Abstract: Method and apparatus enable direct measurement of at least one flow velocity for one or more phases within a multiphase fluid mixture flowing in a conduit. Some embodiments provide determination of actual individual phase flow rates for three phases (e.g., oil, water and gas) that are distinct from one another within the fluid mixture. A multiphase flowmeter according to embodiments of the invention includes at least two optical sensors spatially distributed along a length of the conduit and designed to detect light interactions with the fluid mixture unique to the phases such that detected time-varying signals can be processed via cross-correlation or an array processing algorithm to provide desired individual phase flow velocity for oil, water and/or gas phases. This flow velocity can be applied to phase fraction measurements, which can be obtained utilizing the same flowmeter or another separate device, to calculate the flow rates for the phases.

Abstract: Methods and apparatus enable monitoring a hydrocarbon well for water within a flow stream of the well. A water detector includes a light source for emitting into a flow stream infrared light that includes a water absorbent wavelength band. A detector detects attenuation of the water absorbent wavelength band upon the infrared radiation passing through at least a portion of the flow stream. The water detector outputs a presence of water and/or a phase fraction or quantification of water as determined based on the attenuation. Detecting attenuation of a substantially transmissive wavelength band with respect to water simultaneously with detection of the attenuation of the water absorbent wavelength band can enable correction for non-wavelength dependent attenuation.

Abstract: Methods and apparatus enable monitoring a hydrocarbon well for water within a flow stream of the well. A water detector includes a light source for emitting into a flow stream infrared light that includes a water absorbent wavelength band. A detector detects attenuation of the water absorbent wavelength band upon the infrared radiation passing through at least a portion of the flow stream. The water detector outputs a presence of water and/or a phase fraction or quantification of water as determined based on the attenuation. Detecting attenuation of a substantially transmissive wavelength band with respect to water simultaneously with detection of the attenuation of the water absorbent wavelength band can enable correction for non-wavelength dependent attenuation.

Abstract: Methods and apparatus enable sensing flow of a fluid inside a conduit with an array of pressure or strain sensors. Inputs for a curve fit routine include power correlation values at one of multiple trial velocities or speeds of sound and several steps on either side utilizing data obtained from the sensors. The velocity at which a curve fit routine returns a max curvature result corresponds to an estimate value that facilitates identification of a speed of sound in the fluid and/or a velocity of the flow. Furthermore, a directional quality compensation factor may apply to outputs from the curve fit routine to additionally aid in determining the velocity of the flow.

Abstract: Methods and apparatus enable monitoring a hydrocarbon well for water within a flow stream of the well. A water detector includes a light source for emitting into a flow stream infrared light that includes a water absorbent wavelength band. A detector detects attenuation of the water absorbent wavelength band upon the infrared radiation passing through at least a portion of the flow stream. The water detector outputs a presence of water and/or a phase fraction or quantification of water as determined based on the attenuation. Detecting attenuation of a substantially transmissive wavelength band with respect to water simultaneously with detection of the attenuation of the water absorbent wavelength band can enable correction for non-wavelength dependent attenuation.

Abstract: Methods and apparatus for sensing fluid flow within a conduit using a Distributed Acoustic Sensing (DAS) system. The DAS system may lower production costs and may offer some technical advantages over fiber Bragg grating (FBG)-based flowmeters such as auxiliary measurement of strain from the wellhead down to the flowmeter. The DAS system may also simplify multiplexing multiple flowmeters on a single fiber.

Abstract: Methods and apparatus enable monitoring a hydrocarbon well for water within a flow stream of the well. A water detector includes a light source for emitting into a flow stream infrared light that includes a water absorbent wavelength band. A detector detects attenuation of the water absorbent wavelength band upon the infrared radiation passing through at least a portion of the flow stream. The water detector outputs a presence of water and/or a phase fraction or quantification of water as determined based on the attenuation. Detecting attenuation of a substantially transmissive wavelength band with respect to water simultaneously with detection of the attenuation of the water absorbent wavelength band can enable correction for non-wavelength dependent attenuation.

