Abstract: Systems and methods for processing liquefied natural gas (LNG) can include an LNG production system with a methane refrigeration cycle downstream from an ethylene refrigeration cycle. The methane refrigeration cycle can be a closed loop methane refrigeration cycle that maintains a methane refrigerant separate from a natural gas feed, (e.g., compared to an open loop methane refrigeration cycle that extracts the methane refrigerant from the natural gas feed and recombines the methane refrigerant with the natural gas feed). The natural gas feed can be a medium or high nitrogen gas feed having a nitrogen content greater than 1.0% molarity.

Abstract: A solvent is dispersed into a natural gas feed at a solvent injection point to produce a mixed feed. The mixed feed contains heavy components with a potentially fouling portion that can cause obstructions in a heat exchanger. A fluid injection system can inject the solvent intermittently, for instance, based on an amount of accumulation or expected accumulation of heavy component solids in the heat exchanger. The solvent prevents the potentially fouling portion of the heavy components from freezing, melts or dissolves the accumulation, and reduces the obstructions in the heat exchanger. The fluid injection system includes a solvent supply, an optional atomizer, an injection controller, optionally one or more sensors, and/or optionally a heater. The solvent injection system can disperse the solvent onto a flow surface for the natural gas feed and/or mixed feed to form a solvent film which further reduces heavy component solids.

Abstract: Disclosed are systems and methods for processing liquefied natural gas (LNG). A LNG production system may include a contaminant removal process with one or more sets of sorbent beds co-loaded with a metal sulfide sorbent and/or metal oxide sorbent. In some examples, the contaminant removal process may include one or more molecular sieve dehydrators co-loaded with a 3A or 4A sieve and a 3A or 4A sieve impregnated with silver. The one or more sets of sorbent beds may be arranged at various locations throughout the LNG production system including upstream of or downstream of heavy component removal beds having activated carbon. In some instances, the LNG production system may include a regeneration process for moving heated fluid, typically feed gas, through a first heavy component removal bed while maintaining other heavy component removal beds online to reduce downtime for the LNG production system, increase production efficiency, and decrease an amount of greenhouse gases released from defrost and flare-offs.

Abstract: A method of constructing a plate fin heat exchanger includes joining a first side bar formed from a nickel-iron alloy to a first end of a fin element formed from a nickel-iron alloy through a first nickel-iron alloy bond, and joining a second side bar formed from a nickel-iron alloy to a second end of the fin element through a second nickel-iron alloy bond to create a first layer of the plate fin heat exchanger. The fin element defines a fluid passage.

Abstract: The invention relates to a system, method and apparatus for processing natural gas in an LNG facility. A natural gas feed is introduced into a heavies removal unit. The heavies removal system includes a heavies removal column and a distillation column. The heavies removal column and the distillation column are connected via a purge/recovery line. One or more components of the natural gas feed is purged from the heavies removal column to the distillation column via the purge/recovery line to obtain a specified concentration or concentration range of heavy components feeding into the distillation column.

Abstract: A method of constructing a plate fin heat exchanger includes joining a first side bar formed from a nickel-iron alloy to a first end of a fin element formed from a nickel-iron alloy through a first nickel-iron alloy bond, and joining a second side bar formed from a nickel-iron alloy to a second end of the fin element through a second nickel-iron alloy bond to create a first layer of the plate fin heat exchanger. The fin element defines a fluid passage.

Abstract: Implementations described and claimed herein provide systems and methods for removing nitrogen during liquefaction of natural gas. In one implementation, a nitrogen rejection unit is used in an LNG facility to remove nitrogen from natural gas during an LNG liquefaction process. The nitrogen rejection unit contains at least two columns and at least one 3-stream condenser, 2-stream condenser or a two 2-stream condenser.

