Abstract: Systems and methods for crude oil separations including degassing, dewatering, desalting, and stabilization, one method including separating crude oil into a crude oil off-gas and a partially degassed crude oil output; compressing the crude oil off-gas; applying the compressed crude oil off-gas for indirect heating of the partially degassed crude oil output; further heating the partially degassed crude oil output indirectly with compressed low pressure gas; directly mixing with the partially degassed crude oil output a compressed atmospheric pressure gas; separating from the partially degassed crude oil output a low pressure gas for use in the step of further heating; and separating from the partially degassed crude oil output an atmospheric pressure gas for use in the step of directly mixing.

Abstract: Methods of Enhanced Oil Recovery (EOR) from an oil reservoir by CO2 flooding are disclosed. One method comprises producing a well stream from the reservoir; separating the well stream into a liquid phase and a gas phase with a first gas/liquid separator, wherein the gas phase comprises both CO2 gas and hydrocarbon gas; cooling the gas phase with a first cooler; compressing the gas phase using a first compressor into a compressed stream; mixing the compressed stream with an external source of CO2 to form an injection stream; and injecting the injection stream into the reservoir. Systems for EOR from an oil reservoir by CO2 flooding are also disclosed.

Abstract: Methods and systems for enhanced recovery of coal bed methane. A method includes generating a diluent gas mixture comprising N2 and CO2 in a semi-closed Brayton cycle power plant, injecting at least a portion of the diluent gas mixture into a coal bed, and recovering a mixed production gas comprising methane from the coal bed.

Abstract: A production method for natural gas according to the invention includes a step of adiabatically compressing a raw natural gas containing helium gas, a step of separating the helium gas from the raw natural gas by passing the adiabatically-compressed raw natural gas through a separation membrane unit, a step of conveying the raw natural gas from which the helium gas has been separated to a terminal through a pipe line, and a step of pressing the helium gas separated from the raw natural gas into an underground storage formation.

Abstract: A process and an apparatus are disclosed for the recovery of ethane, ethylene, propane, propylene, and heavier hydrocarbon components from a hydrocarbon gas stream in a compact processing assembly. The gas stream is cooled and divided into first and second streams. The first stream is further cooled to condense substantially all of it and is thereafter expanded to lower pressure and supplied as the top feed to an absorbing means inside the processing assembly. The second stream is also expanded to lower pressure and supplied as the bottom feed to the absorbing means. A distillation vapor stream is collected from the upper region of the absorbing means and directed into one or more heat exchange means inside the processing assembly to heat it while cooling the gas stream and the first stream.

Abstract: A process and an apparatus are disclosed for recovering ethane, ethylene, and heavier hydrocarbon components from a hydrocarbon gas stream. The stream is cooled, expanded to lower pressure, and supplied to a first fractionation tower at a mid-column feed position. A distillation liquid stream is withdrawn from the first fractionation tower below the feed position of the expanded stream, heated, and directed into a second fractionation tower that produces an overhead vapor stream and a bottom liquid stream. The overhead vapor stream is cooled to condense it, with a portion of the condensed stream directed to the second fractionation tower as its top feed and the remainder directed to the first fractionation tower at a lower column feed position. The bottom liquid stream from the second fractionation tower is cooled and directed to the first fractionation tower as its top feed.

Abstract: A system and method for removing nitrogen and producing liquefied natural gas (“LNG”) from methane without the need for external refrigeration. The invention also relates to a system and method for removing nitrogen from methane and for producing liquefied nitrogen in addition to LNG. The system and method of the invention are particularly suitable for use in recovering and processing comparatively small volumes of methane from coal mines or from flash gas captured at an LNG loading site.

Abstract: A process and an apparatus are disclosed for a compact processing assembly to remove C5 and heavier hydrocarbon components from a hydrocarbon gas stream. The hydrocarbon gas stream is expanded to lower pressure and supplied to the processing assembly between an absorbing means and a mass transfer means. A distillation vapor stream is collected from the upper region of the absorbing means and cooled in a first heat and mass transfer means inside the processing assembly to partially condense it, forming a residual vapor stream and a condensed stream. The condensed, stream is supplied to the absorbing means at its top feed point. A distillation liquid stream is collected from the lower region of the mass transfer means and directed into a second beat and mass transfer means inside the processing assembly to heat it and strip out its volatile components.

