Method for driving machines, in an ethylene plant steam generation circuit, the method including recovering heat as high pressure steam from a cracking furnace; providing said high pressure steam to at least one steam turbine, wherein the steam turbine is configured to drive a machine, such as a process compressor; condensing at least part of the high pressure steam in a condenser; pumping condensed steam as boiler feed water back to the cracking furnace.

An ASG system for polygeneration with CC includes a devolatilizer that pyrolyzes solid fuel to produce char and gases. A burner adds exothermic heat by high-pressure sub-stoichiometric combustion, a mixing pot causes turbulent flow of the gases to heat received solid fuel, and a riser micronizes resulting friable char. A devolatilizer cyclone separates the micronized char by weight providing micronized char, steam and gases to a gasifier feed and oversized char to the mixing pot. An indirect fluid bed gasifier combustion loop includes a gasifier coupled to the gasifier feed, a steam input to provide oxygen for gasification and to facilitate sand-char separation, and an output for providing syngas. A burner provides POC to a mixing pot which provides hot sand with POC to a POC cyclone via a riser, where the POC cyclone separates sand and POC by weight and provides POC and sand for steam-carbon reaction.

A method and apparatus for generating electricity and producing carbon and heat via biomass fixed bed gasification, said method and apparatus utilising medium calorific value combustible gas to satisfy high-temperature high-pressure boiler heat requirements, and increasing overall electricity generation efficiency. The method and apparatus have low nitrogen oxides amounts, satisfy environmental protection requirements, and do not require denitrification treatment. The method comprises the following steps: feeding a biomass raw material into a gasification apparatus to prepare a medium calorific value biomass combustible gas, and performing gasification on the biomass raw material at 700-850° C. under the effect of an air/water vapour pre-mixed gasification agent to produce a combustible gas, the calorific value of the combustible gas being 1600-1800 kcal, the temperature being 200-300° C.; directly feeding the combustible gas into an environmentally friendly combustion chamber for combustion, and then into a high-temperature high-pressure boiler, the gas combusting within the high-temperature high-pressure boiler to produce high-temperature high-pressure steam, which drives a steam turbine to generate electricity; utilising steam waste heat discharged by the steam turbine; using boiler tail gas to heat air by means of an air preheater, the hot air being respectively fed into the combustion chamber and the gasification apparatus by means of an air blower, and utilising the waste heat.

A chemical looping combustion (CLC) based power generation, particularly using liquid fuel, ensures substantially complete fuel combustion and provides electrical efficiency without exposing metal oxide based oxygen carrier to high temperature redox process. An integrated fuel gasification (reforming)-CLC-followed by power generation model is provided involving (i) a gasification island, (ii) CLC island, (iii) heat recovery unit, and (iv) power generation system. To improve electrical efficiency, a fraction of the gasified fuel may be directly fed, or bypass the CLC, to a combustor upstream of one or more gas turbines. This splitting approach ensures higher temperature (efficiency) in the gas turbine inlet. The inert mass ratio, air flow rate to the oxidation reactor, and pressure of the system may be tailored to affect the performance of the integrated CLC system and process.

A system for producing high purity carbon monoxide and hydrogen as well as activated carbon includes a pyrolysis reactor, a gasifier, a combustion turbine, a boiler, a steam turbine, a combined cycle unit and an electrolysis unit. Liquid fuel from the pyrolysis reactor is provided to the combustion turbine. Liquid and gaseous fuels are provided to the boiler. Compressed oxygen from the electrolysis unit is provided to the combustion turbine. Electric power from the combustion turbine and steam turbine are provided to the electrolysis unit. The gasifier includes a preheat region, a gasification region, and a cooling region. CO.sub.2 and O.sub.2 are injected into the gasifier at multiple injection levels to create an isothermal gasification region to produce CO. The CO.sub.2 and O.sub.2 are preheated in a heat exchanger using the CO exiting from the gasifier prior to injection.

A plant and a method for the production of hydrogen and bicarbonate. The plant includes a gasifier, a reformer, a direct contact exchanger and an apparatus for the production of bicarbonate. The plant is suitable for receiving fuel, oxygen, water, carbonate, brine at the inlet and for producing hydrogen, bicarbonate and calcium chloride at the outlet. The plant uses a self-cleaning direct contact heat exchanger to cool the syngas downstream of the reformer and to produce the superheated steam that feeds the gasifier: this heat exchanger allows the production of hydrogen at low costs and in modular plants.

A combined vessel comprises a stripping section for removing acid gases from a sour water stream and a direct contact heat exchanger section for heating a graywater stream in order to improve heat and mass transfer in the treatment and recycle of water streams for a gasification process.

The present invention provides a process for the manufacture of a useful product from carbonaceous feedstock of fluctuating compositional characteristics, the process comprising the steps of: continuously providing the carbonaceous feedstock of fluctuating compositional characteristics to a gasification zone; gasifying the carbonaceous feedstock in the gasification zone to obtain raw synthesis gas; sequentially removing ammoniacal, sulphurous and carbon dioxide impurities from the raw synthesis gas to form desulphurised gas and recovering carbon dioxide in substantially pure form; converting at least a portion of the desulphurised synthesis gas to a useful product. Despite having selected a more energy intensive sub-process i.e. physical absorption for removal of acid gas impurities, the overall power requirement of the facility is lower on account of lower steam requirements and thereby leading to a decrease in the carbon intensity score for the facility.

An ASG system for polygeneration with CC includes a devolatilizer that pyrolyzes solid fuel to produce char and gases. A burner adds exothermic heat by high-pressure sub-stoichiometric combustion, a mixing pot causes turbulent flow of the gases to heat received solid fuel, and a riser micronizes resulting friable char. A devolatilizer cyclone separates the micronized char by weight providing micronized char, steam and gases to a gasifier feed and oversized char to the mixing pot. An indirect fluid bed gasifier combustion loop includes a gasifier coupled to the gasifier feed, a steam input to provide oxygen for gasification and to facilitate sand-char separation, and an output for providing syngas. A burner provides POC to a mixing pot which provides hot sand with POC to a POC cyclone via a riser, where the POC cyclone separates sand and POC by weight and provides POC and sand for steam-carbon reaction.

A pulverizer that pulverizes coal into pulverized coal; a gasifier that gasifies pulverized coal pulverized by the pulverizer; a combustor that combusts a gasified gas gasified by the gasifier; a compressor that supplies compressed air to the combustor; a gas turbine driven by a combustion gas generated by the combustor; a generator driven by the gas turbine to generate power; a flue gas supply channel that guides a part of a flue gas from the gas turbine to the pulverizer; an IGV that adjusts a flow rate of air supplied from the compressor to the combustor; and a controller that applies an air flow-rate reduction operation to control the IGV so that the flow rate of air is smaller than a set air flow rate determined from a set combustion temperature of the combustor.