An enhanced natural gas processing method using Fischer-Tropsch (FT) process for the synthesis of sulfur free, clean burning, hydrocarbon fuels, examples of which include syndiesel and aviation fuel. A selection of natural gas, separately or combined with portions of natural gas liquids and FT naphtha and FT vapours are destroyed in a syngas generator and used or recycled as feedstock to an Fischer-Tropsch (FT) reactor in order to enhance the production of syndiesel from the reactor. The process enhancement results are the maximum production of formulated syndiesel without the presence or formation of low value by-products.

A catalyst and corresponding methods of using a catalyst are provided that can be beneficial for conversion of paraffins into a product stream enriched in aromatics and/or methane while reducing or minimizing the content of ethane in the product stream. Such catalysts and methods can be useful, for example, for processing a raw gas, associated gas, tail gas, natural gas, or other type of methane-containing feed stream to convert C.sub.2+ hydrocarbons in the stream to heavier hydrocarbons and methane while reducing or minimizing content of ethane in the products from the conversion reaction. Such conversion can be useful for upgrading a methane-containing feed stream to have an energy content that is suitable for pipeline transport under one or more specifications for transport of natural gas. The catalyst and corresponding method can also be beneficial when used as a second stage catalyst in a configuration involving multiple conversion stages.

The present invention relates to the extraction of gasoline from a gas G, with (a) a step of extracting gasoline from the gas to be treated comprising methanol GM obtained from step (d), (b) a step of separating said fluid GL1 partially condensed in step (a), producing a first aqueous liquid phase Al , a first liquid phase H1 of hydrocarbon(s) a gaseous phase G1 obtained from the gas G; (c) a step of contacting a portion of the gas G to be treated with said first aqueous liquid phase A1, producing a second aqueous liquid phase A2, a gaseous phase of gas to be treated comprising methanol GM; (d) a step of mixing said gaseous phase of gas to be treated comprising methanol GM with the remainder of the gas G to be treated, producing a gas to be treated comprising methanol GM, (e) a step of stabilizing said first liquid phase H1 of hydrocarbon(s).

The present disclosure provides oxidative coupling of methane (OCM) systems for small scale and world scale production of olefins. An OCM system may comprise an OCM subsystem that generates a product stream comprising C.sub.2+ compounds and non-C.sub.2+ impurities from methane and an oxidizing agent. At least one separations subsystem downstream of, and fluidically coupled to, the OCM subsystem can be used to separate the non-C.sub.2+ impurities from the C.sub.2+ compounds. A methanation subsystem downstream and fluidically coupled to the OCM subsystem can be used to react H.sub.2 with CO and/or CO.sub.2 in the non-C.sub.2+ impurities to generate methane, which can be recycled to the OCM subsystem. The OCM system can be integrated in a non-OCM system, such as a natural gas liquids system or an existing ethylene cracker.

The invention relates to various nonlimiting embodiments that include methods, apparatuses or systems for processing natural gas comprising a heavies removal column processing natural gas and light oil reflux. The overhead stream goes to heavies treated natural gas storage. The heavies removal column reboiler bottoms stream product is input to a debutanizer column. The debutanizer column overhead lights are input to a flash drum where the bottoms is pumped through a heat exchanger as a light oil reflux input to the heavies removal column, while the debutanizer reboiler bottoms product is stored as stabilized condensate. Alternatively, debutanizer column overhead lights are sent to heavies treated gas storage and the bottoms stream product goes to a depentanizer column, the overhead lights are pumped through a heat exchanger as a light oil reflux input to the heavies removal column, while the depentanizer reboiler bottoms product is stabilized condensate.

Disclosed are compositions for catalysts comprising a zeolite promoted by metal and or metal oxide. In some aspects, the metal and/or metal oxide comprise a mixture of two or more metal or metal oxides. In various aspects, the zeolite is a pentasil zeolite and/or a ZSM-5 type zeolite. Also disclosed are processes for making the disclosed heterogeneous catalysts comprising preparing a mixture of a zeolite and one or more metal salts, which can include use of incipient wetness impregnation methods. In various aspects, also disclosed are methods for direct, non-oxidative preparation of higher hydrocarbons from natural gas, including selective for high yield production of C6 and higher hydrocarbons. This abstract is intended as a scanning tool for purposes of searching in the particular art and is not intended to be limiting of the present disclosure.

A hydrogen sulfide (H.sub.2S) scavenging system for removing H.sub.2S, mercaptans, and/or other sulfur-containing compounds from a natural gas stream. A co-current contacting system is located in-line within a pipe and receives the natural gas stream and a liquid scavenger stream. The co-current contacting system includes a co-current contactor including a droplet generator and a mass transfer section. The droplet generator generates droplets from the liquid scavenger stream and disperses the droplets into the natural gas stream. The mass transfer section provides a mixed, two-phase flow having a vapor phase and a liquid phase. The liquid phase includes the liquid scavenger stream with H.sub.2S, mercaptans, and/or other sulfur-containing compounds absorbed from the natural gas stream, and the vapor phase includes the natural gas stream. A separation system separates the vapor phase from the liquid phase.

Processes for converting methane and/or other hydrocarbons to synthesis gas (i.e., a gaseous mixture comprising H.sub.2 and CO) are disclosed, in which at least a portion of the hydrocarbon(s) is reacted with CO.sub.2. At least a second portion of the methane may be reacted with H.sub.2O (steam), thereby improving overall thermodynamics of the process, in terms of reducing endothermicity (H) and the required energy input, compared to pure dry reforming in which no H.sub.2O is present. Such dry reforming (reaction with CO.sub.2 only) or CO.sub.2-steam reforming (reaction with both CO.sub.2 and steam) processes are advantageously integrated with Fischer-Tropsch synthesis to yield liquid hydrocarbon fuels. Further integration may involve the use of a downstream finishing stage involving hydroisomerization to remove FT wax. Yet other integration options involve the use of combined CO.sub.2-steam reforming and FT synthesis stages (optionally with finishing) for producing liquid fuels from gas streams generated in a number of possible processes, including the hydropyrolysis of biomass.

A system and a process for processing a natural gas liquid feed is provided. In the system, a dense fluid expander is positioned downstream from a subcooler heat exchanger. The subcooler heat exchanger cools one or more reflux streams against an overhead vapor stream and a distillation column positioned downstream from the dense fluid expander. An increase in recovery of natural gas liquids is provided through the use of this system having at least one dense fluid expander.

An integrated process for converting light hydrocarbon gases into products. Pre-packaged equipment such as a gas turbine and process compressors may be used to efficiently integrate the process. The gas turbine may provide a portion of the oxygen required in the process as compressed air. An additional oxygen rich stream may be provided by a separate air separation process so that the combined air and oxygen rich streams have an oxygen content of 25% to 50%. The gas turbine may also provide thermal energy to pre-heat the oxygen rich stream and feed gas stream and power to run compressors, air separation, and auxiliaries in the process.