A device may include a plurality of controllable components, an input to receive a waste stream including carbon dioxide and volatile organic compounds, and a foam trap coupled to the input. The device may further include one or more sensors coupled to the input and configured to generate an electrical signal proportional to a concentration of at least one compound within the waste stream. The device may also include a control circuit coupled to the one or more sensors and configured to selectively activate one or more of the plurality of controllable components in response to the electrical signal.

Plant and process for the production of liquid methane from a feed gas stream comprising at least methane and carbon dioxide. A feed gas stream is injected into a CO.sub.2 crystallizer in countercurrent fashion against a stream of predominantly liquid methane, thereby crystallizing amounts of carbon dioxide from the feed gas stream. Gaseous methane recovered from the CO.sub.2 crystallizer is liquefied at a liquefaction exchanger.

Processes for separating CO.sub.2 from a gas mixture containing one or more of hydrogen, nitrogen, argon, CO, and methane or a combination thereof is described. The processes involve, for example, cooling and partial condensation of the gas mixture, preferably by a single loop refrigeration system with a mixed refrigerant, phase separation of the partially condensed stream, and distillation of the CO.sub.2-rich liquid stream. At least a portion of the liquid CO.sub.2 produced from the processes during the off-peak electricity demand hours can be stored and then heated, vaporized, further heated, and expanded for power generation during the peak electricity demand hours, helping balance the supply and demand of electricity of the electricity grid.

The invention relates to a process for the combined production of hydrogen and carbon dioxide from a hydrocarbon mixture, in which the residual gas of a PSA H.sub.2 (12) is separated by permeation in order to reduce the hydrocarbon content thereof and the hydrocarbon-purified gas is separated at a low temperature to produce a carbon dioxide-rich liquid (22).

A CO2 separation and liquefaction system such as might be used in a carbon capture and sequestration system for a fossil fuel burning power plant is disclosed. The CO2 separation and liquefaction system includes a first cooling stage to cool flue gas with liquid CO2, a compression stage coupled to the first cooling stage to compress the cooled flue gas, a second cooling stage coupled to the compression stage and the first cooling stage to cool the compressed flue gas with a CO2 melt and provide the liquid CO2 to the first cooling stage, and an expansion stage coupled to the second cooling stage to extract solid CO2 from the flue gas that melts in the second cooling stage to provide the liquid CO2.

The present invention relates to a method and system for treating a flow back fluid exiting a well site following stimulation of a subterranean formation. More specifically, the invention relates to processing the flow back fluid, and separating into a carbon dioxide rich stream and a carbon dioxide depleted stream, and continuing the separation until the carbon dioxide concentration in the flow back stream until the carbon dioxide concentration in the flow back gas diminishes to a point selected in a range of about 50-80 mol % in carbon dioxide concentration, after which the lower concentration carbon dioxide flow back stream continues to be separated into a carbon dioxide rich stream which is routed to waste or flare, and a hydrocarbon rich stream is formed.

A carbon dioxide capture system includes a first heat exchanger that exchanges heat between an exhaust stream and a lean carbon dioxide effluent stream. The carbon dioxide capture system also includes a second heat exchanger in flow communication with the first heat exchanger. The second heat exchanger is configured to cool the exhaust stream such that a condensate is formed, and the second heat exchanger is configured to channel a condensate stream for injection into the lean carbon dioxide effluent stream. A first turboexpander including a first compressor is driven by a first turbine. The first compressor is coupled in flow communication with the first heat exchanger. The first turbine is coupled in flow communication with the first heat exchanger and configured to expand the lean carbon dioxide effluent stream. The carbon dioxide capture system further includes a carbon dioxide membrane unit coupled in flow communication with the first compressor.

A system and method for capturing and separating carbon dioxide from mixed gas streams. The gas stream is processed in a structure including a compression module comprising a plurality of compressors, intercoolers and inter-stage condensate separators. The flow path from the compression module includes a plurality of flow separators, gas stream splitters, heat exchangers and at least a first mixer and a first expander. The gas stream is sequentially compressed and cooled to form process condensate and separate it from the compressed gas stream. The gas stream is further dried and cooled to liquefy carbon dioxide and separate it from the non-condensable portion. Selective expansion of liquid carbon dioxide streams provides cooling for the system, and further energy efficiency is achieved by selective recycling of portions of gas streams, allowing for compact equipment and economical operation, while providing for high purity product streams of carbon dioxide.

A method for separating carbon dioxide from flue gas to generate a high purity CO2 stream.

In a method for compressing a gas that is to be separated in a low-temperature CO.sub.2 separation unit using at least one partial condensation step and/or at least one distillation step, the gas that is to be separated has a variable composition and/or variable flow rate, the gas that is to be separated is compressed in a compressor to produce a compressed gas and the inlet pressure of the gas that is to be separated, entering the compressor, is modified according to the CO.sub.2 content and/or the flow rate of the gas that is to be separated so as to reduce the variations in volumetric flow rate of the gas that is to be separated entering the compressor.