A system and method for treating natural gas, including producing natural gas from a subterranean formation via a wellhead system to a nonthermal plasma (NTP) catalytic unit, converting by the NTP unit carbon dioxide (CO.sub.2) and hydrogen sulfide (H.sub.2S) in the natural gas into carbon monoxide (CO), elemental sulfur (S), and hydrogen (H.sub.2), and removing the elemental sulfur as liquid elemental sulfur to give treated natural gas. The NTP unit may convert methane (CH.sub.4) in the natural gas to heavier hydrocarbons.

A dehydrogenation reaction device includes: an acid aqueous solution storage unit including a first aqueous acid solution; a water storage unit including water; and a dehydrogenation reaction unit including a chemical hydride. The dehydrogenation reaction unit receives a second aqueous acid solution in which the first aqueous acid solution and water are mixed, and further reacts the chemical hydride and the second aqueous acid solution to generate hydrogen.

An engine system includes an engine configured to combust liquid natural gas and generate an exhaust gas comprising methane; a catalytic reactor coupled downstream of the engine and configured to convert methane into a product through one or more of oxidative coupling of methane (OCM) reaction and steam methane reforming (SMR) reaction; and a recirculation loop configured to recirculate at least a part of the product back to the engine.

A process of hydrogen production comprising the steps of: subjecting a gaseous mixture comprising a hydrocarbon and steam, and having a steam to carbon ratio of at least 0.9:1, to adiabatic pre-reforming in a pre-reformer followed by autothermal reforming with an oxygen-rich gas in an autothermal reformer to generate a reformed gas mixture, optionally adding steam to the reformed gas mixture, increasing the hydrogen content of the reformed gas mixture by subjecting it to one or more water-gas shift stages in a water-gas shift unit to provide a hydrogen-enriched reformed gas, cooling the hydrogen-enriched reformed gas and separating condensed water therefrom, passing the resulting de-watered hydrogen-enriched reformed gas to a carbon dioxide separation unit to provide a carbon dioxide gas stream and a crude hydrogen gas stream, passing the crude hydrogen gas stream to a purification unit to provide a purified hydrogen gas and a fuel gas.

A fuel reformer for producing a steam reforming reaction between fuel and water on a reforming catalyst includes a fuel injection part that injects and supplies fuel into the reforming catalyst, a temperature measurement part that measures a temperature of the reforming catalyst, and a determination part that determines whether a process for recovering the reforming catalyst is necessary. The determination by the determination part is made based on a temperature change of the reforming catalyst when the steam reforming reaction is produced.

The invention relates to petroleum sludge or other wastes recycle treatment system, which comprises a pre-treatment operation facility for a treated matter to be treated as a raw material. A feeding unit is arranged to feed the raw material into at least one gasification reactor with a push rod or a screw for pyrolysis gasification. The upper half of the at least one gasification reactor is provided with a syngas collecting pipe which can be connected with a gas collecting pump, and the lower half is provided with a liquid petroleum output pipe and an ash residue outlet, in which the ash residue outlet can be provided with a spiral pipe to draw the ash residue out. The petroleum sludge and other wastes in a dense fluid state are transported from a raw material tank to the at least one gasification reactor end which is bent upward through at least one pipe body, and the feeding mode of pyrolysis gasification of the raw material from below to upper of the gasification reactor is adopted. The top of the at least one gasification reactor is provided with a syngas collecting pipe, and the other side is provided with an ash residue accumulation chamber. The ash residue can be centralized and discharged through the lower buffer chamber and the slag discharge chamber, so as to convert the petroleum sludge or other wastes into more energy-efficient syngas providing human beings as users of electric or thermal energy.

Offshore systems and methods may be configured for offshore power generation and carbon dioxide injection for enhanced gas recovery for gas reservoirs. For example, a method may include: providing an offshore facility including a gas turbine, and a gas separator; producing a produced gas from a gas reservoir to the offshore facility; combusting the produced gas in a gas turbine to produce power and a flue gas; at least partially removing nitrogen from the flue gas in a gas separator to produce a carbon dioxide-enriched flue gas and a nitrogen-enriched flue gas; compressing the carbon dioxide-enriched flue gas in a gas compressor to produce a compressed gas; and injecting the compressed gas from the gas compressor into the gas reservoir, wherein 80 mol % or more of hydrocarbon in the produced gas is combusted and/or injected into the gas reservoir.

A method for co-generating electricity in a process plant using feedwater, where the process plant is integrated with a thermal power generator, is provided. The method includes obtaining a pressurized stream of hot feedwater from a feedwater generation unit of the process plant; compressing the pressurized stream of hot feedwater by pumping and splitting the pressurized stream of hot feedwater to obtain a first stream of feedwater and a second stream of feedwater; routing the second stream of feedwater to the thermal power generator; cooling the second stream of feedwater against a process fluid that is used in the thermal power generator to generate a heat in the thermal power generator and to obtain a cooled second stream of feedwater; and co-generating the electricity, using the thermal power generator integrated with the process plant, using the heat.

An energy storage system includes: a combustion turbine configured to output heated sweep gas; a reformer configured to receive natural gas and steam and to output reformed natural gas; a molten carbonate electrolyzer cell (“MCEC”) comprising an MCEC anode and an MCEC cathode, wherein the MCEC is configured to operate in a hydrogen-generation mode in which: the MCEC anode receives the reformed natural gas from the reformer, and outputs MCEC anode exhaust that contains hydrogen, and the MCEC cathode is configured to receive heated sweep gas from the combustion turbine, and to output MCEC cathode exhaust; and a storage tank configured to receive the MCEC anode exhaust that contains hydrogen.

Embodiments include a method for converting renewable energy source electricity and a hydrocarbon feedstock into a liquid fuel by providing a source of renewable electrical energy in communication with a synthesis gas generation unit and an air separation unit. Oxygen from the air separation unit and a hydrocarbon feedstock is provided to the synthesis gas generation unit, thereby causing partial oxidation reactions in the synthesis gas generation unit in a process that converts the hydrocarbon feedstock into synthesis gas. The synthesis gas is then converted into a liquid fuel.