The present invention provides a novel process and system in which a mixture of carbon monoxide and hydrogen synthesis gas, or syngas, is converted into hydrocarbon mixtures composed of high quality gasoline components, aromatic compounds, and lower molecular weight gaseous olefins in one reactor or step. The invention utilizes a novel molybdenum-zeolite catalyst in high pressure hydrogen for conversion, as well as a novel rhenium-zeolite catalyst in place of the molybdenum-zeolite catalyst, and provides for use of the novel catalysts in the process and system of the invention.

Implementations described and claimed herein provide systems and methods for processing liquefied natural gas (LNG). In one implementation, a solvent is injected into a feed of natural gas at a solvent injection point. A mixed feed is produced from a dispersal of the solvent into the feed of natural gas. The mixed feed contains heavy components. A chilled feed is produced by chilling the mixed feed. The chilled feed includes a vapor and a condensed liquid. The condensed liquid contains a fouling portion of the heavy components condensed by the solvent during chilling. The liquid containing the fouling portion of the heavy components is separated from the vapor. The vapor is directed into a feed chiller heat exchanger following separation of the liquid containing the fouling portion of the heavy components from the vapor, such that the vapor being directed into feed chiller heat exchanger is free of freezing components.

Methanol-to-gasoline conversion may be performed using a heavy gasoline treatment, followed by a separation operation. Methanol may be converted into a first product mixture comprising dimethyl ether (DME) under DME formation conditions. In a methanol-to-gasoline (MTG) reactor, the first product mixture may be converted under MTG conversion conditions to produce a second product mixture comprising light gasoline hydrocarbons and untreated heavy gasoline hydrocarbons. The untreated heavy gasoline hydrocarbons may be separated from the light gasoline hydrocarbons and transferred to a heavy gasoline treatment (HGT) reactor. The untreated heavy gasoline hydrocarbons may be catalytically reacted in the HGT reactor to form a third product mixture. A heavy hydrocarbon fraction may be separated from the third product mixture. The heavy hydrocarbon fraction includes heavy gasoline hydrocarbons having a lower boiling endpoint than does the untreated heavy gasoline hydrocarbons.

Methanol-to-gasoline conversion may be performed using a heavy gasoline treatment, followed by a separation operation. Methanol may be converted into a first product mixture comprising dimethyl ether (DME) under DME formation conditions. In a methanol-to-gasoline (MTG) reactor, the first product mixture may be converted under MTG conversion conditions to produce a second product mixture comprising light gasoline hydrocarbons and untreated heavy gasoline hydrocarbons. The untreated heavy gasoline hydrocarbons may be separated from the light gasoline hydrocarbons and transferred to a heavy gasoline treatment (HGT) reactor. The untreated heavy gasoline hydrocarbons may be catalytically reacted in the HGT reactor to form a third product mixture. A heavy hydrocarbon fraction may be separated from the third product mixture. The heavy hydrocarbon fraction includes heavy gasoline hydrocarbons having a lower boiling endpoint than does the untreated heavy gasoline hydrocarbons.

Implementations described and claimed herein provide systems and methods for processing liquefied natural gas (LNG). In one implementation, a dry feed gas is received. The dry feed gas is chilled with clean vapor from a heavies removal column to form a chilled feed gas. The chilled feed gas is partially condensed into a vapor phase and a liquid phase. The liquid phase retains freezing components. The freezing components are extracted using a reflux stream in the heavies removal column. The freezing components are removed as a condensate. The vapor phase is compressed into a clean feed gas. The clean feed gas is free of the freezing components for downstream liquefaction.

The present invention describes a method for the production of liquid biogas (LBG), said method comprising the following steps:—inflow of crude gas comprising mainly methane and carbon dioxide;—removal of trace elements like hydrogen sulphide, siloxanes and VOC's from the crude gas;—dehumidification;—particle purification; for the production of a treated biogas; separation of carbon dioxide from the treated biogas;—condensation of the treated biogas with a low content of carbon dioxide, for the production of LB G with a carbon dioxide content of maximum 100 ppm, preferably at or close to atmospheric pressure the LB G is lose to 100% pure methane with a carbon dioxide content of maximum 100 ppm, wherein the separation of carbon dioxide from the treated biogas involves freezing carbon dioxide in the treated biogas.

A method, system, and apparatus for managing variable, multi-phase fluid conversion to output fuel and energy for providing customizable management for processing a volume of natural gas including a volume of methane and a volume of other alkanes that may be cleaned of the other alkanes using a conversion system to create synthesis gas and other fuel products to be used in onsite or combined heat and power or cogeneration applications. In particular, the method, system, and apparatus provide for automated feedback and control directing various gas constituents to different application units with allocations according to settings system parameters to quickly and efficiently meet the demand for various products while making adjustments in real-time.

A method, system, and apparatus for managing variable, multi-phase fluid conversion to output fuel and energy for providing customizable management for processing a volume of natural gas including a volume of methane and a volume of other alkanes that may be cleaned of the other alkanes using a conversion system to create synthesis gas and other fuel products to be used in onsite or combined heat and power or cogeneration applications. In particular, the method, system, and apparatus provide for automated feedback and control directing various gas constituents to different application units with allocations according to settings system parameters to quickly and efficiently meet the demand for various products while making adjustments in real-time.

Implementations described and claimed herein provide systems and methods for processing liquefied natural gas (LNG). In one implementation, a dry feed gas is received. The dry feed gas is chilled with clean vapor from a heavies removal column to form a chilled feed gas. The chilled feed gas is partially condensed into a vapor phase and a liquid phase. The liquid phase retains freezing components. The freezing components are extracted using a reflux stream in the heavies removal column. The freezing components are removed as a condensate. The vapor phase is compressed into a clean feed gas. The clean feed gas is free of the freezing components for downstream liquefaction.

The disclosure provides methods for the production of liquefied petroleum gas from sustainable feedstocks, including methods comprising conversion of alcohols produced by gas fermentation for the production of propane and/or butane.