Abstract: Methods and apparatus enable monitoring a hydrocarbon well for water within a flow stream of the well. A water detector includes a light source for emitting into a flow stream infrared light that includes a water absorbent wavelength band. A detector detects attenuation of the water absorbent wavelength band upon the infrared radiation passing through at least a portion of the flow stream. The water detector outputs a presence of water and/or a phase fraction or quantification of water as determined based on the attenuation. Detecting attenuation of a substantially transmissive wavelength band with respect to water simultaneously with detection of the attenuation of the water absorbent wavelength band can enable correction for non-wavelength dependent attenuation.

Abstract: Methods and apparatus enable sensing flow of a fluid inside a conduit with an array of pressure or strain sensors. Inputs for a curve fit routine include power correlation values at one of multiple trial velocities or speeds of sound and several steps on either side utilizing data obtained from the sensors. The velocity at which a curve fit routine returns a max curvature result corresponds to an estimate value that facilitates identification of a speed of sound in the fluid and/or a velocity of the flow. Furthermore, a directional quality compensation factor may apply to outputs from the curve fit routine to additionally aid in determining the velocity of the flow.

Abstract: Method and apparatus enable direct measurement of at least one flow velocity for one or more phases within a multiphase fluid mixture flowing in a conduit. Some embodiments provide determination of actual individual phase flow rates for three phases (e.g., oil, water and gas) that are distinct from one another within the fluid mixture. A multiphase flowmeter according to embodiments of the invention includes at least two optical sensors spatially distributed along a length of the conduit and designed to detect light interactions with the fluid mixture unique to the phases such that detected time-varying signals can be processed via cross-correlation or an array processing algorithm to provide desired individual phase flow velocity for oil, water and/or gas phases. This flow velocity can be applied to phase fraction measurements, which can be obtained utilizing the same flowmeter or another separate device, to calculate the flow rates for the phases.

Abstract: Methods and apparatus enable monitoring a hydrocarbon well for water within a flow stream of the well. A water detector includes a light source for emitting into a flow stream infrared light that includes a water absorbent wavelength band. A detector detects attenuation of the water absorbent wavelength band upon the infrared radiation passing through at least a portion of the flow stream. The water detector outputs a presence of water and/or a phase fraction or quantification of water as determined based on the attenuation. Detecting attenuation of a substantially transmissive wavelength band with respect to water simultaneously with detection of the attenuation of the water absorbent wavelength band can enable correction for non-wavelength dependent attenuation.

Abstract: Methods and apparatus determine phase fractions for phases within a fluid mixture flow under a wide range of flow conditions including wet-gas flow. Appropriate flow algorithms can utilize this phase fraction information with a total flow rate of the mixture to find individual flow rates for phases, such as oil, water, and gas or gas and liquid, which can represent a combination of oil and water phases. For some embodiments, a multiphase flowmeter includes an array of spatially distributed pressure sensors configured to determine a velocity of the mixture flow and hence the total flow rate, which is applied with information from a differential pressure meter to calculate the bulk density of the fluid mixture. Further, additional speed of sound information or a water-in-liquid ratio as may be determined by spectral analysis can enable differentiation between the oil and water phases.

Abstract: Methods and apparatus enable measuring flow of a fluid within a conduit. For example, flowmeters may measure the velocity of production fluid flowing through production pipe of an oil/gas well. The flowmeters rely on detection of pressure variations generated as a result of a backward-facing step as a basis for flow measurement calculations. Pressure sensing occurs away from the step in a direction of the flow of the fluid in an enhanced turbulence region of the flowmeter where the inner diameter remains enlarged as a result of the step.

