Abstract: An apparatus and method for flow management and CO2-recovery from a CO2 containing hydrocarbon flow stream, such as a post CO2-stimulation flowback stream. The apparatus including a flow control zone, a gas separation zone, a pretreatment zone, and a CO2-capture zone. The CO2-capture zone is in fluid communication with the pretreatment zone to provide CO2-capture from a pretreated flowback gas stream and output a captured CO2-flow stream. The CO2-capture zone includes a first CO2-enricher and at least one additional CO2 enricher disposed downstream of the first CO2 enricher and in cascading relationship to provide a CO2-rich permeate stream, the CO2-capture zone further including at least one condenser to condense the enriched CO2-stream and output the captured CO2-flow stream.

Abstract: Method includes recovering a stimulating fluid, which includes transferring working fluid having the stimulating fluid from an operating site (102) to a current temporary processing facility (TPF) (110) that is located remotely with respect to the operating site in the geographical region. After purifying the working fluid at the current TPF (110), thereby providing the stimulating fluid, the stimulating fluid is transferred from the current TPF to an injection site (103) that is located remotely with respect to the current TPF and the operating site. The method also includes transporting fluid-handling equipment after a designated condition has been satisfied. The fluid-handling equipment is transported from the current TPF (110) to a new TPF (110). The recovering of the stimulating fluid, the transferring of the stimulating fluid, and the transporting of the fluid-handling equipment is repeated a plurality of times. The current and new TPFs are at different locations within the geographical region.

Abstract: Method includes recovering a stimulating fluid, which includes transferring working fluid having the stimulating fluid from an operating site (102) to a current temporary processing facility (TPF) (110) that is located remotely with respect to the operating site in the geographical region. After purifying the working fluid at the current TPF (110), thereby providing the stimulating fluid, the stimulating fluid is transferred from the current TPF to an injection site (103) that is located remotely with respect to the current TPF and the operating site. The method also includes transporting fluid-handling equipment after a designated condition has been satisfied. The fluid-handling equipment is transported from the current TPF (110) to a new TPF (110). The recovering of the stimulating fluid, the transferring of the stimulating fluid, and the transporting of the fluid-handling equipment is repeated a plurality of times. The current and new TPFs are at different locations within the geographical region.

Abstract: Thermoelectric energy storage system and an associated method are disclosed. The thermoelectric energy storage system includes a first refrigeration system, a power system, a first thermal storage unit, and a second thermal storage unit. The first refrigeration system includes a first heat exchanger, a first compressor, a second heat exchanger, and a first expander. The first heat exchanger is disposed upstream relative to the first compressor. The power system includes a third heat exchanger, a second compressor, a fourth heat exchanger, a fifth heat exchanger, and a second expander. The third heat exchanger is disposed upstream relative to the fourth heat exchanger. The fifth heat exchanger is disposed downstream relative to the second expander. The first thermal storage unit is coupled to the first heat exchanger and the fifth heat exchanger. The second thermal storage unit is coupled to the first refrigeration system and the power system.

Abstract: Thermoelectric energy storage system and an associated method are disclosed. The thermoelectric energy storage system includes a first refrigeration system, a power system, a first thermal storage unit, and a second thermal storage unit. The first refrigeration system includes a first heat exchanger, a first compressor, a second heat exchanger, and a first expander. The first heat exchanger is disposed upstream relative to the first compressor. The power system includes a third heat exchanger, a second compressor, a fourth heat exchanger, a fifth heat exchanger, and a second expander. The third heat exchanger is disposed upstream relative to the fourth heat exchanger. The fifth heat exchanger is disposed downstream relative to the second expander. The first thermal storage unit is coupled to the first heat exchanger and the fifth heat exchanger. The second thermal storage unit is coupled to the first refrigeration system and the power system.

Abstract: The subject matter disclosed herein relates to a liquefaction system. Specifically, the present disclosure relates to systems and methods for condensing a pressurized gaseous working fluid, such as natural gas, using at least one turboexpander in combination with other cooling devices and techniques. In one embodiment, a turboexpander may be used in combination with a heat exchanger using vapor compression refrigeration to condense natural gas.

