Abstract: A CO2 recovery apparatus is provided with: a CO2 absorption tower for bringing exhaust gas into contact with a CO2 absorbing liquid and making the CO2 absorbing liquid absorb the CO2 contained in the exhaust gas; a CO2 absorbing liquid regeneration tower for heating the CO2 absorbing liquid with steam and releasing CO2 from the CO2 absorbing liquid and regenerating the CO2 absorbing liquid; a flowmeter for determining the flow rates of the exhaust gas introduced into the CO2 absorption tower; and a control unit for classifying the flow rates of the exhaust gas into multiple flow rate ranges, and controlling the flow rate of the CO2 absorbing liquid supplied to the CO2 absorption tower and the flow rate of steam supplied to the CO2 absorbing liquid regeneration tower on the basis of prescribed set load values which have been previously established in accordance with the multiple flow rate ranges.

Abstract: A desulfurization absorption tower, a method for setting up the same and a method for operating the same. The tower may include an internal anti-corrosion layer that may be used for contacting the flue gas and the desulfurization absorption liquid, may define the tower chamber, and may include stainless steel plate whose thickness is 1.0 mm to 6.0 mm. The tower body may include an external supporting layer that may be used for supporting the anti-corrosion layer and may include carbon steel. The supporting layer and the anti-corrosion layer may be designed to jointly bear a load, wherein the supporting layer may be designed to bear a large part of the load, and the anti-corrosion layer may be designed to bear a small part of the load.

Abstract: A desulfurization absorption tower, a method for setting up the same and a method for operating the same. The tower may include an internal anti-corrosion layer that may be used for contacting the flue gas and the desulfurization absorption liquid, may define the tower chamber, and may include stainless steel plate whose thickness is 1.0 mm to 6.0 mm. The tower body may include an external supporting layer that may be used for supporting the anti-corrosion layer and may include carbon steel. The supporting layer and the anti-corrosion layer may be designed to jointly bear a load, wherein the supporting layer may be designed to bear a large part of the load, and the anti-corrosion layer may be designed to bear a small part of the load.

Abstract: The present invention relates to an absorbent, an absorbent system and a process for removing acidic gas such as CO2 from exhaust gases from fossil fuel fired power stations, from natural gas streams, from blast furnace oven off-gases in iron/steel plants, from cement plant exhaust gas and from reformer gases containing CO2 in mixtures with H2S and COS. The liquid absorbent, a mixture of amine and amino acid salt is contacted with a CO2 containing gas in an absorber and CO2 in the gas stream is absorbed into the liquid. The absorbed CO2 forms more than one type of solid precipitate in the liquid at different absorption stages. In a first absorption stage solid precipitate of amine bicarbonate is formed and is withdrawn as slurry from the bottom of a first absorber section. In a second absorption stage solid precipitate of alkali metal bicarbonate is formed and withdrawn as slurry at the bottom of a second absorber section.

Abstract: The disclosure includes a method, comprising passing a fluid into a co-current contactor, passing a solvent into the co-current contactor, dividing the solvent into solvent droplets having a first average droplet size, placing the fluid in contact with the solvent droplets to create a combined stream, coalescing at least a portion of the solvent droplets to create solvent droplets having a second average droplet size, wherein the second average droplet size is greater than the first average droplet size, and separating the fluid and the solvent.

Abstract: A system and a method for industrial plant or utility plant flue gas desulfurization, with zero waste water liquid discharge from a wet flue gas desulfurization system utilized therein, are disclosed herein. The wet flue gas desulfurization system is supplied an absorption liquid for contact with a flue gas to absorb flue gas acid gases. Waste water from the wet flue gas desulfurization system is heated under pressure in a heat exchanger to produce heated waste water, which is supplied to a flash vessel to produce steam. The produced steam is supplied to the flue gas upstream of a particulate collection system and the wet flue gas desulfurization system, supplied to the flue gas upstream of the wet flue gas desulfurization system, or supplied to absorption liquid circulated to the wet flue gas desulfurization system.

Abstract: A process for producing carbon dioxide for use in hydrocarbon recovery includes the steps of transporting a combustion turbine generator to an oilfield, operating the combustion turbine generator in combined cycle so as to produce steam, power and carbon dioxide, injecting the carbon dioxide into a reservoir located within the oilfield so as to produce hydrocarbons from the reservoir, and transmitting the power to a utility or for use by equipment at the oilfield. The combustion turbine generator has a size of no more than 175 megawatts. The combustion turbine generator operating in combined cycle has a heat rate of between 7,500 to 12,000 BTUs per hour. The carbon dioxide is compressed prior to be injected into the reservoir.

Abstract: Systems and methods for separating CO2 and H2S from a natural gas stream are provided herein. The system includes a first loop of co-current contacting systems configured to remove H2S and CO2 from a natural gas stream and a second loop of co-current contacting systems configured to remove the H2S from the CO2.

Abstract: A filtration liquid tank (100) for a dedusting device and a dedusting device with the same are provided. The filtration liquid tank (100) includes a tank body (1) formed with an inlet and an outlet; a cyclone separator (3) disposed within the tank body (1) and in communication with the outlet, defining a cyclone separation chamber therein, and formed with a cyclone inlet (31) in communication with the cyclone separation chamber; and a water pressing assembly (2) disposed within the tank body (1) and in communication with the inlet, and configured to guide an airstream entering from the inlet towards a filtration medium and produce a circumferential motion, the airstream filtered by the filtration medium being exhausted from the outlet.

