1026results about "Direct carbon-dioxide mitigation" patented technology

The present invention provides methods and system for power generation using a high efficiency combustor in combination with a CO2 circulating fluid. The methods and systems advantageously can make use of a low pressure ratio power turbine and an economizer heat exchanger in specific embodiments. Additional low grade heat from an external source can be used to provide part of an amount of heat needed for heating the recycle CO2 circulating fluid. Fuel derived CO2 can be captured and delivered at pipeline pressure. Other impurities can be captured.

A low or no pollution engine is provided for delivering power for vehicles or other power applications. The engine has an air inlet which collects air from a surrounding environment. At least a portion of the nitrogen in the air is removed. The remaining gas is primarily oxygen, which is then routed to a gas generator. The gas generator has inputs for the oxygen and a hydrocarbon fuel. The fuel and oxygen are combusted within the gas generator, forming water and carbon dioxide. The combustion products are then expanded through a power generating device, such as a turbine or piston expander to deliver output power for operation of a vehicle or other power uses. The combustion products are then passed through a condenser where the steam is condensed and the carbon dioxide is collected or discharged. A portion of the water is routed back to the gas generator. The carbon dioxide is compressed and delivered to a terrestrial formation from which return of the CO2 into the atmosphere is inhibited.

A carbon dioxide separation system includes a compressor for receiving an exhaust gas comprising CO2 and generate a compressed exhaust gas and a separator configured to receive the compressed exhaust gas and generate a CO2 lean stream. The separator includes a first flow path for receiving the compressed exhaust gas, a second flow path for directing a sweep fluid therethrough, and a material with selective permeability of carbon dioxide for separating the first and the second flow paths and for promoting carbon dioxide transport therebetween. The system further includes an expander coupled to the compressor for receiving and expanding the CO2 lean stream to generate power and an expanded CO2 lean stream.

An oxy-combustor is provided to combust oxygen with gaseous low heating value fuel. A compressor upstream of the combustor compresses the fuel. The combustor produces a drive gas including steam and carbon dioxide as well as other non-condensable gases in many cases, which pass through a turbine to output power. The drive gas can be recirculated to the combustor, either through the compressor, the oxygen inlet or directly to the combustor. Recirculation can occur before or after a condenser for separation of a portion of the water from the carbon dioxide. Excess carbon dioxide and steam is collected from the system. The turbine, combustor and compressor can be derived from an existing gas turbine with fuel and air / oxidizer lines swapped.

Ultra cleaning of combustion gas to near zero concentration of residual contaminants followed by the capture of CO2 is provided. The high removal efficiency of residual contaminants is accomplished by direct contact cooling and scrubbing of the gas with cold water. The temperature of the combustion gas is reduced to 0-20 degrees Celsius to achieve maximum condensation and gas cleaning effect. The CO2 is captured from the cooled and clean flue gas in a CO2 absorber (134) utilizing an ammoniated solution or slurry in the NH3—CO2H2O system. The absorber operates at 0-20 degrees Celsius. Regeneration is accomplished by elevating the pressure and temperature of the CO2-rich solution from the absorber. The CO2 vapor pressure is high and a pressurized CO2 stream, with low concentration of NH3 and water vapor is generated. The high pressure CO2 stream is cooled and washed to recover the ammonia and moisture from the gas.

There is provided a process for the capture and sequestration of carbon dioxide that would otherwise enter the atmosphere and contribute to global warming and other problems. CO2 capture is accomplished by reacting carbon dioxide in flue gas with an alkali metal carbonate, or a metal oxide, particularly containing an alkaline earth metal or iron, to form a carbonate salt. A preferred carbonate for CO2 capture is a dilute aqueous solution of additive-free (Na2CO3). Other carbonates include (K2CO3) or other metal ion that can produce both a carbonate and a bicarbonate salt. Examples of suitable metal oxides include several alkaline earths including CaO and MgO. The captured CO2 is preferably sequestered using any available mineral or industrial waste that contains calcium magnesium or iron in non-carbonate forms, or iron in the Fe+2 oxidation state.

Carbon dioxide is separated from a feed gas, preferably derived from flue gas from an oxyfuel combustion process, in a membrane separation system to produce separated carbon dioxide gas which is fed to the oxyfuel combustion process to improve the performance of the process.

