A method for operation of an industrial plant having an energy accumulator unit for production of synthetic natural gas, a power plant unit for production of electricity, an oxygen tank, a carbon dioxide tank and a water tank. In a first operation mode the energy accumulator unit is supplied with excessed electricity from the public grid to produce synthetic natural gas, wherein the produced synthetic natural gas is discharged in a gas network, while oxygen and water which are produced together with the synthetic natural gas are stored in the oxygen tank and the water tank correspondingly. In a second operation mode gas from the gas network together with oxygen from the oxygen tank and water from the water tank are used in the power plant unit to produce electricity, which is supplied to the public grid. This way electricity production excess is efficiently accumulated for industrial or municipal use.

A biogas-utilizing methanation system includes: a solid oxide fuel cell using a to-be-treated gas as a fuel gas; a hydrogen production device capable of producing hydrogen by using power of a renewable energy power generation device; and a methanation device capable of methanating carbon dioxide in the system with the hydrogen produced by the hydrogen production device. The carbon dioxide in the system can be stored in a storage device on the basis of the supply amount of the to-be-treated gas or the power of the renewable energy power generation device.

Provided is a first step of causing hydrogen and carbon oxide to react with each other in a presence of a first catalyst to obtain a first fuel gas 2 that contains 2% to 10% hydrogen by volume after dehydration; and a second step of consuming the hydrogen in the first fuel gas 2 to obtain a second fuel gas 4 with a reduced hydrogen concentration. The first catalyst includes a methanation catalyst. The second step includes an exothermic reaction that generates heat of 60 kJ or more per mole of hydrogen, and the exothermic reaction is a reaction through which the hydrogen in the first fuel gas 2 and a predetermined reactant 3 are caused to react with each other in a presence of a second catalyst to generate water or a paraffin hydrocarbon with two to four carbon atoms.

Provided is a first step of causing hydrogen and carbon oxide to react with each other in a presence of a first catalyst to obtain a first fuel gas 2 that contains 2% to 10% hydrogen by volume after dehydration; and a second step of consuming the hydrogen in the first fuel gas 2 to obtain a second fuel gas 4 with a reduced hydrogen concentration. The first catalyst includes a methanation catalyst. The second step includes an exothermic reaction that generates heat of 60 kJ or more per mole of hydrogen, and the exothermic reaction is a reaction through which the hydrogen in the first fuel gas 2 and a predetermined reactant 3 are caused to react with each other in a presence of a second catalyst to generate water or a paraffin hydrocarbon with two to four carbon atoms.

The present invention relates to a technique for treating a raw material, such as combustible waste, and more particularly to combustion, and pyrolysis and gasification treatment techniques that does not emit carbon dioxide into the atmosphere. A treatment apparatus includes a fluidized-bed furnace having a pyrolysis chamber and a combustion chamber therein, the pyrolysis chamber and the combustion chamber are separated by a partition wall, an electrolysis device configured to electrolyze water to generate hydrogen and oxygen, a methanation reactor configured to produce methane from carbon dioxide discharged from the combustion chamber and the hydrogen, a first fluidizing-gas supply line configured to supply a first fluidizing gas to the pyrolysis chamber, and a second fluidizing-gas supply line configured to introduce a second fluidizing gas to the combustion chamber, the second fluidizing gas including the oxygen and a part of the carbon dioxide.

A method for transporting liquid methane includes generating electricity in plants; using the electricity to split water into hydrogen and oxygen; providing carbon dioxide; feeding the hydrogen and the carbon dioxide from step into a reactor system for producing methane, wherein this reactor system comprises a catalytic reactor cooled with boiling water; liquefying the methane so produced; transporting the liquefied methane to a place of consumption located far away; utilising the liquefied methane at the place of consumption subject to generating carbon dioxide;) separating this carbon dioxide. At the place of consumption the methane is subjected to a steam reformation for producing hydrogen, wherein carbon dioxide is generated. At least a part of the carbon dioxide generated during the steam reformation is transported back to the reactor system for producing methane.

Processes, systems, and associated control methodologies are disclosed that control the flow of biogas during the biogas cleanup process to create a more consistent flow of biogas through the digester, while also optimizing the output and efficiency of the overall renewable natural gas facility. In representative embodiments, a biogas buffer storage system may be used during the cleanup process to control the pressure and flow rate of biogas. The biogas buffer storage system may monitor and control the biogas flow rate to either bring down or increase the digester pressure, thereby maintaining a normalized biogas flow rate.

Processes, systems, and associated control methodologies are disclosed that control the flow of biogas during the biogas cleanup process to create a more consistent flow of biogas through the digester, while also optimizing the output and efficiency of the overall renewable natural gas facility. In representative embodiments, a biogas buffer storage system may be used during the cleanup process to control the pressure and flow rate of biogas. The biogas buffer storage system may monitor and control the biogas flow rate to either bring down or increase the digester pressure, thereby maintaining a normalized biogas flow rate.

A method for determining properties of a hydrocarbon-containing gas mixture includes determining a thermal conductivity value, density measurement, viscosity measurement, and temperature and pressure. The method also includes determining a hydrogen content of the gas mixture on the basis of the thermal conductivity value and the temperature and pressure, determining a density measurement and associated temperature and pressure, and determining the mean molar mass or standard density on the basis of the density measurement and the temperature and pressure. The method further includes determining the mean molar mass or standard density of a hydrogen-free residual gas mixture based on the mean molar mass or standard density and the hydrogen fraction, determining the Wobbe index of the residual gas mixture based on the viscosity measurement and the temperature and pressure, and determining a calorific value based on the mean molar mass or standard density and the Wobbe index.

Processes, systems, and associated control methodologies are disclosed that control the flow of biogas during the biogas cleanup process to create a more consistent flow of biogas through the digester, while also optimizing the output and efficiency of the overall renewable natural gas facility. In representative embodiments, a biogas buffer storage system may be used during the cleanup process to control the pressure and flow rate of biogas. The biogas buffer storage system may monitor and control the biogas flow rate to either bring down or increase the digester pressure, thereby maintaining a normalized biogas flow rate.