Abstract: A system for stabilizing a hydrocarbon feedstock includes a High Pressure Separation (HPS) unit in fluid communication with a feedstock inlet. The HPS unit includes an oil outlet. A Heated Low Pressure (LP) Separator unit is downstream from the oil outlet of the HPS unit. The Heated LP Separator unit includes an oil outlet.

Abstract: A method for recovering hydrocarbons with two multistage columns includes receiving a carbon dioxide recycle stream. The carbon dioxide recycle stream is separated in a first multistage column to produce a purified carbon dioxide recycle stream and a light hydrocarbon stream. The light hydrocarbon stream is separated in a second multistage column to produce a liquefied petroleum stream and a natural gas liquids stream. The first multistage column and the second multistage column are the only two multistage columns used in the method.

Abstract: Methods and systems for operating and NGL recovery process are provided. In an exemplary method, an absorber column upstream of a fractionator column is operated at a higher pressure than a pressure in the fractionator column. An NGL (C3 plus) stream is taken from the bottom of a fractionator column and then ethylene/ethane stream is taken from the top of the fractionator column. A differential pressure between the absorber column and the fraction are column is controlled based, at least in part, on a flow rate of the fractionator feed stream from the absorber column to the fractionator column.

Abstract: A method for recovering hydrocarbons with two multistage columns includes receiving a carbon dioxide recycle stream. The carbon dioxide recycle stream is separated in a first multistage column to produce a purified carbon dioxide recycle stream and a light hydrocarbon stream. The light hydrocarbon stream is separated in a second multistage column to produce a liquefied petroleum stream and a natural gas liquids stream. The first multistage column and the second multistage column are the only two multistage columns used in the method.

Abstract: Systems and methods for purifying crude propane streams are provided herein. For example, in some embodiments, methods are provided including passing a crude propane stream to a fixed bed reactor containing a Beta zeolite configured to reduce the propylene oxide content of the crude propane stream and produce a propylene-treated stream and contacting the propylene-treated stream with an acetaldehyde scavenger to produce a treated propane stream. In some embodiments, methods are provided including passing a crude propane stream through a water wash system to provide a treated propane stream having a lower propylene oxide content, a lower acetaldehyde content, or both.

Abstract: Systems and methods for purifying crude propane streams are provided herein. For example, in some embodiments, methods are provided including passing a crude propane stream to a fixed bed reactor containing a Beta zeolite configured to reduce the propylene oxide content of the crude propane stream and produce a propylene-treated stream and contacting the propylene-treated stream with an acetaldehyde scavenger to produce a treated propane stream. In some embodiments, methods are provided including passing a crude propane stream through a water wash system to provide a treated propane stream having a lower propylene oxide content, a lower acetaldehyde content, or both.

Abstract: A system and method of optimizing Carbon Dioxide (CO2) delivery to crops during high-temperature periods. The method of facilitating plant growth includes the steps of (a) determining the wilting temperature of a set of plants; (b) measuring the ambient temperature of the plants; (c) supplying CO2 gas to the plants when the ambient temperature reaches a predetermined temperature point prior to the wilting temperature of the set of plants; and (d) continuing to supply CO2 gas to the plants until the ambient temperature of the set of plants falls below the predetermined temperature point, and then discontinuing supplying CO2 gas to the plants. Temperature of the plants is measured by a temperature sensor continuously monitoring the ambient temperature of the plants. A CO2 gas applicator disposed near the plants supplies CO2. The CO2 gas applicator is connected to a controller that is connected to a CO2 gas source.

Abstract: The invention relates to a process for recovering methane from digester biogas or landfill gas. More specifically, the invention pertains to a method for producing biomethane that removes impurities from a compressed digester biogas with staged membrane modules of at least two different types, to produce a biomethane having at least 94% CH4, below 3% of CO2, and below 4 ppm of H2S.

Abstract: A separation zone and a method of separating a mixed stream are described. The separation zone includes a tank and a stack having a gas outlet. A first baffle is positioned between the sides and defines a disulfide liquid compartment. The stack is positioned above the disulfide liquid compartment. A second baffle is positioned between the first baffle and the second side and defines an alkali compartment. The second baffle has a height less than the height of the first baffle. A third baffle is positioned between the first and second baffles. The bottom of the third baffle is at a height less than the height of the second baffle, and the top of the third baffle is at a height greater than the height of the first baffle.

