Abstract: The dual chamber system has a source chamber and a receiver chamber. The source chamber generates a first steam in a first steam section, and the receiver chamber generates a second steam in a second steam section. The first steam is at a higher temperature than the second steam, and the first steam is at 100% quality. The first steam is injected into a mixing section of the receiver chamber to generate a condensed steam. A sensor or instrument can then be calibrated by the condensed steam. The measurement being taken with the sensor or instrument will have reliability and accuracy. The method includes generating the first steam, generating the second steam, injecting and mixing the first and second steam to form condensed steam at a metering point in the receiver chamber, and calibrating a sensor or instrument at the metering point.

Abstract: A system and method for measuring fluids include a vessel containing at least two fluids with a drain pipe, a seal housing, a tool assembly, and a float assembly. The seal housing fits onto the drain pipe of existing vessels or tanks, and the tool assembly and float assembly are inserted through the seal housing to the vessel to measure the fluids inside the tank. The tool assembly has a shaft section and a flexible section. The flexible section extends into the vessel and through any bend in the drain pipe so that the system is compatible with retrofitting vessels with different drain pipe shapes. The float assembly can be released from the end of the bent drain pipe to float to the fluid boundary between different fluids in the vessel. The float assembly can also be retracted to safe position within the seal housing.

Abstract: A system and method for measuring fluids include a vessel containing at least two fluids with a drain pipe, a seal housing, a tool assembly, and a float assembly. The seal housing fits onto the drain pipe of existing vessels or tanks, and the tool assembly and float assembly are inserted through the seal housing to the vessel to measure the fluids inside the tank. The tool assembly has a shaft section and a flexible section. The flexible section extends into the vessel and through any bend in the drain pipe so that the system is compatible with retrofitting vessels with different drain pipe shapes. The float assembly can be released from the end of the bent drain pipe to float to the fluid boundary between different fluids in the vessel. The float assembly can also be retracted to safe position within the seal housing.

Abstract: The dual chamber system has a source chamber and a receiver chamber. The source chamber generates a first steam in a first steam section, and the receiver chamber generates a second steam in a second steam section. The first steam is at a higher temperature than the second steam, and the first steam is at 100% quality. The first steam is injected into a mixing section of the receiver chamber to generate a condensed steam. A sensor or instrument can then be calibrated by the condensed steam. The measurement being taken with the sensor or instrument will have reliability and accuracy. The method includes generating the first steam, generating the second steam, injecting and mixing the first and second steam to form condensed steam at a metering point in the receiver chamber, and calibrating a sensor or instrument at the metering point.

Abstract: A system for inline phase separation includes a pipe with an inlet and first outlet, a stagnation chamber, and a second outlet at a top of the stagnation chamber. The stagnation chamber is formed by a top panel, a first side panel, a second side panel and a bottom panel. The bottom panel remains flush with the pipe, and the top panel extends radially outward from a flow direction through the pipe. The cross-section formed by the panels is greater than the cross-section of the pipe, reducing flow speed in the stagnation chamber and allowing the fluid mixture to separate into phases from heavier on the bottom to lighter at the top. The second outlet can be used to remove lighter contents at the top, and analysis of the outlets allow for determination of density of the fluid mixture. The heavier contents return to the pipe through the first outlet.

Abstract: An apparatus and method for measuring the concentrations of oil, water and/or hydrates in a multiphase production fluid flow comprises measuring the complex permitivities, both real and imaginary parts, of the flow at at least two frequencies. One dispersive and one non-dispersive frequency are used. In one embodiment at least three frequencies may be selected, one of which is below about 1 MHz while the other two are within the dispersive and non-dispersive ranges for water. In this embodiment water may be distinguished from hydrates and both measured simultaneously.

Abstract: A method and system for on-line multi-component fluid analysis, the system can be configured to measure the absolute viscosity using data acquired by monitoring the flow rate or pump rate and pressure at the discharge for a reference fluid and the flow rate or pump rate and pressure at the discharge for a sample fluid. The system and method can also include comparing the data acquired for the sample fluid and the reference fluid. The system and method can present rheological behavior of the sample fluid as Newtonian viscosity and the shear rate in real time.