A method of remediating and recovering energy from combustion products from a fossil fuel power plant having at least one fossil fuel combustion chamber, at least one compressor, at least one turbine, at least one heat exchanger and a source of oxygen. Combustion products including non-condensable gases such as oxygen and nitrogen and condensable vapors such as water vapor and acid gases such as SOX and NOX and CO2 and pollutants are produced and energy is recovered during the remediation which recycles combustion products and adds oxygen to support combustion. The temperature and / or pressure of the combustion products are changed by cooling through heat exchange with thermodynamic working fluids in the power generation cycle and / or compressing and / or heating and / or expanding the combustion products to a temperature / pressure combination below the dew point of at least some of the condensable vapors to condense liquid having some acid gases dissolved and / or entrained and / or directly condense acid gas vapors from the combustion products and to entrain and / or dissolve some of the pollutants while recovering sensible and / or latent heat from the combustion products through heat exchange between the combustion products and thermodynamic working fluids and / or cooling fluids used in the power generating cycle. Then the CO2, SO2, and H2O poor and oxygen enriched remediation stream is sent to an exhaust and / or an air separation unit and / or a turbine.

A gas turbine system is configured to inhibit release of carbon dioxide to the atmosphere in such a manner that methane is combusted with oxygen that has been separated from air by an oxygen generator to allow an oxygen combustion type gas turbine to be driven. Carbon dioxide emitted from the turbine is fed under pressure into an underground coal bed along with an air component after separating the oxygen from the air and fixed into the coal bed, and the coal bed methane is collected above the ground by a gas drive action of the gas and supplied to the gas turbine as fuel.

A power generation system includes first and second turbines. The first turbine including a low-pressure compressor (14) and a high-pressure compressor (16). A combustion chamber (22) combusts compressed oxidant and a fuel stream to generate a hot flue gas (31). The first turbine further includes a high-pressure expander (20) for receiving the flue gas and generating a CO2 rich exhaust gas. A low-pressure expander (22) generates a first final exhaust (52) and electrical energy. A CO2 separation system receives exhaust gas (38) and provides a CO2 lean gas fed to low-pressure expander (22). The second turbine including a compressor section (64) configured to discharge a recycle stream (71) from a high pressure compressor (70) to a second combustion chamber (72) and supply a split stream (84) from a low-pressure compressor (68) to high pressure compressor (16) of the first turbine.

A semi-closed combined cycle power system 100 is provided which can also convert an open combined cycle gas turbine 10 into a non-polluting zero emissions power system. The prior art open combined cycle gas turbine 10 includes a compressor 20 which compresses air A' and combusts the air A' with a fuel, such as natural gas. The products of combustion and the remaining portions of the air form the exhaust E' which is expanded through the turbine 40. The turbine 40 drives the compressor 20 and outputs power. The exhaust E' exits the turbine 40 and then can optionally be routed through a heat recovery steam generator 50 to function as a combined cycle. According to this invention, the exhaust E' is not emitted into the atmosphere, but rather is routed to a divider 110. The divider 110 includes two outlets for the exhaust E' including a return duct 120 and a separation duct 130 which both receive a portion of the exhaust E'. The return duct 120 routes a portion of the exhaust E' back to the compressor 20. Before reaching the compressor 20, an oxygen duct 150 adds additional oxygen to the exhaust E' to form a gas mixture C which includes CO2 and steam from the exhaust E' and oxygen from the oxygen duct 150. This gas mixture C has characteristics which mimic those of air, so that the compressor 20 need not be modified to effectively compress the gas mixture C. The gas mixture C is compressed within the compressor 20 and routed to the combustor 30 where the fuel combusts with the oxygen of the gas mixture C' and produces exhaust E' which is substantially entirely CO2 and steam. This exhaust E' is routed through the turbine 40 and expanded to drive the compressor 20 and output power. The exhaust E' exits the turbine 40 and is routed back to the divider 110, preferably by way of a heat recovery steam generator 50 or other heat removal device, so that the semi-closed cycle operates as a combined cycle power system 100. The divider 110 directs a portion of the exhaust E' to a separation duct 130 which leads to a condenser 140. In the condenser 140 the exhaust E' is separated by condensation of the steam / water portion of the exhaust and removal of the remaining CO2 as gas from the condenser 140. The only exhaust from the semi-closed power system 100 is water and CO2 from the condenser. The CO2 exhaust is substantially pure and ready for appropriate further handling and disposal. Hence, no pollutants are emitted from the semi-closed power system 100. The return duct 120 can

An apparatus and method for absorbing and recovering carbon dioxide from flue gas using ammonia water as an absorbent, including an absorption column and a circulation cooler connected to the absorption column so that a high-temperature absorbent is recovered from the absorption column, cooled to a preset temperature, and then supplied again into the absorption column, in order to dissipate absorptive heat generated when carbon dioxide is absorbed from the flue gas.

