An anaerobic digester is provided. The anaerobic digester includes a biogas storage container comprising a semi-permeable membrane separating the biogas storage container into a first space and a second space, such that the first space is configured to be methane enriched and the second space is configured to be CO.sub.2 enriched. The anaerobic digester further includes a cover positioned over the biogas storage container for protecting the biogas storage container against the elements.

A facility and method for membrane permeation treatment of a feed gas flow containing at least methane and carbon dioxide that includes a compressor, a pressure measurement device, at least one valve, and first, second, third, and fourth membrane separation units for separation of CO.sub.2 from CH.sub.4 to permeates enriched in CO.sub.2 and retentates enriched in CH.sub.4, respectively. The at least one valve adjusts the number of membranes combined and connected to the flow of gas entering into at least one of the membrane separation units as a function of the pressure recorded by the pressure measurement device.

A cryogenic distillation tower for separating a feed stream. The tower includes a distillation section. A controlled freeze zone section is situated above the distillation section and forms a solid from the feed stream. The controlled freeze zone section includes a spray assembly in an upper section and a melt tray assembly in a lower section. The melt tray assembly includes at least one vapor stream riser that directs the vapor from the distillation section into liquid retained by the melt tray assembly, and one or more draw-off openings positioned to permit a portion of the liquid to exit the controlled freeze zone section. The portion of the liquid indirectly exchanges heat with a heating fluid. One or more return inlets return the portion of the liquid to the melt tray assembly after it has been heated in the heat exchanger.

A co-current contacting system for removing impurities from a gas stream is described herein. The co-current contacting system includes a co-current contactor configured to co-currently flow a gas stream including impurities and a liquid stream through the co-current contactor. The co-current contactor is also configured to incorporate liquid droplets formed from the liquid stream into the gas stream, such that the impurities from the gas stream are absorbed by the liquid droplets. The co-current contacting system also includes a separator configured to remove the gas stream from the liquid droplets including the impurities, generating a purified gas stream and a rich liquid stream. The co-current contacting system is configured to recycle the rich liquid stream for reuse as a portion of the liquid stream flowing into the co-current contactor.

A system for processing an LNG feed, the system comprising: a bulk removal stage arranged to remove and release CO.sub.2 liquid from the inflow feed, said bulk removal stage including a first HGMT device, and; a polishing stage arranged to receive a lean CO.sub.2 feed from the first HGMT device, said polishing stage arranged to remove and release residual CO.sub.2, the polishing stage including a second HGMT device; wherein the polishing stage is arranged to release an outflow of CO.sub.2 stripped LNG.

A solid handling vessel comprising: a separation tank having an inlet for tangentially receiving an inflow of CO.sub.2 enriched hydrocarbon feed stream; said separation tank to facilitate cyclonical flow of said feed stream; a heating assembly within the separation tank for maintaining the feed stream above a temperature for solidification of CO.sub.2; a gas outlet arranged to vent gas from the separation tank; a collection tank located below, and in fluid communication with, the separation tank, said collection tank arranged to receive separated liquid and outflow said liquid from a liquid outlet.

Systems and methods are provided to mitigate flaring of natural gas. A natural gas processing system may process raw natural gas into a fuel gas stream that may be used to power any number of on-site power generation modules. In turn, the power generation modules may convert the fuel gas stream into an electrical output, which may be employed to power any number of distributed computing units housed within one or more mobile data centers. In certain embodiments, the distributed computing units may be adapted to mine cryptocurrency or perform other distributed computing tasks to generate revenue.

This disclosure relates to CO.sub.2-philic crosslinked polyethylene glycol membranes useful for natural gas purification processes. Also provided are methods of using the membranes to remove CO.sub.2 and H.sub.2S from natural gas.

A gas separation membrane, methods of forming the membrane, and methods of using the membrane for gas separation are provided. An exemplary gas separation membrane includes a cellulosic matrix and a polymer of intrinsic microporosity (PIM). The PIM includes chains coupled by a heat-treating under vacuum.

Devices, systems, and methods for liquefied natural gas production facilities are disclosed herein. A liquefied natural gas (LNG) production facility includes a liquefaction unit and a gas turbine. The liquefaction unit condenses natural gas vapor into liquefied natural gas. The LNG production facility further includes at least one post-combustion capture unit that captures a carbon dioxide (CO2)-rich stream from a flue gas stream of the gas turbine. The LNG production facility also includes a sequestration compression unit that compresses at least one CO2-rich stream from the at least one post-combustion capture unit.