Abstract: A method for vaporizing a liquefied natural gas (LNG) stream and recovering heavier hydrocarbons from the LNG utilizing a heat transfer fluid is disclosed.

Abstract: A process for efficiently removing carbon dioxide from a hydrocarbon containing feed stream utilizing a membrane separation unit in conjunction with a heat exchanger and a carbon dioxide separation unit wherein the streams obtained in the carbon dioxide separation unit are utilized to provide the cooling effect in the heat exchanger.

Abstract: Devices and methods for retrofitting a natural gas liquids plant are contemplated to extend recovery of C3+ hydrocarbons from various feed gases to recovery of C2+ and C3+ hydrocarbons. In especially preferred aspects, dedicated C2+ exchangers are integrated to exclusively cool the feed gas to produce a cooled absorber feed and to produce two separate absorber reflux streams. During C2+ recovery, absorber reflux is provided by a portion of the residue gas and a portion of the feed gas, while during C3+ recovery absorber and distillation column reflux are provided by the distillation column overhead product.

Abstract: A method of natural gas liquefaction may include cooling a gaseous NG process stream to form a liquid NG process stream. The method may further include directing the first tail gas stream out of a plant at a first pressure and directing a second tail gas stream out of the plant at a second pressure. An additional method of natural gas liquefaction may include separating CO2 from a liquid NG process stream and processing the CO2 to provide a CO2 product stream. Another method of natural gas liquefaction may include combining a marginal gaseous NG process stream with a secondary substantially pure NG stream to provide an improved gaseous NG process stream. Additionally, a NG liquefaction plant may include a first tail gas outlet, and at least a second tail gas outlet, the at least a second tail gas outlet separate from the first tail gas outlet.

Abstract: Nitrogen is removed from a cryogenic hydrocarbon composition. A least a first portion of the cryogenic hydrocarbon composition is fed to a nitrogen stripper column. The nitrogen stripper column operates at a stripping pressure. A stripping vapour is passed into the nitrogen stripper column, comprising at least a stripping portion of a compressed process vapour that has been produced from the nitrogen-stripped liquid which has been depressurized after drawing it from the nitrogen stripper column. Reflux is generated involving partially condensing overhead vapour of the nitrogen stripper column by passing heat from the overhead vapour to an auxiliary refrigerant stream at a cooling duty. An off gas consisting of a, non-condensed, vapour fraction from the overhead vapour is discharged. The cooling duty is adjusted to regulate a heating value of the vapour fraction being discharged.

Abstract: A process and an apparatus are disclosed for a compact processing assembly to recover propane, propylene, and heavier hydrocarbon components from a hydrocarbon gas stream. The gas stream is cooled, expanded to lower pressure, and fed to an absorbing means. A first distillation liquid stream from the absorbing means is fed to a mass transfer means. A first distillation vapor stream from the mass transfer means is cooled to partially condense it, forming a residual vapor stream and a condensed stream. The condensed stream is supplied as the top feed to the absorbing means. A second distillation vapor stream from the absorbing means is heated by cooling the first distillation vapor stream, combined with the residual vapor stream, and heated by cooling the gas stream. A second distillation liquid stream from the mass transfer means is heated in a heat and mass transfer means to strip out its volatile components.

Abstract: Acid gas is removed from a feed gas in an absorber that produces a treated feed gas and a rich solvent. The treated feed gas is passed through an H2S scavenger bed, and the H2S scavenger bed is regenerated using H2S depleted acid gas flashed from the rich solvent. Most preferably, the off gas from the regenerating bed is injected into a formation.

