Fluor Technologies Corporation

Fluor Corporation

Richard B Nielsen

John Mak

Curt Graham

Thomas King Chow

Vincent Wai Wong

Henry Kister

Eh Deng

Robert Henderson

Michael Debest

Oliver Morgan

Contemplated NGL plants include a feed gas bypass circuit through which a portion of the feed gas is provided downstream to a vapor portion of the feed gas to thereby increase turbo expander inlet temperature and demethanizer temperature. Contemplated configurations are especially advantageous for feed gases with relatively high carbon dioxide content as they entirely avoid carbon dioxide freezing in the demethanizer, provide additional power production by the turboexpander, and recover C2+ components to levels of at least 80% while achieving a low carbon dioxide content in the NGL product.

NGL recovery methods and configurations

Heat is removed from a process liquid of a direct contact condenser in waste gas cooling using two separate and distinct cooling devices that provide cooled process liquid to at least two separate sections in the direct contact condenser. Most preferably, the sections are liquidly isolated and provide the heated process liquids to the respective cooling devices. However, in other embodiments, the sections are liquidly coupled to each other so to allow transfer of the process liquid from one section to another section. One of the two cooling devices uses a lower-cost or higher-availability coolant that the other. It is generally preferred that one of the cooling devices is an air cooler and that another one of the cooling devices employs a cooling medium other than air.

Low-energy waste gas cooling using direct contact condenser

LNG vapor from an LNG storage vessel is absorbed using Cand heavier components provided by a fractionator that receives a mixture of LNG vapors and the Cand heavier components as fractionator feed. In such configurations, refrigeration content of the LNG liquid from the LNG storage vessel is advantageously used to condense the LNG vapor after separation. Where desired, a portion of the LNG liquid may also be used as fractionator feed to produce LPG as a bottom product.

Liquid natural gas fractionation and regasification plant

A syngas treatment plant is configured to remove sulfurous compounds and carbon dioxide from shifted or un-shifted syngas in a configuration having a decarbonization section and a desulfurization section. Most preferably, the solvent in the decarbonization section is regenerated and cooled by flashing, while the solvent is regenerated in the desulfurization section via stripping using external heat, and it is still further preferred that carbonylsulfide is removed in the desulfurization section via hydrolysis, and that the so produced hydrogen sulfide is removed in a downstream absorber.

Configurations and methods for carbon dioxide and hydrogen production from gasification streams

Contemplated configurations and methods for elemental sulfur removal from various gases, and especially well acid gases employ a hydrocarbon solvent that dissolves the sulfur to form a rich solvent and that is then regenerated by hydrotreating. Thus, sulfur is removed from the rich solvent as H2S that may then be processed (e.g., in Claus unit or absorption unit) while the regenerated solvent is routed back to the well and associated production pipes.

Hydrocarbon based sulfur solvent systems and methods

A filter system has a first filter from which solvent is recovered in a cleaning cycle using a rinse fluid in forward flow, and from which particulates are removed using flush gas in reverse flow. At least part of the solvent and the flush gas are recycled to the system, and in still further preferred aspects, filtration of the solvent continues during the cleaning cycle via a bypass circuit through which the solvent is routed to a second filter.

Solvent filtration system and methods

Hydrogen sulfide is selectively enriched from an acid gas () that comprises relatively large quantities of carbon dioxide using a configuration in which a portion of an isolated hydrogen sulfide stream is introduced into an absorber () operating as a carbon dioxide rejecter. The resulting concentrated hydrogen sulfide enriched solvent () is then further used (directly or indirectly) to absorb hydrogen sulfide from an acid feed gas.

Methods and configurations for acid gas enrichment

Contemplated plants comprise an acid gas removal unit that receives a compressed gas from an injection gas compressor, wherein acid gas is removed from the compressed gas in the acid gas removal unit at a pressure approximately above pipeline pressure.

High pressure gas processing configurations and methods

A plant includes an absorber () that operates in a gas phase supercritical region and removes an acid gas from a feed stream () at high recovery of the feed stream () while producing a high purity acid gas stream (). Particularly preferred plants include gas purification plants that receive a feed gas with at least 5 mol % carbon dioxide at a pressure of at least 3000 psi.

Configurations and method for improved gas removal

Methods and configurations for improved propane recovery plant employ an absorber column, and a deethanizer column with an overhead condenser that produces a reflux condensate. The reflux condensate is recycled to both the absorber column and the deethanizer column, and a third recycling loop feeds propane from the absorber column into the deethanizer column in a gaseous form. The overhead condenser employs cold reject gas from the absorber and/or propane as a refrigerant, and preferred deethanizer columns include an integral water removal contactor.

Growing community of inventors

Laguna Niguel, CA, United States of America

Richard B Nielsen