The present invention provides methods and system for power generation using a high efficiency combustor in combination with a CO2 circulating fluid. The methods and systems advantageously can make use of a low pressure ratio power turbine and an economizer heat exchanger in specific embodiments. Additional low grade heat from an external source can be used to provide part of an amount of heat needed for heating the recycle CO2 circulating fluid. Fuel derived CO2 can be captured and delivered at pipeline pressure. Other impurities can be captured.

A gas cleaning system, which is operative for cleaning a process gas containing carbon dioxide and sulphur dioxide, comprises a combined cooling and cleaning system (16), and a CO2-absorber. The combined cooling and cleaning system (16) comprises a first gas-liquid contacting device (50) located upstream of the CO2-absorber and operative for cooling the process gas by means of a cooling liquid, and for absorbing into the cooling liquid sulphur dioxide of the process gas, such that a cooling liquid containing sulphate is obtained. The combined cooling and cleaning system (16) further comprises a second gas-liquid contacting device (94) located downstream of the CO2-absorber and operative for removing ammonia from the process gas, which has been treated in the CO2-absorber, by means of bringing the process gas containing ammonia into contact with the cooling liquid containing sulphate.

The present invention relates to methods and systems for controlling a combustion reaction and the products thereof. One embodiment includes a combustion control system having an oxygenation stream substantially comprising oxygen and CO2 and having an oxygen to CO2 ratio, then mixing the oxygenation stream with a combustion fuel stream and combusting in a combustor to generate a combustion products stream having a temperature and a composition detected by a temperature sensor and an oxygen analyzer, respectively, the data from which are used to control the flow and composition of the oxygenation and combustion fuel streams. The system may also include a gas turbine with an expander and having a load and a load controller in a feedback arrangement.

A method for separation of CO2 from the combustion gas from a thermal power plant fired with fossil fuel, wherein the combustion gas from the thermal power plant is used as cooled, compressed and reheated by combustion of natural gas in a combustion chamber to form an exhaust gas, where the exhaust gas is cooled an brought in contact with an absorbent absorbing CO2 from the exhaust gas to form a low CO2 stream and an absorbent with absorbed CO2, and where the low CO2 stream is heated by means of heat exchanges against the hot exhaust gas leaving the combustion chamber before it is expanded in turbines, is described. A plant for performing the method and a combined plant is also described.

Disclosed herein is a power generation process in which a portion of the carbon dioxide generated by gaseous fuel combustion is recycled back to the power generation process, either pre-combustion, post-combustion, or both. The power generation process of the invention may be a combined cycle process or a traditional power generation process. The process utilizes sweep-based membrane separation.

A combustor apparatus is provided, comprising a mixing arrangement for mixing a carbonaceous fuel with enriched oxygen and a working fluid to form a fuel mixture. A combustion chamber is at least partially defined by a porous perimetric transpiration member, at least partially surrounded by a pressure containment member. The combustion chamber has longitudinally spaced apart inlet and outlet portions. The fuel mixture is received by the inlet portion for combustion within the combustion chamber at a combustion temperature to form a combustion product. The combustion chamber directs the combustion product longitudinally toward the outlet portion. The transpiration member is configured to substantially uniformly direct a transpiration substance therethrough toward the combustion chamber, such that the transpiration substance is directed to flow helically about the perimeter and longitudinally between the inlet and outlet portions, for buffering interaction between the combustion product and the transpiration member. Associated systems are also provided.

A combustor apparatus is provided, comprising a mixing arrangement for mixing a carbonaceous fuel with enriched oxygen and a working fluid to form a fuel mixture. A combustion chamber is at least partially defined by a transpiration member. The transpiration member is at least partially surrounded by a pressure containment member. The combustion chamber has opposed inlet and outlet portions. The inlet portion of the combustion chamber is configured to receive the fuel mixture for the fuel mixture to be combusted at a combustion temperature. The combustion chamber is further configured to direct the resulting combustion product toward the outlet portion. The transpiration member directs a transpiration substance therethrough toward the combustion chamber for buffering interaction between the combustion product and the transpiration member. Associated systems, apparatuses, and methods are also provided.

