A method for exhaust waste energy recovery at the reciprocating gas engine-based polygeneration plant which includes supplying this plant with any on-site available methaneous gas, converting from 15 to 30% of supplied gas into electric or mechanical power and producing a liquefied methaneous gas (LMG) co-product from the other 85-70% of supplied gas, and thereby obviates a need for any specialized refrigeration equipment, refrigerants and fuel for LMG co-production at a rate of 0.4-0.6 ton/h for each MW of engine output and makes possible to increase the LMG co-production rate up to 0.9-1.1 t/MWh at the sacrifice of a fuel self-consumption minimized down to 1-2% of the amount of gas intended for liquefaction.

The present disclosure relates to the technical field of natural gas power generation, and particularly discloses a natural gas combined power generation process with zero carbon emission, the process comprising: introducing the pressurized air into an air separation facility to obtain liquid oxygen and liquid nitrogen, wherein the liquid oxygen is used for gasification and power generation, the liquid nitrogen is applied as the coolant of flue gas, and then used for the gasification and power generation; the liquid nitrogen and a part of liquid oxygen stored during the valley period with low electricity load are provided for use during the peak period with high electricity load; the natural gas, oxygen and the recyclable CO.sub.2 jointly enter a combustion gas turbine for burning to drive an air compressor and a generator to rotate at a high speed, the air compressor compresses the air to a pressure of 0.40.8 MPa, the generator generates electricity; the high-temperature combustion flue gas performs the supercritical CO.sub.2 power generation, its coolant is liquid oxygen; the moderate temperature flue gas then exchanges heat with liquid nitrogen, the liquid nitrogen vaporizes for power generation, the cooled flue gas is dehydrated and subjects to distillation and separation to obtain the recovered CO.sub.2, a part of the CO.sub.2 can be returned for circulation and temperature control, another part of the CO.sub.2 may be used for replenishment of work medium for supercritical CO.sub.2 power generation, and the remaining part of CO.sub.2 may be sold outward as liquid CO.sub.2 product. During the peak period with high electricity load, the liquid nitrogen stored during the valley period with low electricity load and separated during the peak period is pumped and pressurized and then subjects to heat exchange and vaporization for power generation. The power generation process provided by the present disclosure not only solves the difficult problems in the existing natural gas combined power generation technology such as high water consumption, low power generation efficiency and small range of peak load adjustment capacity; but also can compress air with high unit volume for energy storage with a high conversion efficiency, and greatly reduce load of the air compressor, thereby perform CO.sub.2 capture and utilization with low cost, zero NO.sub.x emission and discharging fuel gas at a normal temperature, and significantly improve the power generation efficiency.

The present disclosure relates to the technical field of coal chemical industry, and particularly discloses an integrated coal gasification combined power generation process with zero carbon emission, the process comprising: pressurizing air for performing air separation to obtain liquid oxygen and liquid nitrogen, wherein the liquid oxygen is used for gasification and power generation, the liquid nitrogen is applied as the coolant for the gasification and power generation, the liquid nitrogen and a part of liquid oxygen stored during the valley period with low electricity load are provided for use during the peak period with high electricity load; the pulverized coal delivered under pressure and high-pressure oxygen enter a coal gasification furnace for gasification, so as to generate high-temperature fuel gas, which subjects to heat exchange and purification, and then the high-pressure fuel gas enters into a combustion gas turbine along with oxygen and recyclable CO.sub.2 for burning and driving an air compressor and a generator to rotate at a high speed; the air compressor compresses the air to a pressure of 0.40.8 MPa, and the generator generates electricity; the high-temperature combustion flue gas performs the supercritical CO.sub.2 power generation, its coolant is liquid oxygen or liquid nitrogen; the heat exchanged combustion fuel gas subsequently perform heat exchange with liquid nitrogen, the liquid nitrogen vaporizes to drive a nitrogen turbine generator for generating electricity, the cooled flue gas is dehydrated and distilled to separate CO.sub.2, a part of CO.sub.2 is used for circulation and temperature control, and another portion of CO.sub.2 is sold outward as liquid CO.sub.2 product. The power generation process provided by the present disclosure not only solves the difficult problems of high water consumption, low power generation efficiency and small range of peak load adjustment capacity of the existing IGCC technology; but also can compress air with high unit volume for energy storage with a high conversion efficiency, and greatly reduce load of the air compressor, thereby perform CO.sub.2 capture and utilization with low-cost, zero NO.sub.x emission and discharging fuel gas at a normal temperature, and significantly improve the power generation efficiency.

