Agar Corporation, Inc.

Agar Technologies Process & Environmental Limited Control Limited

Joram Agar

David Farchy

Hector Alfredo Viale-Rigo Capuzzo

David Farchi

Efim Metsner

Vikram Siddavaram

Jacob Inbar

Itzack Tavori

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.

Dual chamber system and method to generate steam for calibration

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.

System and method for measuring fluids

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.

Method and apparatus for detecting water in a fluid media

Bypass pipe joint

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.

Method and system for analysis of rheological properties and composition of multi-component fluids

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.

Multi-phase fluid measurement apparatus and method

Antenna detection probe for a storage tank

Drill

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.

Method and apparatus for measuring multi-streams and multi-phase flow

A high void fraction multi-phase fluid flow meter and method, wherein a first fluid flow path including a multi-phase flow measuring device disposed in series with a liquid flow restrictor is provided in parallel with a second fluid flow path including a gas flow measuring device. The presence of liquid flow in the flow meter is detected. When liquid flow is detected, a valve in the second fluid flow path operates to cut off fluid flow through the second fluid flow path. Otherwise the valve in the second fluid flow path operates to divert gas flow through the second fluid flow path. Alternatively, a negative pressure differential is produced across the second fluid flow path when liquid flow is present, by passing the incoming liquid flow through a jet pump nozzle, to prevent liquid flow into the second fluid flow path. A check valve is then disposed in the second fluid flow path to prevent backflow from the output of the multi-flow measuring device into the second fluid flow path. A computer outputs an indication of the liquid flow, typically oil flow and water flow, through the multi-phase flow meter, and the combined total amount of gas flow through the two flow meters.

High void fraction multi-phase fluid flow meter

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. The second and third momentum flow meter stages can be implemented by two separate momentum flow meters or by a single momentum flow meter, such as a venturi flow meter having a venturi nozzle including pressure taps for obtaining at least two differential pressure measurements. In the event that the density of the liquid component is known, a single momentum flow meter stage is sufficient.

Apparatus and method for measuring two- or three- phase fluid flow

Disclosed is a method and apparatus for measuring the percentages of oil and water present in an oil/water mixture. By measuring the energy absorption properties of the oil/water mixture, the percentages of oil and water present in the oil/water mixture can be determined regardless of whether the oil or the water is in the continuous phase and regardless of what the relative proportions of water and oil are. Measuring the energy absorption properties of the oil/water mixture yields a current output which can be plotted on one of two distinct, empirically or theoretically derived data curves. One of the data curves represents oil being in the continuous phase and the other data curve represents water being in the continuous phase. A comparator is used to determine whether the oil or the water is in the continuous phase to thereby select the proper data curve on which the energy absorption is plotted. Each of the curves has the energy absorption properties of the media plotted against the percentage of water and plotting the amount of energy absorbed on the proper curve yields the percentage of water present.

Apparatus for determining the percentage of a fluid in a mixture of

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. The second and third momentum flow meter stages can be implemented by two separate momentum flow meters or by a single momentum flow meter, such as a venturi flow meter having a venturi nozzle including pressure taps for obtaining at least two differential pressure measurements. In the event that the density of the liquid component is known, a single momentum flow meter stage is sufficient.

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Grand Cayman, Cayman Islands

Joram Agar