Abstract: Provided are processes and systems for recovering hydrocarbons in a vent stream from a polymerization process. The methods and systems may include the recovery of an olefin monomer from a polymerization vent gas using ethylene refrigeration to condense and recover the olefin monomers from the vent gas. In some embodiments, the methods and systems may also include compression and condensation of polymerization vent gas, recompression of ethylene refrigerant, and use of an expander compressor turbine device for ethylene refrigeration.

Abstract: There is provided a method for recovering hydrocarbon compounds from a gaseous by-products generated in the Fisher-Tropsch synthesis reaction, the method comprising a pressurizing step in which the gaseous by-products are pressurized, a cooling step in which the pressurized gaseous by-products are pressurized to liquefy hydrocarbon compounds in the gaseous by-products, and a separating step in which the hydrocarbon compounds liquefied in the cooling step are separated from the remaining gaseous by-products.

Abstract: A compact transportable apparatus for flexibly recovering natural gas liquids from a natural gas stream feedstock includes a replaceable segment on one or more natural gas liquids transfer lines that is removable in the field without cutting the line for replacement with different replaceable part, for example, a J-T valve replacing a length of pipe, for flexibility in adjusting performance of the apparatus to match on site or changing conditions of the natural gas stream feedstock. Insulation surrounding the replaceable segment is discontinuous with insulation surrounding the remainder of the natural gas liquids transfer line in which the segment is interposed. This allows separation of the segment from such transfer line without disturbing the insulation of the remainder of that natural gas liquids transfer line if the replaceable segment is removed and replaced with a different replaceable segment.

Abstract: A process comprising receiving an ethane-rich stream comprising at least about 70 molar percent ethane, conditioning the ethane-rich stream to a temperature such that the ethane-rich stream has a vapor pressure similar to the vapor pressure of conventional liquefied natural gas (LNG), and transporting the conditioned ethane-rich stream. Included is a plurality of processing equipment configured to implement a process comprising receiving an ethane-rich stream, adjusting a temperature, a pressure, or both of the ethane-rich stream such that the ethane-rich stream has a temperature from about ?160° F. to about 0° F. and a pressure from about 14.7 pounds per square inch absolute (psia) to about 100 psia, and removing substantially all of any vapor fraction from the ethane-rich stream.

Abstract: Contemplated plant configurations and methods employ a vaporized and supercritical LNG stream at an intermediate temperature that is expanded, wherein refrigeration content of the expanded LNG is used to chill one or more recompressor feed streams and to condense a demethanizer reflux. One portion of the so warmed and expanded LNG is condensed and fed to the demethanizer as reflux, while the other portion is expanded and fed to the demethanizer as feed stream. Most preferably, the demethanizer overhead is combined with a portion of the vaporized and supercritical LNG stream to form a pipeline product.

Abstract: A process and apparatus for separating a feed containing hydrogen, carbon monoxide, methane, and optionally nitrogen to form a product gas having a desired H2:CO molar ratio and optionally a hydrogen product gas and a carbon monoxide product gas. The feed is partially condensed to form a hydrogen-enriched vapor fraction and a carbon monoxide-enriched liquid fraction. The hydrogen-enriched vapor fraction and carbon monoxide-enriched liquid fraction are combined in a regulated manner to form an admixture, which is cryogenically separated to form the product mixture having the desired H2:CO molar ratio.

Abstract: A method for removing condensable components from a fluid containing condensable components. The method involves optimizing the temperature of an initial feed stream including the condensable components through heat exchange and cooling to condense liquids there from. The liquids are removed to form a gas stream which is then compressed and after-cooled to form a high pressure stream. A portion of the high pressure stream is expanded to form a cooled low pressure stream which is mixed with the initial feed stream to augment cooling and condensation of condensable components in the initial feed stream.

