Methods and systems for gas separation of syngas applying differences in water solubilities of syngas components, the method including producing a product gas comprising hydrogen and carbon dioxide from a hydrocarbon fuel source; separating hydrogen from the product gas to create a hydrogen product stream and a byproduct stream by solubilizing components in water that are more soluble in water than hydrogen; injecting the byproduct stream into a reservoir containing mafic rock; and allowing components of the byproduct stream to react in situ with components of the mafic rock to precipitate and store components of the byproduct stream in the reservoir.

The invention relates to an ethylene plant, comprising a cracking furnace for converting a hydrocarbon feedstock into a cracked gas stream; a separation section to provide at least an ethylene-enriched product stream, a hydrogen-enriched fuel stream and a methane-enriched fuel stream from the cracked gas stream; a passage way for feeding at least part of the hydrogen-enriched fuel from the separation section to a burner of the cracking furnace and/or a passage way for feeding at least part of the hydrogen-enriched fuel from the separation section to a burner of a waste heat recovery boiler of a combined cycle gas turbine power plant(CCGT); a methane storage configured for storing methane-enriched fuel and a passage way for feeding at least part of the methane-enriched fuel from the separation section to the storage; the CCGT, comprising a gas turbine—comprising a combustor—and a passage way for feeding at least part of the methane-enriched fuel from the storage to the combustor of the gas turbine of the CCGT, which CCGT is configured to generate electric power and/or to generate high pressure steam to drive a steam turbine forming part of a steam generation circuit of the ethylene plant; and an electric power connection for providing part of the power for operating the plant, which is a connection to an electric power system to produce electric power from a renewable source.

The present application relates to a process for cracking a hydrocarbon feedstock, using to the largest extent electrically powered equipment where the power is obtained from renewable sources or low-carbon sources. In particular, it relates to a furnace for steam cracking a hydrocarbon feedstock, wherein the furnace comprises one or more tubes for transporting the hydrocarbon feedstock and dilution steam; and an electrically heated infrared emitter for transferring heat to the tubes. It also relates to a process for steam cracking a hydrocarbon feedstock using infrared radiation.

The present application relates to a process for cracking a hydrocarbon feedstock, using to the largest extent electrically powered equipment where the power is obtained from renewable sources or low-carbon sources. In particular, it relates to a process for cracking a hydrocarbon feedstock, including bringing the hydrocarbon feedstock and dilution steam to supersonic velocities in the reactor, followed by applying a shockwave to induce cracking of the hydrocarbon feedstock, to convert at least a part of the hydrocarbon mixture to produce olefins.

An automatic control system (ACS) for capturing and utilizing carbon dioxide (CO.sub.2) of one or more gases from one or more plants receives one or more parameters of at least one gas of one or more gases through a system gas flow inlet channel, a first volumetric flow rate of the one or more gases through a plug flow reactor (PFR), a second volumetric flow rate of the one or more gases through a bypass channel that bypasses the PFR, the CO.sub.2 flowing into the CO.sub.2 capture unit, or the syngas flowing into the CO.sub.2 capture unit. The ACS commands one or more flow controllers to modulate at least one of the first volumetric flow rate of the one or more gases through PFR or the second volumetric flow rate of the one or more gases through the bypass channel based on the one or more parameters.

A system optionally including a carbon oxide reactor. A method for carbon oxide reactor control, optionally including selecting carbon oxide reactor aspects based on a desired output composition, running a carbon oxide reactor under controlled process conditions to produce a desired output composition, and/or altering the process conditions to alter the output composition.

A method may include obtaining reservoir data for a geological region of interest. The method may further include obtaining production data regarding one or more wells coupled to the geological region of interest. The method may further include obtaining carbon emission data for the one or more wells. The method may further include determining predicted carbon emission data and predicted production data using a machine-learning model. The method may further include determining one or more stimulation parameters for a stimulation operation based on the predicted carbon emission data and the predicted production data. The method may further include transmitting a command to a control system coupled to an injection well. The command adjusts an amount of carbon dioxide that is supplied to the injection well based on the one or more stimulation parameters.

Processes for producing high biogenic concentration Fischer-Tropsch liquids derived from the organic fraction of municipal solid wastes (MSW) feedstock that contains a relatively high concentration of biogenic carbon (derived from plants) and a relatively low concentration of non-biogenic carbon (derived from fossil sources) wherein the biogenic content of the Fischer-Tropsch liquids is the same as the biogenic content of the feedstock.

A three step method for the conversion of ethanol into fuels that can be utilized as full-performance military jet or diesel fuels. Embodiments of the invention further describe methods for the selective conversion of ethanol to full performance saturated hydrocarbon fuels that are suitable for both jet and diesel propulsion.

Systems and methods are provided for performing hydrocarbon reforming within a reverse flow reactor environment (or another reactor environment with flows in opposing directions) while improving management of CO.sub.2 generated during operation of the reactor. The improved management of CO.sub.2 is achieved by making one or more changes to the operation of the reverse flow reactor. The changes can include using an air separation unit to provide an oxygen source with a reduced or minimized content of nitrogen and/or operating the reactor at elevated pressure during the regeneration stage. By operating the regeneration at elevated pressure, a regeneration flue gas can be generated that is enriched in CO.sub.2 at elevated pressure. The CO.sub.2-enriched stream can include primarily water as a contaminant, which can be removed by cooling while substantially maintaining the pressure of the stream. This can facilitate subsequent recovery and use of the CO.sub.2.