Abstract: A method and system for on-line multi-component fluid analysis, the system can be configured to measure the absolute viscosity using data acquired by monitoring the time it takes for a pump to move from one side to the other side and pressure at the discharge for a reference fluid and the time it takes for a pump to move from one side to the other side and pressure at the discharge for a sample fluid. The system and method can also include comparing the data acquired for the sample fluid and the reference fluid. The system and method can present rheological behavior of the sample fluid as Newtonian viscosity and the shear rate in real time.

Abstract: The flow meter system includes flow meters taking measurements based on a set of parameters of a multiphase fluid, each measurement corresponding to respective groups of interrelated unknown variables. These unknown variables are selected from the set of parameters, and the groups of unknown variables are different from each other. A processor uses an iterative process to solve equations of a mathematical model, determined by the equations corresponding to the measurements and groups of unknown variables, so as to estimate an amount of a target unknown variable selected from the set of parameters. The method for estimating a target unknown variable of a multiphase fluid includes installing flow meters in the multiphase fluid; taking measurements based on a set of parameters; determining a mathematical model with equations corresponding to the measurements and groups of interrelated unknown variables; and solving equations with an iterative process.

Abstract: The present disclosure provides a flowmeter including a vibrating element configured to be inserted in a measured fluid; a driver circuit to vibrate the vibrating element in its natural frequency of oscillation; one or more additional technology flow meters configured to measure an additional property of the fluid; a data acquisition circuit configured to measure signals effected by the flow of a multi-phase fluid; and a computer suitable to solve non-linear simultaneous equations. The fluid may include gas, oil and/or water. The fluid may also include solids.

Abstract: A method and apparatus for installing a device in a storage vessel having a drawline while the storage vessel is in operation is disclosed. A cutting tool is run through the drawline from a distal location to a location inside the storage vessel. The cutting tool is used to create an opening in the drawline at the location inside the storage vessel. The device is installed at the created opening.

Abstract: The present disclosure provides a flowmeter including a vibrating element configured to be inserted in a measured fluid; a driver circuit to vibrate the vibrating element in its natural frequency of oscillation; one or more additional technology flow meters configured to measure an additional property of the fluid; a data acquisition circuit configured to measure signals effected by the flow of a multi-phase fluid; and a computer suitable to solve non-linear simultaneous equations. The fluid may include gas, oil and/or water. The fluid may also include solids.

Abstract: A method for correcting measurements of conventional flow meters is provided. Using prior determination of fundamental behavior parameters, flow meter measurements are iteratively calculated to improve their accuracy and eliminate the need for dissimilar momentum meters or moving parts in multiphase flow metering. In some applications, corrections to meter readings are made by using an algorithm having a generic model for the entire system and validating the converged solution against realistic bounds on fluid properties.

Abstract: A method for correcting measurements of conventional flow meters is provided. Using prior determination of fundamental behavior parameters, flow meter measurements are iteratively calculated to improve their accuracy and eliminate the need for dissimilar momentum meters or moving parts in multiphase flow metering. In some applications, corrections to meter readings are made by using an algorithm having a generic model for the entire system and validating the converged solution against realistic bounds on fluid properties.

Abstract: An apparatus and method for measuring the concentrations of oil, water and/or hydrates in a multiphase production fluid flow comprises measuring the complex permitivities, both real and imaginary parts, of the flow at at least two frequencies. One dispersive and one non-dispersive frequency are used. In one embodiment at least three frequencies may be selected, one of which is below about 1 MHz while the other two are within the dispersive and non-dispersive ranges for water. In this embodiment water may be distinguished from hydrates and both measured simultaneously.

Abstract: An apparatus and method for measuring the flow rates of each component of two-phase flow consisting of a gas and a liquid or three-phase flow consisting of water, oil and gas, including a first volumetric flow meter stage, and second and third momentum flow meter stages coupled in a series flow path with the volumetric flow meter stage and in which a velocity ratio between the gas and the liquid in the series flow path is maintained to be one. A processor calculates flow rates of the components of flow by solving volumetric flow and momentum or energy equations defining flow through the first through third stages utilizing a volumetric flow output from the first stage and momentum flux outputs from said second and third stages, and an indicator displays flow of liquid and gas or oil, water and gas components of the flow. To measure three-phase flow, a water-cut meter is provided to determine the amount of water flow, which is then used by the processor to determine the flow of the rest of the liquid.