Abstract: A process and an apparatus are disclosed for removing carbon dioxide from a hydrocarbon gas stream. The gas stream is cooled, expanded to intermediate pressure, and supplied to a fractionation tower at a top column feed position. The tower overhead vapor stream is compressed to higher pressure and cooled to partially condense it, forming a condensed stream. The condensed stream is expanded to intermediate pressure, used to subcool a portion of the tower bottom liquid product, then supplied to the tower at a mid-column feed position. The subcooled portion of the tower bottom liquid product is expanded to lower pressure and used to cool the compressed overhead vapor stream. The quantities and temperatures of the feeds to the fractionation tower are effective to maintain the overhead temperature of the fractionation tower at a temperature whereby the major portion of the carbon dioxide is recovered in the tower bottom liquid product.

Abstract: A method to recover NGL's at gas Pressure Reducing Stations. A first step involve providing at least one heat exchanger having a flow path for passage of high pressure natural gas with a counter current depressurized lean cold gas. A second step involves passing the high pressure natural gas stream in a counter current flow with the lean cold gas and cooling it before de-pressurization. A third step involves the expansion of the high pressure cooled gas in a gas expander. The expansion of the gas generates shaft work which is converted into electrical power by the power generator and the expanded low pressure and cold gas enters a separator where NGL's are recovered. This process results in the recovery NGL's, electricity and the displacement of a slipstream of natural that is presently used to pre-heat gas at Pressure Reduction Stations.

Abstract: A refrigeration system for condensation of carbon dioxide (CO2) in a flue gas stream, the system includes a refrigeration circuit, a flue gas treatment system that includes a flue gas compressor, a flue gas adsorption drier, and a refrigeration system for condensation of CO2; and a method for condensation of CO2 in a flue gas stream using a circulating stream of an external refrigerant.

Abstract: A process for recovery of natural gas liquids is disclosed, the process including: fractionating a gas stream comprising nitrogen, methane, ethane, and propane and other C3+ hydrocarbons into at least two fractions including a light fraction comprising nitrogen, methane, ethane, and propane, and a heavy fraction comprising propane and other C3+ hydrocarbons; separating the light fraction into at least two fractions including a nitrogen-enriched fraction and a nitrogen-depleted fraction in a first separator; separating the nitrogen-depleted fraction into a propane-enriched fraction and a propane-depleted fraction in a second separator; feeding at least a portion of the propane-enriched fraction to the fractionating as a reflux; recycling at least a portion of the propane-depleted fraction to the first separator. In some embodiments, the nitrogen-enriched fraction may be separated in a nitrogen removal unit to produce a nitrogen-depleted natural gas stream and a nitrogen-enriched natural gas stream.

Abstract: A method for recovering natural gas liquids without using cryogenic conditions, membranes, and carbon dioxide recovery solvents is provided. In one embodiment, a carbon dioxide recycle stream that comprises carbon dioxide and natural gas liquids is received. The carbon dioxide recycle stream is separated into a purified carbon dioxide recycle stream and a natural gas liquids stream. The purified carbon dioxide recycle stream comprises the carbon dioxide, and the natural gas liquids stream comprises the natural gas liquids. The carbon dioxide recycle stream, the purified carbon dioxide recycle stream, and the natural gas liquids are not subjected to cryogenic conditions, membranes, and carbon dioxide recovery solvents between being received and being separated into the purified carbon dioxide recycle stream and the natural gas liquids stream.

Abstract: A method for processing heavy hydrocarbons in an NGL recovery system is provided. In one embodiment, a feed stream is separated into a carbon dioxide recycle stream and a heavy hydrocarbon stream. The heavy hydrocarbon stream comprises carbon dioxide and natural gas liquids, and the heavy hydrocarbon stream comprises heavy hydrocarbons. The carbon dioxide recycle stream is separated into a purified carbon dioxide recycle stream and a natural gas liquids stream. The purified carbon dioxide recycle stream comprises the carbon dioxide, and the natural gas liquids stream comprises the natural gas liquids. In another embodiment, a set of process equipment comprises a first separator and a second separator. The first separator is configured to separate a feed stream into a recycle stream and a heavy hydrocarbons stream, and the second separator is configured to separate the recycle stream into a purified recycle stream and a natural gas liquids stream.