Complementary metal oxide semiconductor (CMOS) static random access memory (SRAM) cells include at least a first inverter formed in a fin-shaped pattern of stacked semiconductor regions of opposite conductivity type. In some of these embodiments, the first inverter includes a first conductivity type (e.g., P-type or N-type) MOS load transistor electrically coupled in series with a second conductivity type (e.g., N-type of P-type) MOS driver transistor. The first inverter is arranged so that active regions of the first conductivity type MOS load transistor and the second conductivity type driver transistor are vertically stacked relative to each other within a first portion of a vertical dual-conductivity semiconductor fin structure. This fin structure is surrounded on at least three sides by a wraparound gate electrode, which is configured to modulate conductivity of both the active regions in response to a gate signal.

A system and method for biomass pyrolysis utilizing chemical looping combustion of a produced char to capture carbon dioxide is disclosed. The system includes a biomass pyrolysis reactor, a char combustor, and oxidation reactor and a separator for separating carbon dioxide from flue gas produced by the char combustion. The pyrolysis reactor pyrolyzes biomass in the presence of reduced metal oxide sorbents producing char and pyrolysis oil vapor. The char is separated and combusted in the char combustor, in the presence of oxidized metal oxide sorbents, into a gaseous stream of carbon dioxide and water vapor. The carbon dioxide and water are separated so that a stream of carbon dioxide may be captured. The oxidation reactor oxidizes, in the presence of air, a portion of reduced metal oxide sorbents into oxidized metal oxide sorbents that are looped back to the char combustor to provide oxygen for combustion. A second portion of the reduced metal oxide sorbents is recycled from the char combustor to the pyrolysis reactor to provide heat to drive the pyrolysis. Pyrolysis oil upgrading catalyst particles may be used in addition to the metal oxide sorbents as heat energy carrier particles to improve the quality of the pyrolysis oil vapors produced in the pyrolysis reactor. Also, the metal oxide sorbents may have metals incorporated therein which serve to upgrade the pyrolysis vapors produced during pyrolysis. Non-limiting examples of such metals include Ni, Mo, Co, Cr, W, Rh, Ir, Re, and Ru.

A power generation system includes a first turbine system. The first turbine system includes a first compressor section comprising at least two stages. The two stages includes a first low pressure compressor fluidly coupled to a first high pressure compressor configured to supply a first portion of compressed oxidant and a second portion of compressed oxidant A first combustion chamber is configured to combust said first portion of compressed oxidant and a first fuel stream comprising carbon-based fuels and to generate a first hot flue gas. The first turbine system further includes a first expander section having an inlet for receiving said first hot flue gas and generating a first expanded exhaust gas rich in CO2. The first high-pressure expander is fluidly coupled to a first low-pressure expander configured to generate a first exhaust and electrical energy. A CO2 separation system is fluidly coupled to the high-pressure expander for receiving said first expanded exhaust gas from said first high-pressure expander and provide a CO2 lean gas that is then fed to said first low-pressure expander. The power generation system also includes a second turbine system including a second compressor section comprising at least two stages. The two stages includes a second low-pressure compressor fluidly coupled to a second high pressure compressor, wherein said high pressure compressor is configured to receive said second portion of compressed oxidant. A second combustion chamber is configured to combust a second fuel stream comprising carbon-based fuels and to generate a second hot flue gas and a second expander section is configured to receive said second hot flue gas and to generate a second final exhaust and electrical energy. The second compressor section is configured to receive said second final exhaust comprising carbon dioxide and to discharge a recycle stream from said second high pressure compressor to said second combustion chamber and a split stream from said second low-pressure compressor to said first high pressure compressor.

An air pollution control apparatus according to an embodiment of the present invention includes: a stack that discharges flue gas discharged from a boiler outside; a blower that is provided downstream of the stack and draws in the flue gas; and a CO2 recovering apparatus that recovers CO2 in the flue gas drawn in by the blower. The stack includes a controlling unit that suppresses release of the flue gas outside from the stack and suppresses inflow of atmosphere to the stack, and the controlling unit is a channel forming unit that forms a serpentine channel through which the flue gas and the atmosphere in the stack flow.