Abstract: Disclosed herein is a system for recovering olefins from a vent stream comprising an absorber; and a stripper; where the absorber and the stripper are in a recycle loop; and where the absorber is operative to treat a vent stream with a solvent to remove more than 99 wt % of a halogenated by-product contained in the vent stream and to recover 90 to 95 wt % of olefin molecules present in the vent stream; and where the stripper is operative to remove more than 99 wt % of the halogenated by-products present in the solvent; and where the solvent is recycled to the absorber.

Abstract: A wet desulfurization apparatus which removes sulfur oxides in flue gas from a boiler 11 includes a mist collection/agglomeration apparatus which is provided on a downstream side of the desulfurization apparatus and forms agglomerated SO3 mist by causing particles of SO3 mist contained in flue gas 12B from the wet desulfurization apparatus to be bonded together and have bloated particle sizes; a CO2 recovery apparatus constituted by a CO2 absorption tower having a CO2 absorption unit which removes CO2 contained in flue gas by being brought into contact with a CO2 absorbent and an absorbent regeneration tower which recovers CO2 by releasing CO2 from the CO2 absorbent having absorbed CO2 and regenerates the CO2 absorbent; and a mist collection unit which collects CO2 absorbent bloated mist bloated by the CO2 absorbent being absorbed by the agglomerated SO3 mist in the CO2 absorption unit.

Abstract: A system including a fluid processing system including an absorber configured to remove a component from an untreated first fluid using a lean second fluid, output a treated first fluid, and output a rich second fluid, a stripper configured to strip the component from the rich second fluid, output the lean second fluid, and output the component, a first pump configured to pump the lean second fluid into the absorber, and a hydraulic turbocharger configured to pump the lean second fluid by transferring pressure from the rich second fluid to the lean second fluid.

Abstract: Systems and methods for removing hydrogen sulfide from an ammonia stream in the NH3 purification and liquefaction stage of a conventional two-column sour water stripping system using an adsorbent bed.

Abstract: A method for continuously removing water vapor from a carrier gas is disclosed. This method includes, first, causing direct contact of the carrier gas with a liquid mixture in a separation chamber, the carrier gas condensing at a lower temperature than the water vapor. A combination of chemical effects cause the water vapor to condense, complex, or both condense and complex with the liquid mixture.

Abstract: In a natural gas dehydration system and method, a first stream of natural gas and water vapor having a first pressure and a first temperature is mixed with a second stream of natural gas and water vapor having a second, lower pressure than the first pressure and a second temperature to form a third stream of natural gas and water vapor. The pressure and temperature of the third stream is then reduced and at least part of the water is separated from the third stream to form a fourth stream of natural gas and water vapor having a lower water vapor content than the third stream. In response to a temperature of the third stream being above a predetermined temperature, causing the fourth stream to extract heat from the first stream prior mixing the first and second streams. Then, the fourth stream is flowed to a distribution pipeline or a storage system.

Abstract: A system for producing an ion concentration gradient and a temperature-responsive electrolyte material which are utilizable, for example, for efficiently converting heat energy that has been discarded into reusable energy or for efficiently recovering an acid gas, such as carbon dioxide is provided. A temperature-responsive electrolyte is used to produce an ion concentration gradient by means of a temperature gradient. The temperature-responsive electrolyte is used in the state of an aqueous solution and also in the state of a solid phase.

Abstract: A method for decontaminating a contaminated fluid stream, comprising receiving the contaminated fluid stream, distributing the contaminated fluid stream substantially equally across a plurality of separation units sharing a unitary pressure boundary, receiving a solvent stream, and co-currently contacting the contaminated fluid stream with the solvent stream in the plurality of separation units.

Abstract: A method and device for gas scrubbing, in which, in a first scrubbing step, substances of a first kind and, in a subsequent second scrubbing step, substances of a second kind are selectively washed out from the gas mixture that is made to flow in countercurrent to physically acting scrubbing agents, wherein part of the scrubbing agent that is free from substances of the first kind but laden with substances of the second kind in the second scrubbing step is used in the first scrubbing step, and so there occurs a scrubbing agent stream that is laden with substances of the first and second kinds, during the regeneration of which a partly regenerated scrubbing agent stream (semilean); that contains substances of the first and second kinds but has a lower content of substances of the first kind than the scrubbing agent stream laden in the first scrubbing step is generated.

Abstract: The present invention corresponds to a device for extracting water from the environment by means of a liquid desiccant. The device comprises a means for capturing water from the environment using a liquid desiccant, an extraction chamber, a first duct through which liquid desiccant with water flows from the capture means to the extraction chamber, a second duct through which liquid desiccant flows from the extraction chamber to the capture means, a reservoir for depositing water extracted from the liquid desiccant in the extraction chamber, a third duct through which water flows from the extraction chamber to the reservoir, a means to create a vacuum within the extraction chamber, and a control device that controls the heating element. The extraction chamber comprises a container located at the bottom of the extraction chamber, in which the water captured by the liquid desiccant is extracted and a heating element located within the container.

Abstract: A waste gas scrubbing tower includes a tower body unit, a filtration unit arranged in the tower body unit, a washing unit that introduces water from an external supply into the tower body unit. The tower body unit includes division boards that define a plurality of channels through which waste gas flows, the tower body unit including a waste gas inlet opening and a waste gas outlet opening. The filtration unit includes a plurality of filter members, which are arranged in the channels. The washing unit is operable to generate water mist curtains in the channels to wash the waste gas so that the waste gas that enters the waste gas scrubbing tower is subjected to multiple times of washing and filtration and purification.