Abstract: The invention is directed to a process and apparatus for removing hydrogen sulfide from a gas stream comprising biogas. In accordance with the invention the gas stream is contacted with an oxidizing agent present in a vessel, whereby said hydrogen sulfide is oxidized into elemental sulfur and said oxidizing agent is reduced, wherein oxygen containing gas is also fed to said vessel, wherein said oxygen oxidizes at least part of said reduced oxidizing agent.

Abstract: A method for recovering synthetic oils from a feed stream, the method comprising separating at least a portion of the non-synthetic oil constituents from a commingled stream to produce a partially purified synthetic oil stream and one or more contaminant streams. Extracting at least a portion of the synthetic oil from the partially purified synthetic oil stream to produce a synthetic oil stream and a second contaminant stream.

Abstract: A process and an apparatus are disclosed for a compact processing assembly to improve the recovery of C2 (or C3) and heavier hydrocarbon components from a hydrocarbon gas stream. The preferred method of separating a hydrocarbon gas stream generally includes producing at least a substantially condensed first stream and a cooled second stream, expanding both streams to lower pressure, and supplying the streams to a fractionation tower. In the process and apparatus disclosed, the expanded first stream is heated to form a vapor fraction and a liquid fraction. The vapor fraction is combined with the tower overhead vapor, directed to a heat and mass transfer means inside a processing assembly, and cooled and partially condensed by the expanded first stream to form a residual vapor stream and a condensed stream. The condensed stream is combined with the liquid fraction and supplied to the tower at its top feed point.

Abstract: A method for gas processing, in particular for processing biogas of a biogas plant in which in one method step a membrane process or a reactive process is executed, and in at least one further method step an adsorption and/or absorption process is executed.

Abstract: In a process for the separation of a stream containing carbon dioxide, water and at least one light impurity including a separation step at subambient temperature, the feed stream is compressed in a compressor comprising at least two stages to form a compressed feed stream, the compressed feed stream is purified in an adsorption unit to remove water and form a dried compressed stream, the dried compressed stream or a stream derived therefrom is cooled to a subambient temperature and separated by partial condensation and/or distillation in a separation apparatus, liquid enriched in carbon dioxide is removed from the separation apparatus, the adsorption unit is regenerated using a regeneration gas and the regeneration gas is formed by separating, by permeation in a permeation unit, the dried compressed stream or a gas derived therefrom, the permeate of the permeation unit constituting the regeneration gas.

Abstract: One exemplary embodiment can be a process for removing one or more sulfur compounds from a first liquid. The process can include passing the first liquid through a first inlet and a second liquid through a second inlet of a vessel, passing the first and second liquids through the passageway for facilitating contacting of the first and second liquids to extract the one or more sulfur compounds from the first liquid to the second liquid, and passing the first liquid through the first outlet and the second liquid through the second outlet. Often, the vessel has a plurality of vortex contactors, and a first outlet and a second outlet. The plurality of vortex contactors can include a first vortex contactor, in turn having at least one wall forming a perimeter about an interior region and including a first side and a second side forming a passageway communicating the first liquid from an exterior to the interior region, and a frustum positioned proximate to the passageway and abutting the at least one wall.

Abstract: Methods and apparatuses are provided for producing low sulfur propane and butane. The method includes reacting a mercaptan in a washed feed stream with a caustic stream to produce a mercaptan salt in a rich caustic stream and a hydrocarbon treated stream. The mercaptan salt in the rich caustic stream is reacted with oxygen and water to produce a mixed caustic/disulfide stream, and the caustic and disulfides in the mixed caustic/disulfide stream are separated to produce a disulfide stream and the caustic stream. The hydrocarbon treated stream is fractionated to produce a propane stream, a butane stream, and a C5+ stream.