Abstract: The invention relates to a system, method and apparatus for processing natural gas in an LNG facility. A natural gas feed is introduced into a heavies removal unit. The heavies removal system includes a heavies removal column and a distillation column. The heavies removal column and the distillation column are connected via a purge/recovery line. One or more components of the natural gas feed is purged from the heavies removal column to the distillation column via the purge/recovery line to obtain a specified concentration or concentration range of heavy components feeding into the distillation column.

Abstract: A method of constructing a plate fin heat exchanger includes joining a first side bar formed from a nickel-iron alloy to a first end of a fin element formed from a nickel-iron alloy through a first nickel-iron alloy bond, and joining a second side bar formed from a nickel-iron alloy to a second end of the fin element through a second nickel-iron alloy bond to create a first layer of the plate fin heat exchanger. The fin element defines a fluid passage.

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: An LNG facility employing an optimized heavies removal system. The heavies removal system can comprise at least one distillation column and at least two separate heat exchangers. Feed and/or compressor discharge streams can be used to provide heat duty to the heat exchangers in a thermally efficient manner to facilitate the removal of heavy components from an overall LNG facility.

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 process and apparatus for the liquefaction of natural gas including at least one liquid expander for providing expansion of a high-pressure stream and powering a generator capable of producing electricity to be used to drive a compressor located elsewhere in the liquefaction apparatus. Particularly, a liquid expander is used to expand a high-pressure refrigerant stream and to power an electrical generator. The electricity provided by the generator can be used to power a compressor located in the same or a different refrigeration cycle as the liquid expander.

Abstract: A pretreatment system for natural gas liquefaction employing heat integration for more efficient and effective natural gas temperature control. The pretreatment system expands the natural gas prior to acid gas removal. After acid gas removal, the natural gas is cooled by indirect heat exchange with the expanded natural gas located upstream of the acid gas removal system.

Abstract: A pretreatment system for natural gas liquefaction employing heat integration for more efficient and effective natural gas temperature control. The pretreatment system expands the natural gas prior to acid gas removal. After acid gas removal, the natural gas is cooled by indirect heat exchange with the expanded natural gas located upstream of the acid gas removal system.

Abstract: Natural gas liquefaction system having an optimum configuration of mechanical drivers and compressors. A heat recovery system can be employed with the liquefaction system to enhance thermal efficiency. A unique start-up system can also be employed.

Abstract: Natural gas liquefaction system employing electric motors as compressor drivers. A combination of motors and steam turbines can be powered by a cogeneration plant and employed as drivers.

Abstract: An olefin polymerization apparatus is disclosed wherein monomer, diluent and catalyst are circulated in a continuous pipe loop reactor and an intermediate product slurry is recovered by a continuous product take off means. The intermediate product slurry is passed to a hydrocyclone to stratify polymer particles based on size. A slurry containing predominantly fines is withdrawn overhead and returned to the reaction zone. The slurry containing predominantly fines is preferably returned to the polymerization zone just upstream of the circulation pump and in a preferred embodiment this pressure differential is the sole driving force for the hydrocyclone separation. In another embodiment the product slurry from the bottom of the hydrocyclone is passed to a solids-liquid separator where the solids settle to the bottom and essentially polymer free diluent is recycled. In another embodiment, the intermediate product slurry is withdrawn via a conical settling leg.

Abstract: An olefin polymerization apparatus is disclosed wherein monomer, diluent and catalyst are circulated in a continuous pipe loop reactor and an intermediate product slurry is recovered by a continuous product take off means. The intermediate product slurry is passed to a hydrocyclone to stratify polymer particles based on size. A slurry containing predominantly fines is withdrawn overhead and returned to the reaction zone. The slurry containing predominantly fines is preferably returned to the polymerization zone just upstream of the circulation pump and in a preferred embodiment this pressure differential is the sole driving force for the hydrocyclone separation. In another embodiment the product slurry from the bottom of the hydrocyclone is passed to a solids-liquid separator where the solids settle to the bottom and essentially polymer free diluent is recycled. In another embodiment, the intermediate product slurry is withdrawn via a conical settling leg.