A device and a method for removing fats, oils and/or grease (“FOGs”) from water comprise a separator, wherein the separator removes the FOGs that separate from the water under gravity, and a filter wherein the filter removes the FOGs remaining in the water after the water has passed through the separator. The filter comprises several layers having different compositions suitable for removing FOGs from water, including a layer comprising granular activated carbon bonded together and wrapped in polyester.

An emulsion separation device including a plurality of inclined plates, a buoyancy device, and an electric field generation system. Also disclosed are systems and methods for the separation of an emulsion into a continuous aqueous phase and a continuous oil phase. The systems may include: a vessel having an emulsion inlet, a continuous aqueous phase outlet, and a continuous oil phase outlet. A separation device may be disposed in the vessel, the separation device including: a plurality of inclined plates and a buoyancy device configured to maintain the plurality of inclined plates between the continuous aqueous phase and the continuous oil phase. An electric field generation system may also be provided and configured to expose the emulsion to an electric field.

The present disclosure relates to methods and devices for the separation of blood components including separation by rapid sedimentation, including in an automated fashion.

A system for separating solids from a fluid mixture includes a vessel including a first chamber to receive a solid-laden fluid mixture, and a second chamber to receive liquids separated from the solid-laden fluid mixture. In certain aspects, at least one eductor is disposed in the first chamber to flow the solid-laden fluid mixture out of the first chamber. In certain aspects, an auger is disposed in the first chamber to move at least solids of the solid-laden fluid mixture out of the first chamber.

A process of dewatering oil sands/coal tailings includes generating nanobubble water, mixing a chemical dispersant into the nanobubble water to form a nanobubble-dispersant mixture, adding tailings to the nanobubble-dispersant mixture to form a nanobubble-dispersant-tailings mixture, and agitating the nanobubble-dispersant-tailings mixture to form an agitated nanobubble-dispersant-tailings mixture having a solid portion and a liquid portion. The solid portion is thereafter separated from the liquid portion. The agitation may be a centrifugal motion or shaking motion to agitate the nanobubble-dispersant-tailings mixture The chemical dispersant may be sodium hydroxide dispersant for asphaltenes and the volume of the tailings added may be substantially equal to the volume of the nanobubble water generated. An oil layer may further be skimmed off the liquid portion a polymer clarifier may also be added to the liquid portion. The process may be applied to achieve accelerated tailings processing for rapid and economic environmental remediation.

A system and method for a gas oil separation plant (GOSP) that receives crude oil from a wellhead. The GOSP has a sand filter associated with a water-oil separator vessel that removes crude oil from oily water in the GOSP. The sand filter is a filter having sand as filter media.

A system for collecting solid particles accumulating at the bottom of a subsea oil/water separation station of an installation for the subsea disposal of water produced during the deepwater subsea production of hydrocarbons, comprises at least one vertical drainage channel intended to open into a lower part of a horizontal body (of the oil/water separation station, a discharge pipe to be positioned horizontally under the horizontal body of the oil/water separation station and into which the drainage channel opens, and a high-pressure slurry ejector having a suction port connected to the discharge pipe via a supply valve.

An apparatus and method for flow management and CO.sub.2-recovery from a CO.sub.2 containing hydrocarbon flow stream, such as a post CO.sub.2-stimulation flowback stream. The apparatus including a flow control zone, a gas separation zone, a pretreatment zone, and a CO.sub.2-capture zone. The CO.sub.2-capture zone is in fluid communication with the pretreatment zone to provide CO.sub.2-capture from a pretreated flowback gas stream and output a captured CO.sub.2-flow stream. The CO.sub.2-capture zone includes a first CO.sub.2-enricher and at least one additional CO.sub.2 enricher disposed downstream of the first CO.sub.2 enricher and in cascading relationship to provide a CO.sub.2-rich permeate stream, the CO.sub.2-capture zone further including at least one condenser to condense the enriched CO.sub.2-stream and output the captured CO.sub.2-flow stream.

A system for separating a multiphase well stream into a solids fraction, a water fraction, an oil fraction and a gas fraction includes a transportable support surface; a solids separator which is mounted on the support surface and is configured to receive the multiphase well stream and separate the well stream into a first heavy fraction primarily comprising the solids fraction and a first light fraction primarily comprising the gas, oil and water fractions; and a multiphase fluid separator which is mounted on the support surface and includes a first separator section and a second separator section which is positioned vertically below and connected directly to the first separator section. The first separator section is configured to receive the first light fraction and separate the first light fraction into a second light fraction primarily comprising the gas fraction and a second heavy fraction primarily comprising the oil and water fractions. The second separator section is configured to receive the second heavy fraction and separate the second heavy fraction into a third light fraction primarily comprising the oil fraction and a third heavy fraction primarily comprising the oil fraction.

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 gas separation followed by pressure reduction and then a second gas separation. Indirect follows the second gas separation and then three-phase separation.