Abstract: Disclosed are systems and methods which provide a process stream comprising a gaseous component, capture the gaseous component from the process stream by an ionic liquid solvent of a separator, and recover a captured gaseous component from the ionic liquid solvent in a regenerator. A second gaseous component from the process stream may be captured by the ionic liquid solvent of the separator, and the second gaseous component may be recovered from the ionic liquid solvent in the regenerator. Alternatively, the second gaseous component from the process stream may be uncaptured by the ionic liquid solvent, and the uncaptured second gaseous component may be recovered from a membrane unit.

Abstract: The present disclosure relates to a biogas purification system and method for removal of sulfur and halogenated compounds and acidic reaction products from biogas. A contaminant removal module is supplied containing a catalytic oxidation catalyst comprising vanadium oxide (V2O5) on a metal oxide support where the catalyst oxidizes 85% or more of the sulfur and halogenated compounds. This may be followed by a contaminant removal module containing alkali impregnated carbon which removes 85% or more of the acidic reaction products. If siloxane impurities are present in the biogas, one may utilize a contaminant removal module containing alumina oxide.

Abstract: The present invention provides a novel system and method for sulphur and metal removal from crude oil and all liquid fuel fractions to biofuels by means of ultrasonic cavitation to enhance chemical reactions of said contaminants with sodium or potassium methylate and a water/fluoride mix in separate stages obtaining a solid form which is filtered out by the use of a centrifuge system. The resulting fuel is molecularly stable and cleaner than regular fuels.

Abstract: Elimination of mercury contained in a hydrocarbon feed by: a) feed 1 is mixed with a hydrogen stream 14 and a gaseous fraction 13 originating from c), b) mixture 1a contacted with a catalyst to convert mercury compounds to elemental mercury producing an effluent containing elemental mercury 6, c) effluent containing elemental mercury is cooled to between 20° C. and 80° C., then, at 1.5 MPa and 3.5 MPa and between 20° C. and 80° C., separation 10 of said effluent containing the elemental mercury into a gaseous fraction 11 and a liquid fraction 15, at least a part of said gaseous fraction 11 being recycled to step a), d) fractionation 20 of liquid fraction 15 to produce a gaseous phase 42 and a liquid phase 21, and e) contacting at least a part of gaseous phase 42 with a mercury collection material 43.

Abstract: Methods and systems for processing crude oil comprise adding water to the crude oil to produce an emulsion comprising brine and oil and solids; separating oil from brine including producing brine comprising a rag layer; separating the rag layer into a hydrocarbon emulsion having finer solids and brine comprising larger solids; and passing the hydrocarbon emulsion along a cross-flow filter to produce a retentate comprising brine and solids and a permeate comprising hydrocarbon.

Abstract: A process and an apparatus are disclosed for a compact processing assembly to improve the recovery of C2 (or C3) and heavier hydrocarbon components from a hydrocarbon gas stream. The preferred method of separating a hydrocarbon gas stream generally includes producing at least a substantially condensed first stream and a cooled second stream, expanding both streams to lower pressure, and supplying the streams to a fractionation tower. In the process and apparatus disclosed, the expanded first stream is heated to form a vapor fraction and a liquid fraction. The vapor fraction is combined with the tower overhead vapor, directed to a heat and mass transfer means inside a processing assembly, and cooled and partially condensed by the expanded first stream to form a residual vapor stream and a condensed stream. The condensed stream is combined with the liquid fraction and supplied to the tower at its top feed point.

Abstract: A process and an apparatus are disclosed for a compact processing assembly to fractionate lighter components from mixed hydrocarbon streams. The hydrocarbon stream is supplied to the processing assembly between an absorbing means and a mass transfer means. A distillation vapor stream is collected from the upper region of the absorbing means and cooled in a first heat and mass transfer means inside the processing assembly to partially condense it, forming a volatile stream and a condensed stream. The condensed stream is supplied to the absorbing means as its top feed. A distillation liquid stream is collected from the lower region of the mass transfer means and heated in a second heat and mass transfer means inside the processing assembly to strip out its volatile components, forming a relatively less volatile stream and a vaporized stream. The vaporized stream is supplied to the mass transfer means as its bottom feed.

