Embodiments of the disclosure include processes using microwave heating to promote the separation of components of crude oil. In some embodiments, microwave-heated water may be used to heat the interphase between the gas phase and the oil phase of a crude oil stream to promote the separation of sulfur (for example, H.sub.2S) and light end components of the crude oil stream. In some embodiments, microwave-heated water may be used to heat the interphase between the oil phase and the water phase of a crude oil stream to promote the separation of water, salt, or both of the crude oil stream. Systems having a microwave unit to provide microwave-heated water to crude oil stream are also provided.

A method for separating a lubrication oil from a waste fluid includes separating water from the waste fluid by heating the waste fluid while sealed in a first vacuum chamber to a first temperature and first pressure. Fuel oil is separated from a fluid received from the first vacuum chamber by heating the fluid while sealed in a second vacuum chamber to a second temperature that is higher than the first temperature and at a second pressure. Finally, the lubrication oil is separated from a fluid received from the second vacuum chamber by heating the fluid received from the second vacuum chamber while sealed in a third vacuum chamber to a third temperature that is higher than the second temperature and at a third pressure.

A method for separating a lubrication oil from a waste fluid includes separating water from the waste fluid by heating the waste fluid while sealed in a first vacuum chamber to a first temperature and first pressure. Fuel oil is separated from a fluid received from the first vacuum chamber by heating the fluid while sealed in a second vacuum chamber to a second temperature that is higher than the first temperature and at a second pressure. Finally, the lubrication oil is separated from a fluid received from the second vacuum chamber by heating the fluid received from the second vacuum chamber while sealed in a third vacuum chamber to a third temperature that is higher than the second temperature and at a third pressure.

Provided is a method for treating a liquid, the method including: receive a liquid; passing the liquid through a generator to cut and shear the liquid and releasing the resultant liquid for use. Also provided is a liquid treatment system including: a source of liquid; a generator in fluid communication with the liquid source which cuts and shears the liquid; a pump which produces liquid flow through the system; and an outlet through which the treated liquid flows.

Systems and methods for separation of hydrocarbon containing fluids are provided. More particularly, the disclosure is relevant to separating fluids having a gas phase, a hydrocarbon liquid phase, and an aqueous liquid phase using indirect heating. In general, the system uses a first three-phase gas separation followed by indirect heating and then a second three-phase gas separation. Pressure reduction of the hydrocarbon containing fluid occurs either before or after the indirect heating.

Systems and methods for separation of hydrocarbon containing fluids are provided. More particularly, the disclosure is relevant to separating fluids having a gas phase, a hydrocarbon liquid phase, and an aqueous liquid phase using indirect heating. In general, the system uses a first three-phase gas separation followed by indirect heating and then a second three-phase gas separation. Pressure reduction of the hydrocarbon containing fluid occurs either before or after the indirect heating.

A method for pre-treating bitumen froth for mixing with solvent for froth treatment includes heating the froth to a froth-solvent mixing temperature below the solvent flash temperature and suitably high to provide reduced bitumen viscosity sufficiently low for complete mixing of the solvent and the froth prior to introduction into a separation apparatus. A method of improving energy use in froth treatment includes reducing heat provided to the solvent, increasing heat provided to the froth prior to adding the solvent to reduce bitumen viscosity and adding the temperature-reduced solvent to the heated froth. A froth treatment separation process includes trim heating first and second solvent streams to adjust the first and second stage separation temperatures.

A method for pre-treating bitumen froth for mixing with solvent for froth treatment includes heating the froth to a froth-solvent mixing temperature below the solvent flash temperature and suitably high to provide reduced bitumen viscosity sufficiently low for complete mixing of the solvent and the froth prior to introduction into a separation apparatus. A method of improving energy use in froth treatment includes reducing heat provided to the solvent, increasing heat provided to the froth prior to adding the solvent to reduce bitumen viscosity and adding the temperature-reduced solvent to the heated froth. A froth treatment separation process includes trim heating first and second solvent streams to adjust the first and second stage separation temperatures.

Certain implementations of the subject matter can be implemented as a method of screening demulsifiers for live crude oil-water emulsions. A live emulsion of a hydrocarbon sample and a water sample is flowed through a capillary viscometer. The live emulsion includes dissolved gases retrieved from a hydrocarbon-carrying reservoir. While flowing the live emulsion through the capillary viscometer, a demulsifier sample is flowed through the capillary viscometer. The demulsifier sample causes breakdown of the live emulsion. Using the capillary viscometer, change in a viscosity of the live emulsion over time resulting from the breakdown of the live emulsion due to the demulsifier sample is measured. Multiple images of the breakdown of the live emulsion over time are captured. A strength of the live emulsion is classified based, in part, on the change in the viscosity of the live emulsion over time and on the plurality of images.

Volatile organic compounds are removed from crude oil by adding heat upstream of a vapor recovery tower. The heat input may either be sufficient to break the emulsion as in a here treater or extra heat may be added to stabilize the crude oil. Produced gas may be recovered as NGL in one or more cooling stages. Produced gas, whether partially recovered or not, may be used as fuel for said heater treater, other combustion device or compressed into a pipeline.