Abstract: A process and an apparatus for liquefying a portion of a natural gas stream are disclosed. The natural gas stream is cooled under pressure and divided into a first stream and a second stream. The first stream is cooled, expanded to an intermediate pressure, and supplied to a lower feed point on a distillation column. The second stream is expanded to the intermediate pressure and divided into two portions. One portion is cooled and then supplied to a mid-column feed point on the distillation column; the other portion is used to cool the first stream. The bottom product from this distillation column preferentially contains the majority of any hydrocarbons heavier than methane that would otherwise reduce the purity of the liquefied natural gas, so that the overhead vapor from the distillation column contains essentially only methane and lighter components.

Abstract: An energy-efficient method of recovering carbon dioxide (CO2) in a high-pressure liquid state from a high-pressure gas stream. The method includes cooling, condensing, and/or separating CO2 from a high-pressure gas stream in two or more separation zones and further purifying the resulting sub-critical pressure liquid CO2 streams in a third purification zone to thereby provide purified CO2. The purified liquid CO2 may be pumped to above the critical pressure for further utilization and/or sequestration for industrial or environmental purposes.

Abstract: A natural gas liquids (NGL) recovery system and method for separating NGLs from a feed gas is provided. The method includes receiving the feed gas; increasing a pressure of the feed gas by running the feed gas through a compressor connected to a gas turbine; diverting part of the feed gas from an output of the compressor and feeding the diverted part to a dryer; drying the diverted part to remove water and produce a dry gas; expanding the dry gas in a turbo-expander; separating the expanded gas into the NGL and fuel gas; and providing the fuel gas to the gas turbine as fuel without contamination.

Abstract: A method for recovering a sour natural gas liquids stream is provided. In one embodiment, a carbon dioxide recycle stream that comprises carbon dioxide, natural gas liquids, and acid gas is received. The carbon dioxide recycle stream is separated into a purified carbon dioxide recycle stream and a natural gas liquids stream. The purified carbon dioxide recycle stream comprises the carbon dioxide, and the natural gas liquids stream comprises the natural gas liquids and the acid gas. In another embodiment, a system comprises piping and a separator. The piping is configured to receive a recycle stream that comprises an injection gas, natural gas liquids, and acid gas. The separator is configured to separate the recycle stream into a purified recycle stream and a natural gas liquids stream. The purified recycle stream comprises the injection gas, and the natural gas liquids stream comprises the natural gas liquids and the acid gas.

Abstract: Provided are systems and methods for separating a purge gas recovered from a polyethylene product. The method includes recovering a polyethylene product containing one or more volatile hydrocarbons from a polymerization reactor and contacting the polyethylene product with a purge gas to remove at least a portion of the volatile hydrocarbons to produce a polymer product having a reduced concentration of volatile hydrocarbons and a purge gas product enriched in volatile hydrocarbons. The purge gas product is compressed to a pressure of 2,500 kPaa to 10,000 kPaa, and is then cooled and separated into at least a first product, a second product, and a third product. A portion of one or more of the first, second, or third products is then recycled as a purge gas, to the polymerization reactor, or to the purge gas product enriched in volatile hydrocarbons prior to compression, respectively.

Abstract: Ethane is separated from a carbon dioxide-containing feed gas in a demethanizer that receives a rich subcooled reflux stream at very low temperature. Freezing of carbon dioxide is prevented by feeding a temperature-controlled vapor portion of the feed gas to the column, wherein the temperature of the vapor portion is adjusted by routing a portion of the expander discharge through a heat exchanger in response to the tray temperature in the demethanizer. Thus, high separation efficiency is achieved at reduced, or even eliminated carbon dioxide freezing.

Abstract: A method of conditioning natural gas in preparation for storage, involves taking an existing stream of continuously flowing natural gas flowing through a gas line (12) on its way to end users and diverting a portion of the stream of continuously flowing natural gas to a storage facility through a storage diversion line (22). The pressure of the natural gas is lowered, as is the temperature by the Joule-Thompson effect. The natural gas is passed in a single pass through a series of heat exchangers (18, 28,30, 32) prior to resuming flow through the gas line (12) at the lowered pressure. The diverted natural gas is liquefied in preparation for storage by effecting a heat exchange with the natural gas.

