Atlantic Richfield Company

Frank H Hsu

Lloyd A Baillie

Y Sam Yang

James A Dech

The concentration of a gas such as hydrogen sulfide in a liquid such as crude oil or other hydrocarbon liquid is measured by conducting a flowstream of the liquid through a jet or eductor type pump for mixing a recirculating vapor stream with the liquid, separating the liquid and the vapor stream in a separator to provide equilibrium conditions between the vapor and the liquid and withdrawing the vapor flowstream for recirculation and remixing with the liquid flowstream while measuring the concentration of the gas in the vapor flowstream. A known flow rate of the gas is added to the combined liquid and recirculating vapor flowstream and the incremental change in concentration of the gas in the recirculating vapor flowstream is measured to determine the concentration of the gas in the liquid flowstream initially. The jet type pump utilizes the liquid flowstream and is in communication with a separator chamber, preferably at atmospheric pressure, for separating liquid from the equilibrium vapor flowstream and recirulating the vapor flowstream through a nonconsumptive concentration detector for the gas. The quantity of gas added to the system is conducted to the pump for mixing with the liquid flowstream by way of a bubble counter type flow measuring device.

Method and system for determining the concentration of a gas in a liquid

Multiple wellbores may be extended from a common, generally vertical wellbore and completed for conduction of fluids between said common wellbore and each of said wells by drilling the common wellbore, inserting a seal bore into the common wellbore below the junction of a deviated well with said common wellbore, inserting a whipstock and then drilling the deviated well. The whipstock is removed and a guide member is inserted into the common wellbore and secured to the anchor member. A dual packer is inserted in the common wellbore above the junction of the deviated well and is connected to the guide member to provide a slow passage into the wellbore located below the junction. A second tubing guide connector member is inserted into the common wellbore with a tubing string extending downwardly therefrom. The tubing string is passed through the dual packer and into the deviated well and the second guide member is latched to the dual packer to provide dual flow paths from each of the separate wellbores into the common wellbore or to the surface. The second guide member includes separate configurations for the respective flow passages to permit insertion of tubing strings and separate guide heads into selected wellbores for various well operations.

System and method for providing multiple wells from a single wellbore

The total mass flowrate of a multiphase fluid flowstream such as a water, oil and gas mixture being produced from subterranean wells is determined by passing the flowstream through an apparatus which forces a substantial change in direction of the fluid flowstream and wherein a pressure differential is measured across flow paths of known cross-sectional flow area. The total mass flow is determined from the cross-sectional flow areas, the measured total density of the flowstream and the differential pressure. A sample of the flowstream is withdrawn from the flow path, gas is separated from liquid and the liquid fraction of water is measured by passing the liquid mixture through a device which measures the dielectric constant of the liquid mixture using microwave radiation transmissivity or differential pressure between columns of the liquid mixture and a column of water of equal height is compared. Total density of the flowstream may be obtained by measuring differential pressures across changes in elevation of the flowstream.

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Plano, TX, United States of America

Frank H Hsu