Abstract: Method and apparatus enable direct measurement of at least one flow velocity for one or more phases within a multiphase fluid mixture flowing in a conduit. Some embodiments provide determination of actual individual phase flow rates for three phases (e.g., oil, water and gas) that are distinct from one another within the fluid mixture. A multiphase flowmeter according to embodiments of the invention includes at least two optical sensors spatially distributed along a length of the conduit and designed to detect light interactions with the fluid mixture unique to the phases such that detected time-varying signals can be processed via cross-correlation or an array processing algorithm to provide desired individual phase flow velocity for oil, water and/or gas phases. This flow velocity can be applied to phase fraction measurements, which can be obtained utilizing the same flowmeter or another separate device, to calculate the flow rates for the phases.

Abstract: Methods and apparatus enable sensing flow of a fluid inside a conduit with an array of pressure or strain sensors. Inputs for a curve fit routine include power correlation values at one of multiple trial velocities or speeds of sound and several steps on either side utilizing data obtained from the sensors. The velocity at which a curve fit routine returns a max curvature result corresponds to an estimate value that facilitates identification of a speed of sound in the fluid and/or a velocity of the flow. Furthermore, a directional quality compensation factor may apply to outputs from the curve fit routine to additionally aid in determining the velocity of the flow.

Abstract: Methods and apparatus enable monitoring a hydrocarbon well for water within a flow stream of the well. A water detector includes a light source for emitting into a flow stream infrared light that includes a water absorbent wavelength band. A detector detects attenuation of the water absorbent wavelength band upon the infrared radiation passing through at least a portion of the flow stream. The water detector outputs a presence of water and/or a phase fraction or quantification of water as determined based on the attenuation. Detecting attenuation of a substantially transmissive wavelength band with respect to water simultaneously with detection of the attenuation of the water absorbent wavelength band can enable correction for non-wavelength dependent attenuation.

Abstract: Methods and apparatus determine phase fractions for phases within a fluid mixture flow under a wide range of flow conditions including wet-gas flow. Appropriate flow algorithms can utilize this phase fraction information with a total flow rate of the mixture to find individual flow rates for phases, such as oil, water, and gas or gas and liquid, which can represent a combination of oil and water phases. For some embodiments, a multiphase flowmeter includes an array of spatially distributed pressure sensors configured to determine a velocity of the mixture flow and hence the total flow rate, which is applied with information from a differential pressure meter to calculate the bulk density of the fluid mixture. Further, additional speed of sound information or a water-in-liquid ratio as may be determined by spectral analysis can enable differentiation between the oil and water phases.

Abstract: Methods and apparatus determine phase fractions for phases within a fluid mixture flow under a wide range of flow conditions including wet-gas flow. Appropriate flow algorithms can utilize this phase fraction information with a total flow rate of the mixture to find individual flow rates for phases, such as oil, water, and gas or gas and liquid, which can represent a combination of oil and water phases. For some embodiments, a multiphase flowmeter includes an array of spatially distributed pressure sensors configured to determine a velocity of the mixture flow and hence the total flow rate, which is applied with information from a differential pressure meter to calculate the bulk density of the fluid mixture. Further, additional speed of sound information or a water-in-liquid ratio as may be determined by spectral analysis can enable differentiation between the oil and water phases.

Abstract: Methods and apparatus enable measuring flow of a fluid within a conduit. For example, flowmeters may measure the velocity of production fluid flowing through production pipe of an oil/gas well. The flowmeters rely on detection of pressure variations generated as a result of a backward-facing step as a basis for flow measurement calculations. Pressure sensing occurs away from the step in a direction of the flow of the fluid in an enhanced turbulence region of the flowmeter where the inner diameter remains enlarged as a result of the step.

Abstract: Methods and apparatus enable measuring flow of a fluid within a conduit. For example, flowmeters may measure the velocity of production fluid flowing through production pipe of an oil/gas well. The flowmeters rely on detection of pressure variations generated as a result of a backward-facing step as a basis for flow measurement calculations. Pressure sensing occurs away from the step in a direction of the flow of the fluid in an enhanced turbulence region of the flowmeter where the inner diameter remains enlarged as a result of the step.