Abstract: A process and an apparatus are disclosed for a compact processing assembly to remove C5 and heavier hydrocarbon components from a hydrocarbon gas stream. The hydrocarbon gas stream is expanded to lower pressure and supplied to the processing assembly between an absorbing means and a mass transfer means. A distillation vapor stream is collected from the upper region of the absorbing means and cooled in a first heat and mass transfer means inside the processing assembly to partially condense it, forming a residual vapor stream and a condensed stream. The condensed, stream is supplied to the absorbing means at its top feed point. A distillation liquid stream is collected from the lower region of the mass transfer means and directed into a second beat and mass transfer means inside the processing assembly to heat it and strip out its volatile components.

Abstract: The invention involves a process for treating a natural gas stream comprising sending the natural gas stream first to an adsorbent unit for removal of mercury. Then the gas stream is sent to an absorbent unit containing a chemical solvent and a physical solvent for removal of carbon dioxide, hydrogen sulfide, carbonyl sulfide and organic sulfur compounds to produce a partially purified natural gas stream. This stream is dehydrated and becomes the product stream. The partially purified natural gas stream to a dehydration unit to remove water to produce a natural gas product stream. The impurities absorbed by the absorption unit are removed and a liquid stream is separated that contains the sulfur impurities. This liquid stream may be purified and stabilized before being shipped for further treatment.

Abstract: Methods and systems for processing crude oil comprise adding water to the crude oil to produce an emulsion comprising brine and oil and solids; separating oil from brine including producing brine comprising a rag layer; separating the rag layer into a hydrocarbon emulsion having finer solids and brine comprising larger solids; and passing the hydrocarbon emulsion along a cross-flow filter to produce a retentate comprising brine and solids and a permeate comprising hydrocarbon.

Abstract: An exemplary embodiment can be a process for removing one or more sulfur compounds in a gas hydrocarbon stream. The process may include feeding the gas hydrocarbon stream to a prewash zone containing an alkali stream and passing the gas hydrocarbon stream from the prewash zone to an extraction zone. Usually, the gas hydrocarbon stream includes one or more sulfur compounds and the prewash zone includes a hollow fiber membrane.

Abstract: An adsorption process using a fractionation column including a drying section is described. The drying section dries the desorbent and removes water from the adsorption process resulting in increased capacity for the adsorbent bed.

Abstract: One exemplary embodiment can be a process for treating a hydrocarbon stream. The stream can include passing the hydrocarbon stream into a vessel containing a packed zone and a coalescing zone, passing an amine stream into the vessel at a location above an inlet for the hydrocarbon stream, and withdrawing the hydrocarbon stream.

Abstract: One exemplary embodiment can be a process for separating at least one amine from one or more hydrocarbons for regenerating the at least one amine. The process can include passing the at least one amine after contacting with the one or more hydrocarbons from a first vessel to a second vessel. Often, the second vessel includes one or more walls surrounding one or more baffles and contains at least one coalescing zone.

Abstract: One exemplary embodiment can be a process for removing one or more sulfur compounds from one or more hydrocarbons. The process may include passing a hydrocarbon stream from a prewash zone containing a coalescing zone to an extraction zone. Often, the zones are contained within a single vessel and the coalescing zone comprises an oleophilic media.

Abstract: One exemplary embodiment can be a process for removing carbonyl sulfide in a gas phase hydrocarbon stream. The process may include combining the gas phase hydrocarbon stream with another stream including an alkali and an alkanolamine, and passing the combined stream to a prewash zone including a vessel. The gas phase hydrocarbon may include carbonyl sulfide, and the alkali can include at least one of potassium hydroxide, sodium hydroxide, and ammonia. Usually, the vessel contains a contacting zone and a coalescing zone for removing the carbonyl sulfide.

Abstract: A process for treatment of a natural gas stream, or other methane containing stream that passes through a guard bed for removal of mercury and hydrolysis of COS, followed by treatment with an absorbent unit containing an amine solvent for removal of carbon dioxide and hydrogen sulfide. The gas is then dried by a molecular sieve bed. The regeneration gas for the molecular sieve adsorbent bed is chilled to remove liquid hydrocarbons and sulfur compounds. The process is accomplished without the use of an absorbent unit to remove the sulfur compounds.