Abstract: An apparatus and method for flow management and CO2-recovery from a CO2 containing hydrocarbon flow stream, such as a post CO2-stimulation flowback stream. The apparatus including a flow control zone, a gas separation zone, a pretreatment zone, and a CO2-capture zone. The CO2-capture zone is in fluid communication with the pretreatment zone to provide CO2-capture from a pretreated flowback gas stream and output a captured CO2-flow stream. The CO2-capture zone includes a flow splitter to direct a first portion of the pretreated flowback gas stream to a CO2-enricher to provide an enriched CO2-stream for mixing with a second portion of the pretreated flowback gas to form a mixed stream. The CO2-capture zone further includes at least one condenser to output the captured CO2-flow stream.

Abstract: An electrothermal energy storage and discharge system is provided including a charging cycle and a discharging cycle. The charging cycle includes a refrigeration unit and a thermal unit, and the discharging cycle includes a power unit. The refrigeration unit is driven by an excess electric power and is configured to generate a cold energy storage having a solid carbon dioxide. The thermal unit is driven by a thermal energy and is configured to generate a hot energy storage and/or provide a hot source. The power unit operates between the cold energy storage and at least one of the hot energy storage and hot source so as to retrieve the energy by producing a high pressure carbon dioxide and a hot supercritical carbon dioxide, and generating an electric energy using the hot supercritical carbon dioxide.

Abstract: An apparatus and method for flow management and CO2-recovery from a CO2 containing hydrocarbon flow stream, such as a post CO2-stimulation flowback stream. The apparatus including a flow control zone, a gas separation zone, a pretreatment zone, and a CO2-capture zone. The CO2-capture zone is in fluid communication with the pretreatment zone to provide CO2-capture from a pretreated flowback gas stream and output a captured CO2-flow stream. The CO2-capture zone includes a flow splitter to direct a first portion of the pretreated flowback gas stream to a CO2-enricher to provide an enriched CO2-stream for mixing with a second portion of the pretreated flowback gas to form a mixed stream. The CO2-capture zone further includes at least one condenser to output the captured CO2-flow stream.

Abstract: An apparatus and method for flow management and CO2-recovery from a CO2 containing hydrocarbon flow stream, such as a post CO2-stimulation flowback stream. The apparatus including a flow control zone, a gas separation zone, a pretreatment zone, and a CO2-capture zone. The CO2-capture zone is in fluid communication with the pretreatment zone to provide CO2-capture from a pretreated flowback gas stream and output a captured CO2-flow stream. The CO2-capture zone includes a first CO2-enricher and at least one additional CO2 enricher disposed downstream of the first CO2 enricher and in cascading relationship to provide a CO2-rich permeate stream, the CO2-capture zone further including at least one condenser to condense the enriched CO2-stream and output the captured CO2-flow stream.

Abstract: The subject matter disclosed herein relates to a liquefaction system. Specifically, the present disclosure relates to systems and methods for condensing a pressurized gaseous working fluid, such as natural gas, using at least one turboexpander in combination with other cooling devices and techniques. In one embodiment, a turboexpander may be used in combination with a heat exchanger using vapor compression refrigeration to condense natural gas.

Abstract: An electrothermal energy storage and discharge system is provided including a charging cycle and a discharging cycle. The charging cycle includes a refrigeration unit and a thermal unit, and the discharging cycle includes a power unit. The refrigeration unit is driven by an excess electric power and is configured to generate a cold energy storage having a solid carbon dioxide. The thermal unit is driven by a thermal energy and is configured to generate a hot energy storage and/or provide a hot source. The power unit operates between the cold energy storage and at least one of the hot energy storage and hot source so as to retrieve the energy by producing a high pressure carbon dioxide and a hot supercritical carbon dioxide, and generating an electric energy using the hot supercritical carbon dioxide.

Abstract: A method of separating carbon dioxide (CO2) from nitrogen (N2) and oxygen (O2) within a turbine engine system includes, in an exemplary embodiment, directing an air stream into an air separation unit (ASU), separating N2 from the air stream in the ASU to form an oxygen (O2) rich air stream, and directing the O2 rich air stream to the combustor to mix with a fuel for combustion forming hot combustion gases, containing O2 and CO2, which are used to rotate the turbine. The method also includes directing turbine expander exhaust gases to a heat recovery steam generator (HRSG) to create steam, directing exhaust from the HRSG to a condenser to separate water from a mixture of O2 and CO2 gases, and directing the mixture of O2 and CO2 gases to a separation system where the CO2 is separated from the O2 gases and removed from the separation system.

