Conocophillips Company

Phillips Petroleum Company

Wesley R Qualls

Matthew C Gentry

Jame Yao

Attilio Jose Praderio

Bobby D Martinez

Megan Victoria Evans

Ned P Baudat

Paul R Hahn

Will T James

Marc Thomas Bellomy

Mohan Chahal

Robert L Boulanger

Paula A Leger

Scott E Kufeld

Anthony P Eaton

John H Tait

Rong-Jwyn Lee

Qi Ma

Jong Juh Chen

Weldon L Ransbarger

Peter Nelson Slater

Karl Lee Herzog

Lisa M Strassle

Shawn S Huang

James L Rockwell

Stuart L Wilson

Satish L Gandhi

Christopher M Widner

Doug Elliot

Mike Wilkes

Shrikant R Thakkar

Hans P Weyermann

George O Obath

Matt Calvin Gentry

Garry A Marek

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.

Systems and methods for removing nitrogen during liquefaction of natural gas

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.

Contaminant removal with catalyst beds for LNG processing

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.

Heat exchanger for a liquefied natural gas facility

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 with varying characteristics, such as, for example higher heating value (HHV) and/or propane content. Resulting LNG and/or NGL products are capable of meeting the significantly different specifications of two or more markets.

LNG facility with integrated NGL recovery for enhanced liquid recovery and product flexibility

Methods and systems for removing nitrogen during liquefaction of natural are provided. Methods of removing nitrogen include warming a predominantly methane stream in a methane cold box to provide a warmed predominantly methane stream; conducting at least a portion of the warmed predominantly methane stream from the methane cold box to a nitrogen removal unit comprising at least a first nitrogen removal column and a last nitrogen removal column, wherein the first nitrogen removal column is located upstream of the last nitrogen removal column; passing the warmed predominantly methane stream through the last nitrogen removal column to provide a refluxed warmed predominantly methane stream; and routing at least a portion of the refluxed warmed predominantly methane stream to the last nitrogen removal column.

Nitrogen rejection unit

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.

Optimized heavies removal system in an LNG facility

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.

Optimized LNG system with liquid expander

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.

Heat integration system for natural gas liquefaction

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.

Driver and compressor system for natural gas liquefaction

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.

Motor driven compressor system for natural gas liquefaction

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. Because of the converging nature of the leg, as polymer is withdrawn the velocity increases progressively going from the entry to the exit of the leg thus avoiding polymer buildup.

Solids concentration in slurry polymerization

Growing community of inventors

Houston, TX, United States of America

Wesley R Qualls