The present invention provides a method of liquefying a contaminated hydrocarbon-containing gas stream: (a) providing a CO2 contaminated hydrocarbon-containing gas stream (20); (b) cooling the contaminated hydrocarbon-containing gas stream to obtain a partially liquefied stream (70); (c) separating the partially liquefied stream obtaining a liquid stream (90); (d) cooling the liquid stream (90) in a direct contact heat exchanger (200) obtaining a multiphase stream (201) containing at least a liquid phase and a solid CO2 phase; (e) separating the multiphase stream in a solid-liquid separator (202) obtaining a CO2 depleted liquid stream (141); (f) passing the CO2 depleted liquid stream (141) to a further cooling, pressure reduction and separation stage to generate a further CO2 enriched slurry stream (206); (g) passing at least part of the further CO2 enriched slurry stream (206) to the direct contact heat exchanger (200) to provide cooling duty to and mix with the liquid stream (90).

The present disclosure relates to a hydrogen liquefaction system and hydrogen liquefaction method capable of increasing a hydrogen liquefaction amount through a pre-cooling process, and may comprise a hydrogen pipe, where gaseous hydrogen is introduced at a front end, heat exchange occurs in a heat exchange section leading to liquefaction of gaseous hydrogen into liquid hydrogen, and liquefied liquid hydrogen can be discharged at a rear end; a pre-cooling device formed between the front end of the hydrogen pipe and the heat exchange section, pre-cooling gaseous hydrogen; and a cooling cycle device, which is in thermal contact with the heat exchange section of the hydrogen pipe so as to perform heat exchange with the heat exchange section of the hydrogen pipe such that pre-cooled gaseous hydrogen can be liquefied into liquid hydrogen.

Implementations described and claimed herein provide systems and methods for processing liquefied natural gas (LNG). In one implementation, a solvent is injected into a feed of natural gas at a solvent injection point. A mixed feed is produced from a dispersal of the solvent into the feed of natural gas. The mixed feed contains heavy components. A chilled feed is produced by chilling the mixed feed. The chilled feed includes a vapor and a condensed liquid. The condensed liquid contains a fouling portion of the heavy components condensed by the solvent during chilling. The liquid containing the fouling portion of the heavy components is separated from the vapor. The vapor is directed into a feed chiller heat exchanger following separation of the liquid containing the fouling portion of the heavy components from the vapor, such that the vapor being directed into feed chiller heat exchanger is free of freezing components.

Process for efficiently operating a natural gas liquefaction system with integrated heavies removal/natural gas liquids recovery to produce liquefied natural gas (LNG) and/or natural gas liquids (NGL) products.

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.

A method of producing liquefied natural gas (LNG) is disclosed. A natural gas is compressed in at least two serially arranged compressors to a pressure of at least 2,000 psia and cooled to form a cooled compressed natural gas stream. The cooled compressed natural gas stream is additionally cooled to a temperature below an ambient temperature to form an additionally cooled compressed natural gas stream, which is expanded in at least one work producing natural gas expander to a pressure that is less than 3,000 psia and no greater than the pressure to which the at least two serially arranged compressors compress the natural gas stream, to thereby form a chilled natural gas stream. The chilled natural gas stream is liquefied by indirect heat exchange with a refrigerant to form liquefied natural gas and a warm refrigerant. The cooled compressed natural gas stream is additionally cooled using the warm refrigerant.

The LNG plant comprises a compression train and a further compression. The compression train (100) comprises comprising an engine and a compressor driven by the engine; the compressor is an axial compressor and comprises a first set of axial compression stages and a second set of axial compression stages arranged downstream the first set of axial compression stages; at least the first set and the second set of axial compression stages are housed inside one case. The further compression train comprises a further engine and a further compressor driven by the further engine; the further compressor is a centrifugal compressor and comprises a first set of impellers and a second set of impellers arranged downstream or upstream the first set of impellers.

Systems and a method for the formation of a liquefied natural gas (LNG) are disclosed herein. The system includes a first fluorocarbon refrigeration system configured to chill a natural gas using a first fluorocarbon refrigerant and a second fluorocarbon refrigeration system configured to further chill the natural gas using a second fluorocarbon refrigerant. The system also includes a nitrogen refrigeration system configured to cool the natural gas using a nitrogen refrigerant to produce LNG and a nitrogen rejection unit configured to remove nitrogen from the LNG. As an alternative embodiment, the nitrogen refrigeration system can be replaced by a methane autorefrigeration system.

This invention relates to a system and method for liquefying natural gas. In another aspect, the invention concerns an improved liquefied natural gas facility employing a closed loop methane refrigeration cycle. In another aspect, the invention concerns the utilization of lean boil-off gas.

A process and apparatus for liquefying natural gas includes a heavies recovery system. In another aspect, a liquefied natural gas (LNG) facility may employ an ethylene independent heavies recovery system. The recovery system may thus operate relying only on fluid input from upstream of an ethylene refrigeration cycle. A heavies-depleted stream recovered from a liquid withdrawn from a heavies removal column in the heavies recovery system may combine at a location downstream of the heavies removal column with an overhead withdrawn from the heavies removal column for further cooling of such combined stream into liquefied natural gas product.