Abstract: One embodiment of the present invention is a portable natural gas discharge system for discharging compressed natural gas into a receiving location. The system comprises a portable chassis for holding the natural gas discharge system and all subcomponents, an inlet port for receiving the natural gas at an inlet pressure higher than a pressure of the receiving location, an expansion valve for regulating pressure of the natural gas to a stable intermediate pressure, a heat exchanger for heating up the cooled natural gas stream as a result of cooling due to expansion, a regulator for regulating a flow of the heated natural gas stream through the heat exchanger and out of the portable natural gas discharge system, and a discharge port for discharging the heated natural gas stream into the receiving location.

Abstract: One embodiment of the present invention is a gas discharge system utilizing a temperature-actuated valve. The temperature-actuated valve uses a temperature-measuring device to sense the temperature of the natural gas after it pass through an expansion valve and after leaving a heat exchanger inside the discharge station. This temperature-measuring device sends a signal to a valve that is automatically actuated. If the temperature of the gas is too low, the valve is tightened, increasing the residence time in the heat exchanger and increasing the gas temperature. If the gas temperature is too high, the valve is opened, reducing the residence time in the heat exchanger, decreasing gas temperature. Using this temperature-actuated valve to control the temperature of a wet gas discharge station is also disclosed.

Abstract: An incoming compressed gas, such as natural gas, is pre-cooled and the gas separated from any included liquid. The pre-cooled and separated gas is expanded using an expander to rapidly reduce pressure and corresponding temperature, as well as remove any components solidified by the temperature drop. An output stream from the expander, combined with other streams, is again gas/liquid separated. The output separated gas stream is sent through another expansion and gas/liquid separation, separating one or more other components, such that a final output gas is achieved. In the case of natural gas, the final output is, for example, methane, which may be fed back to cool the incoming gas prior to end use of the methane.

Abstract: A method for recovering C2 and higher weight hydrocarbons, or alternatively C3 and higher weight hydrocarbons, from low pressure gas, wherein the method avoids the need to significantly compress contaminated low pressure gas in most cases, and is robust in response to pressure and temperature variations in the low pressure gas feed.

Abstract: Methods of reducing the concentration of low boiling point components in liquefied natural gas are disclosed. The methods involve dynamic decompression of the liquefied natural gas and one or more pre-fractionation vessels. Particular embodiments are suited for recovering helium and/or nitrogen enriched streams from a liquefied natural gas stream.

Abstract: Systems and methods for processing a hydrocarbon mixture wherein heat is generated from compression of recovered natural gas vapors and used to provide a heating medium for a heat exchanger.

Abstract: A method comprising receiving a hydrocarbon feed stream, separating the hydrocarbon feed stream into a heavy hydrocarbon rich stream and a carbon dioxide recycle stream, separating the carbon dioxide recycle stream into a natural gas liquids (NGL) rich stream and a purified carbon dioxide recycle stream, and injecting the purified carbon dioxide recycle stream into a subterranean formation. Included is a method comprising selecting a first recovery rate for a NGL recovery process, estimating the economics of the NGL recovery process based on the first recovery rate, selecting a second recovery rate that is different from the first recovery rate, estimating the economics of the NGL recovery process based on the second recovery rate, and selecting the first recovery rate for the NGL recovery process when the estimate based on the first recovery rate is more desirable than the estimate based on the second recovery rate.

Abstract: An LNG facility employing an optimized heavies removal system. The optimized heavies removal system can comprise at least one distillation column and at least two separate heat exchangers. The heat exchangers can be operable to heat a liquid stream withdrawn from a distillation column to thereby provide predominantly vapor and/or liquid streams that can be reintroduced into the column.