A syngas cooler system includes a pressure vessel, a conduit, a plenum, a plenum, a conduit, and a bellows assembly. The pressure vessel includes a throat and a dome adjacent to the throat. The throat includes an area of excess heat, and the dome includes an area of deficient heat. The plenum extends between the throat and the bellows assembly. The bellows assembly is coupled at least partially within the dome. The conduit is coupled to the plenum for channeling a flow of purge fluid from external to the pressure vessel into the plenum such that purge fluid transfers heat from the area of excess heat into the area of deficient heat to facilitate reducing temperature differential stresses within the dome and the pressure vessel.

The present disclosure relates to cogeneration of power and one or more chemical entities through operation of a power production cycle and treatment of a stream comprising carbon monoxide and hydrogen. A cogeneration process can include carrying out a power production cycle, providing a heated stream comprising carbon monoxide and hydrogen, cooling the heated stream comprising carbon monoxide and hydrogen against at least one stream in the power production cycle so as to provide heating to the power production cycle, and carrying out at least one purification step so as to provide a purified stream comprising predominately hydrogen. A system for cogeneration of power and one or more chemical products can include a power production unit, a syngas production unit, one or more heat exchange elements configured for exchanging heat from a syngas stream from the syngas production unit to a stream from the power production unit, and at least one purifier element configured to separate the syngas stream into a first stream comprising predominately hydrogen and a second stream.

The purpose of the present invention is to provide a furnace wall in which a throat section with a smaller channel diameter than other regions can be formed using all peripheral wall tubes. Provided is a furnace wall comprising: a plurality of peripheral wall tubes (142), which are disposed so as to form a cylindrical shape when aligned in one direction and through the interior of which cooling water flows; and fins (140) that connect neighboring peripheral wall tubes (142) in an airtight manner. In a throat section in which the diameter of a horizontal cross-section of the cylindrical shape is reduced in comparison to other regions, the peripheral wall tubes (142) are disposed so as to be in mutual contact and the fins (140) are disposed on the inner circumferential sides of the cylindrical shapes.

This IGCC plant is provided with an ASU which separates oxygen gas and nitrogen gas from air, a coal gasification furnace which uses an oxidizing agent to gasify coal, and a gas turbine which is driven by the combustion gas resulting from burning a gas generated by means of the coal gasification furnace. This IGCC plant control device (50) is provided with an air separation amount determination unit (52) which determines the production amount of nitrogen gas produced by the ASU depending on the operating load of the IGCC plant, and supplies to the coal gasification furnace the entire amount of oxygen gas generated as a byproduct in response to the determined nitrogen gas production amount. By this means, the IGCC plant can minimize blow-off of oxygen gas produced from the air.

The present disclosure relates to cogeneration of power and one or more chemical entities through operation of a power production cycle and treatment of a stream comprising carbon monoxide and hydrogen. A cogeneration process can include carrying out a power production cycle, providing a heated stream comprising carbon monoxide and hydrogen, cooling the heated stream comprising carbon monoxide and hydrogen against at least one stream in the power production cycle so as to provide heating to the power production cycle, and carrying out at least one purification step so as to provide a purified stream comprising predominately hydrogen. A system for cogeneration of power and one or more chemical products can include a power production unit, a syngas production unit, one or more heat exchange elements configured for exchanging heat from a syngas stream from the syngas production unit to a stream from the power production unit, and at least one purifier element configured to separate the syngas stream into a first stream comprising predominately hydrogen and a second stream.

A method of operation of a thermal power plant having an air separation system with a plurality of air storage unit (ASU) compressors and a liquid oxygen/liquid air (LOX/LA) storage facility for oxyfuel firing of fossil fuel and a power plant having a control system to perform the same are described. The method is characterized by the step of controlling the net power output of the plant in response to short term variations in grid demanded net plant output by dynamically adjusting the works power of the ASU compressors preferably in conjunction with co-ordinated changes in firing demand. The method is in particular a method to produce an improved primary and secondary response to transient changes in grid demand and to provide accurate response to load dispatch ramps.

A method of start-up for a gasification system includes establishing a flow of a start-up fuel external to the gasifier prior to ignition of the gasifier. The method also includes establishing a start-up liquid feed external to the gasifier during gasifier start-up. The method further includes channeling the start-up liquid feed and the start-up fuel to the gasifier during gasifier start-up.