Abstract: A natural gas feedstream containing contaminants such as carbon dioxide is purified by passing the contaminated natural gas stream through a membrane to remove the bulk of the contaminant, passing the purified natural gas stream to a TSA unit to remove additional contaminant from the natural gas stream to a desired specification, and regenerating the TSA adsorbent by heating the adsorbent with a heated contaminant-containing permeate stream from the membrane.

Abstract: One exemplary embodiment can be a fractionation zone for an alkylation apparatus. The fractionation zone can be a column adapted to receive a feed including at least one alcohol, water, and at least one ketone. The column may provide an overhead stream including the at least one ketone and a side-stream including the at least one alcohol and water.

Abstract: We provide a process for producing high quality gasoline blending components, comprising: a) operating an alkylation reactor in an alkylate mode wherein a gasoline blending component is made having a RON of 90 or higher; and b) operating the alkylation reactor in a distillate mode wherein a second gasoline blending component and a distillate product is made, and wherein the second gasoline blending component has a RON of 85 or higher. Also, we provide an alkylation process unit, comprising: a control system connected to an alkylation reactor, that enables the alkylation reactor to operate in both an alkylate mode that produces a gasoline blending component having a RON of 90 or higher and in a distillate mode that produces a second gasoline blending component having a RON of 85 or higher.

Abstract: [PROBLEM] To provide an industrially advantageous method and system that are simple and have superior energy efficiency for obtaining high-purity propane from low-purity propane. [SOLUTION] Water, carbon dioxide, at least one of ethane and propylene, and at least one of isobutane and normal butane present in low-purity propane in a gaseous phase are adsorbed by means of a zeolite molecular sieve that preferentially adsorbs water and carbon dioxide over propane, an activated carbon molecular sieve that preferentially adsorbs ethane and propylene over propane, and activated carbon that preferentially adsorbs isobutane and normal butane over propane. Propane is condensed in a state in which nitrogen and oxygen are maintained in a gaseous state by introducing the low-purity propane in a gaseous phase into a partial condenser. Nitrogen and oxygen in the gaseous phase are extracted from the partial condenser.

Abstract: One exemplary embodiment can be a process for initiating operations of a separation apparatus. The process may include passing a hydrocarbon carrier having a sulfiding agent through an exchanger for heating the hydrocarbon carrier prior to entering a stripper.

Abstract: Methods and systems for processing crude oil comprise adding water to the crude oil to produce an emulsion comprising brine and oil and solids; separating oil from brine including producing brine comprising a rag layer; separating the rag layer into a hydrocarbon emulsion having finer solids and brine comprising larger solids; and passing the hydrocarbon emulsion along a cross-flow filter to produce a retentate comprising brine and solids and a permeate comprising hydrocarbon.

Abstract: A method for removing high-boiling hydrocarbons from water-soluble solvent flows, wherein said solvent flows are produced in industrial processes which circulate a solvent as a part of the process, and the solvent must be periodically or permanently freed of high-boiling hydrocarbons which influence the quality or the desired properties of the solvent in an unwanted way, and water is added for carrying out the method in a phase separator, so that the high-boiling hydrocarbons are separated off because of their immiscibility with water, and then the water-miscible phase containing water and solvent is returned to the process. According to the invention, the proportion of high-boiling hydrocarbons in circulating solvents in an industrial process can be kept permanently low.

Abstract: One exemplary embodiment can be a process for modifying an apparatus. The apparatus can include adding an adsorption zone upstream of a hydrocracking zone and a downstream of a vacuum distillation zone to adsorb polynuclear aromatic compounds originating from a feed provided to the vacuum distillation zone.

Abstract: Integrated hydroprocessing methods using high activity, low density catalysts are provided. The high activity catalysts allow for blocked operation when processing lube range feedstocks of widely varying characteristics, such as wax content, without having to substantially change the configuration or operating conditions of the process train. Instead, the different feedstocks can be accommodated by varying the reaction temperature in the process train.

Abstract: Integrated hydroprocessing methods using high activity, low density catalysts are provided. The high activity catalysts allow for lower temperature operation, which reduces catalyst degradation, while the low density of the catalysts means a corresponding reduction in the amount of metal needed to fill a reactor volume. The methods allow for flexible processing of feedstocks with a variety of wax contents.