Abstract: A system and method for producing liquid natural gas (LNG) from a natural gas stream is presented. The system includes a moisture removal device and compressor for removing moisture from and compressing the natural gas stream. The low moisture compressed natural gas stream is cooled in a heat exchanger to discharge a cooled compressed discharge stream. A multi-phase turbo expander provides for further cooling and expansion of the cooled compressed discharge stream, generating an expanded exhaust stream comprising a mixture of a vapor comprised substantially of CH4 and a LNG/ice/solid CO2 slurry. The expanded exhaust stream is separated to generate a vapor stream comprised substantially of CH4 and a liquid natural gas/ice/solid CO2 slurry stream. Further separation of the liquid natural gas/ice/solid CO2 slurry stream generates a liquid natural gas output stream and an output stream comprised substantially of ice/solid CO2.

Abstract: A heat exchange assembly for treating carbon dioxide (CO2) is described. The heat exchange assembly includes a housing that includes an inlet, an outlet, and an inner surface that defines a cavity extending between the inlet and the outlet. The housing is configured to receive solid CO2 through the inlet. At least one heat exchange tube extends through the housing. The heat exchange tube is oriented to contact solid CO2 to facilitate transferring heat from solid CO2 to a heat exchanger fluid being channeled through the heat exchange tube to facilitate converting at least a portion of solid CO2 into liquid CO2. The heat exchange assembly is configured to recover a refrigeration value from the solid CO2 and transfer at least a portion of the recovered refrigeration value to a flue gas.

Abstract: A system and method are provided for boosting overall performance of a fuel cell while simultaneously separating a nearly pure stream of CO2 for sequestration or for use in generating electrical power to further increase overall efficiency of the process. The system and method employ a heat exchanger system configured to generate a stream of fuel that is returned to the inlet of the fuel cell anode with a higher molar concentration of carbon monoxide (CO) and hydrogen (H2) fuel than was initially present in the fuel cell anode outlet.

Abstract: A method for ammonia synthesis using a water-gas shift membrane reactor (WGSMR) is presented. The method includes carrying out a water-gas shift reaction in the WGSMR to form a first product stream and a carbon dioxide (CO2) stream, wherein the first product stream includes nitrogen (N2) and hydrogen (H2), and a molar ratio of H2 to N2 in the first product stream is about 3. The method further includes separating at least a portion of the residual CO2 in the first product stream in a CO2 separation unit to form a second product stream, and separating at least a portion of the residual CO2 and carbon monoxide (CO) in the second product stream in a methanator unit to form a third product stream. The method further includes generating an ammonia stream from the third product stream in an ammonia synthesis unit. A system for ammonia synthesis is also presented.

Abstract: A hybrid multichannel porous structure for processing between two fluid streams of different compositions includes a housing and one or more structures disposed within the cavity of the housing in a shell and tube configuration. Each structure includes a body made of a porous, inorganic material and a plurality of channels for processing an optional sweep stream. Each channel is coated with a membrane layer. A feed stream introduced into the housing is in direct contact with the structures such that a gas selectively permeates through the body and into the channels. The gas combines with the sweep stream to form a permeate that exits from each channel. The remaining feed stream forms a retentate that exits from the housing. The feed stream may consist of syngas containing hydrogen gas and the sweep stream may contain nitrogen gas. A power plant that incorporates the hybrid structure is disclosed.

Abstract: A method for separating carbon dioxide (CO2) from a gas stream is provided. The method includes cooling the gas stream in a cooling stage to form a cooled gas stream and cooling the cooled gas stream in a converging-diverging nozzle to form one or both of solid CO2 and liquid CO2. The method further includes separating at least a portion of one or both of solid CO2 and liquid CO2 from the cooled gas stream in the converging-diverging nozzle to form a CO2-rich stream and a CO2-lean gas stream. The method further includes expanding the CO2-lean gas stream in an expander downstream of the converging-diverging nozzle to form a cooled CO2-lean gas stream and circulating at least a portion of the cooled CO2-lean gas stream to the cooling stage for cooling the gas stream. Systems for separating carbon dioxide (CO2) from a CO2 stream are also provided.

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.