, whereby the flow conditions of the fluid in the flowmeter (30) can be made compatible with the measurement domain of the flowmeter.

Abstract: A method and apparatus for real time gas analysis involving determining individual concentrations of fluid constituents in a mixture of known constituents by measuring properties of the mixture and solving a set of equations, which relate the individual gas concentrations to the measured properties of the mixture, for the unknown individual gas concentrations. The individual concentrations of four gasses in a mixture are determined by: passing the mixture through a flowmeter, a capillary, an orifice, and a sonic oscillator; transducing temperature, pressure and acoustic frequency measurements taken from the sensors; determining the density, viscosity, and the specific heat of the mixture; forming three equations which respectively relate these three properties to individual gas concentrations; and solving the three equations and the constitutive equation which requires that the sum of the concentrations equal unity, for the four unknown individual gas concentrations.

Abstract: A system for evaluating multiphase fluid flow in a wellbore. Two distinct AC signals are injected into a fluid. One AC signal originates from a transmitter electrode in ohmic contact with the fluid, and the other AC signal originates from a transmitter electrode capacitively coupled to the fluid. The geometric factors between the electrode pairs are selected to distinguish between different constituents within the wellbore fluids. The output electrical impedance of the ohmic transmitter is low so that the AC signal from the capacitive transmitter is shunted to signal ground in electrically conductive fluids. A single detector can measure the fraction of electrically conductive water covering the detector electrode as well as the dielectric constant of an oil and gas mixture. Arrays of such detector electrodes can measure the holdups and velocities of the constituent fluids in a flowing multiphase fluid.

Abstract: The invention is a device for separating a mixture of fluids (conducting fluid, non-conducting fluid, gas), suited to measure the volumes of the various fluids by means of a capacitive measuring process.

Abstract: The invention relates to a flow section for measurements concerning oil well effluent, the section comprising a pipe in parallel with a pipe connected to the well head. The flow section includes elements of material having low attenuation for gamma rays fixed in recesses formed in the wall of the pipe on its inside, and protection members disposed in housings connecting said recesses respectively to the outside, said housings being suitable for receiving gamma ray attenuation measuring means after the protection members have been removed.

Abstract: The present invention includes a method for multiphase metering of multiphase flow. the method begins with reducing gas volume to about 20% or less, then pumping the flow stream through two meters, a cut meter and a mass flow meter, arranged in series. Computations may be made on the flow stream to determine net oil rate, water cut, and gas fraction in the flow stream.

Abstract: A method and an apparatus for determining at least one property of a multiphase fluid. The method includes the steps of directing the multiphase fluid through a first flow passage, monitoring the multiphase fluid as it passes through the first flow passage to obtain a first signal representing a first flow characteristic of the multiphase fluid as a function of time, directing the multiphase fluid through a second flow passage, monitoring the multiphase fluid as it passes through the second flow passage to obtain a second signal representing a second flow characteristic of the multiphase fluid as a function of time, and then determining the property of the multiphase fluid by comparing the first signal and the second signal with a set of calibration maps. The second flow passage has a geometry different from the first flow passage which relates either to the cross section of the two flow passages or to the direction in which the multiphase fluid passes through the flow passages relative to gravity.

Abstract: A mixing assembly which transfers a number of nutritional fluids from individual source containers into a collection container while noninvasively sensing the type of fluid being transferred is provided. The mixing assembly utilizes a transfer set to establish fluid communication between the source containers and the collection container. A sensing assembly is configured to noninvasively sense a number of the types of fluid flowing through the transfer set to help to prevent improper mixing. For other fluids for which the sensing assembly alone may not be able to distinguish with the desired accuracy, the mixing device utilizes a method to approximate the flow rate of that fluid with the flow rate also providing an indication of that type of fluid. By combining the output of the sensing assembly with the flow rate determination, additional fluids can be identified.

Abstract: A disposable sensor is disclosed for non-invasively detecting and characterizing a container's contents. By generating microwave frequency signals, electromagnetic fields are produced by a sensor and penetrate a container. The EM fields are analyzed in regards to how they are perturbed by the container contents. Analysis of the perturbed EM fields enables determination of content level, content purity, content density, content temperature, container pressure, and content conductivity.

Abstract: To study the properties of a multiphase fluid under pressure flowing along a duct, such as the petroleum stream produced by an oil well, a fraction of the fluid is taken from a substantially vertical first length of the duct within which the fluid is agitated and flows upwards, and this fraction is transferred into a separator receptacle with the top of said receptacle being connected to a second length of the duct located downstream from the first length and at a slightly lower pressure relative thereto. Thereafter, the volume ratio of the liquid phases can be determined, e.g. by pouring them into the separator receptacle and measuring the levels thereof, or by causing the liquid emulsion to flow through an appropriate sensor device and where the emulsion density can be determined by weighing the separator receptacle before and after such a liquid phase/emulsion pouring step.