Abstract: Embodiments of apparatuses and methods for separating a paraffin isomerization-zone effluent are provided. In one example, an apparatus comprises a DIB column configured for fractionating the paraffin isomerization-zone effluent to form a branched C4 hydrocarbon-rich stream. The DIB column comprises a vessel. The vessel comprises a cylindrical wall that extends vertically and that encloses an internal cylindrical volume having a lower portion extending to an upper portion. An internal swage is disposed in the lower portion of the internal cylindrical volume. A plurality of fractionation trays includes an upper fractionation tray that is disposed in the internal cylindrical volume above the internal swage and a lower fractionation tray that is disposed in the internal swage. The lower fractionation tray has a smaller diameter than the upper fractionation tray.

Abstract: An exemplary embodiment can be a process for sweetening natural gas to liquefied natural gas specifications. The process can include providing a membrane contactor having a lumen side and a shell side. A feed natural gas is introduced to the lumen side of the membrane contactor. An absorption solvent is introduced to the shell side of the membrane contactor. CO2 and H2S are removed with the absorption solvent from the feed natural gas resulting in a sweetened natural gas containing less than 50 ppmv CO2 and less than 4 ppmv H2S. Corresponding or associated systems for such sweetening of natural gas are also provided.

Abstract: Systems and methods for conditioning synthetic crude oils are provided herein. The systems and methods described herein subject the synthetic crude to one or more process solutions to provide conditioned synthetic crude exhibiting, for example, a reduced TAN.

Abstract: The present invention provides a method for preparing the polymer grade low-carbon olefin through separation of the methanol pyrolysis gas, including steps of the compression, impurity removal, and absorption and separation. In the absorption and separation step, the pyrolysis gas is sent to the front-end ethylene removing column, and then is, with the C4 absorbent, further absorbed and separated to produce polymer grade ethylene products, polymer grade propylene products, and C4 and C5 products. The moderate-temperature and moderate-pressure separation without a cold box according to the present invention provides safer production process, less investment in the equipment, as well as easier separation and lower energy consumption as a result of the front-end ethylene removing and C4 absorption and separation process.

Abstract: The invention relates to a method for producing low-odor n-butane by catalytic hydrogenation of a feed mixture. The aim of the invention is to provide such a method, wherein the feed material, in addition to n-butane, n-butene and up to 1 mass % formic acid and/or up to 1 mass % pentanals and/or up to 0.5 mass % pentanols, also comprises carbon monoxide. The aim is achieved by treating the feed mixture in the temperature range of 15 to 120° C. with an aqueous solution of an alkali metal or alkaline earth metal hydroxide in the concentration range of 0.5 to 30 mass % and subsequently subjecting the feed mixture to the catalytic hydrogenation.

Abstract: A system and method for efficiently removing hydrogen sulfide from a natural gas feed stream to produce a Stinson Process feed stream and an acid gas stream. A first solvent separates the majority of the carbon dioxide and hydrocarbons from the hydrogen sulfide in the natural gas feed to produce the Stinson feed stream. By removing the majority of the hydrogen sulfide prior to feeding the Stinson Process, a carbon dioxide stream suitable for use in flooding operations may be produced with the Stinson Process. The system and method also increase the concentration of hydrogen sulfide in the acid gas stream, making it suitable for sulfur recovery operations. The system and method are particularly suitable for natural gas feed streams containing 0.5%-20% hydrogen sulfide and at least 20% carbon dioxide. Operation in an anhydrous mode with the addition of nitrogen aids in solvent recovery for recycling.

Abstract: Systems and methods for removal of gas phase contaminants may utilize catalytic oxidation. For example, a method may include passing a gas that includes a gas phase contaminant through a catalytic membrane reactor at a temperature of about 150° C. to about 300° C., wherein the catalytic membrane reactor includes a bundle of tubular inorganic membranes, wherein each of the tubular inorganic membranes comprise a macroporous tubular substrate with an oxidative catalyst and a microporous layer disposed on a bore side of the macroporous tubular substrate, and wherein at least about 50% of the gas flows through the tubular inorganic membranes in a Knudsen flow regime; and oxidizing at least some of the gas phase contaminant with the oxidative catalyst layer, thereby reducing a concentration of the gas phase contaminant in the gas.