Abstract: A method and apparatus for conditioning imported liquefied natural gas to conform to a particular pipeline heating value specification and recovery of liquefied petroleum gas or natural gas liquids from liquefied natural gas are disclosed. An input stream containing liquefied natural gas is split into a direct stream and a bypass stream. The direct stream is heated in a cross-exchanger to produce a heated rich liquefied natural gas stream, which is split into a primary column feed and a secondary column feed. At least a major portion of the secondary column feed is vaporized to produce a vaporized secondary column feed, which is expanded in an expander to produce a vaporized and expanded secondary column feed. A top feed, the primary column feed, and the vaporized and expanded secondary column feed are fractionated to produce an overhead product stream and a bottom product stream. The overhead product stream is compressed in a compressor coupled to the expander.

Abstract: A system and method for utilizing stranded natural gas produced by one wellsite or facility site at a second wellsite or facility site as natural gas in a fuel supply system to reduce the dependency of diesel fuel in operating equipment at the second wellsite or facility site. The system and method includes transporting the gas collected at the first wellsite or facility site to the second wellsite or facility site as a gas mixture of natural gas and hydrocarbon liquids in vapor form at a pressure and temperature to prevent drop out of the hydrocarbon liquids during transport. At the second wellsite or facility site, the gas mixture is processed to recover the hydrocarbon liquids and to provide a compressed natural gas free of the hydrocarbon liquids to a fuel system for combustion by wellsite or facility site equipment.

Abstract: The invention relates to an apparatus (100) for working up a hydrogen- and methane-comprising stream (1.1), which comprises the following components: (i) at least one heat exchanger (KS1) for cooling a stream (1.1) to be worked up; (ii) at least one separation unit (A, A1, A2, A2?) for purifying the stream (3) to be worked up to give a stream (5) rich in hydrogen and methane; (iii) at least one cooling unit (KS2) for cooling the stream (5) rich in hydrogen and methane; and (iv) at least one cryogenic gas separation unit (KS3) for separating the stream (6) rich in hydrogen and methane into at least one hydrogen-rich stream (7) and at least one methane-rich stream (8, 9). The invention further relates to a process for working up a stream of material.

Abstract: Provided are processes and systems for recovering hydrocarbons in a vent stream from a polymerization process. The methods and systems may include the recovery of an olefin monomer from a polymerization vent gas using ethylene refrigeration to condense and recover the olefin monomers from the vent gas. In some embodiments, the methods and systems may also include compression and condensation of polymerization vent gas, recompression of ethylene refrigerant, and use of an expander compressor turbine device for ethylene refrigeration.

Abstract: The present invention relates to a method of liquefying a hydrocarbon stream such as a natural gas stream, the method at least comprising the steps of: supplying a partly condensed feed stream (10) having a pressure above 60 bar to a first separator (2) wherein it is separated into a gaseous stream (20) and a liquid stream (30); expanding the liquid stream (30) and the gaseous stream (20) and subsequently feeding them into the distillation column (3); removing from the distillation column (3) a gaseous overhead stream (80), partially condensing it, feeding it (90) into a second separator (8) thereby obtaining a liquid stream (100) and a gaseous stream (110), feeding the liquid stream (100) into the distillation column (3) and liquefying the gaseous stream (110) thereby obtaining a liquefied stream (200); wherein the gaseous overhead stream (80) is partially condensed by heat exchanging against the expanded gaseous stream (60) before it (70) is fed into the distillation column (3); and wherein the gaseous stre

Abstract: The various embodiments herein provide a method and system for a process configuration with internal refrigeration for light gas and a process configuration with external refrigeration system for rich gas. The self-refrigeration unit comprising an open-closed cycle of refrigeration provides a required refrigeration load and the external refrigeration unit provides a refrigeration load corresponding to variations in a feed composition percentage. The configuration with internal refrigeration system utilizes a slip stream from or near the bottom of the demethanizer as a mixed refrigerant.

Abstract: A method of altering the heating value of a liquefied natural gas by adding higher heating value components is disclosed. A portion of the liquefied natural gas is used to cool the higher heating value component stream prior to combining the higher heating value components with the liquefied natural gas to obtain a combined stream having a heating value greater than the liquefied natural gas.