Chevron U.s.a. Inc.

Shabbir Husain

Daniel Chinn

Nitesh Bhuwania

Tapan Kumar Das

Ronald P MacDonald

Lin Li

Zhen Zhou

Huping Luo

William L Schinski

Lyman Arnold Young

Graham J Forder

Lixin You

Alice Zunqing He

Dennis John O'Rear

Alexander E Kuperman

Charles Kibby

Russell Evan Cooper

Zunqing He

Prakhar Prakash

Paul Bryan

Gordon R Deppe

Anne M Helgeson

Christopher M Chen

Babak Fayyaz-Najafi

Brent A Hetrick

Sam J Mishael

Siji Okeowo

Jeff D Euhus

Disclosed are methods and systems for reducing elemental sulfur production in a gas production plant that includes receiving produced fluids high in hydrogen sulfide, removing hydrogen sulfide and converting hydrogen sulfide to elemental sulfur in a Claus unit. An acid gas stream is diverted from a feed line to the Claus unit in the gas processing plant and directed to a multistage acid gas compressor. An elemental sulfur production rate is reduced without reducing a production rate of the produced fluids. The compressed acid gas stream can be injected into a subterranean formation. In some embodiments, the gas production plant is integrated with an oil processing and gas injection plant.

Processes and systems for high HS gas processing having reduced sulfur production

Disclosed are systems and methods for producing oil and gas while removing hydrogen sulfide from fluids produced from oil and gas reservoirs. Hydrogen sulfide-selective membranes are used to remove hydrogen sulfide from bottlenecked plant process steps including hydrogen sulfide removal. In some embodiments of the present disclosure, plant processing efficiency is improved for processing of high temperature associated gas streams by using membranes while integrating heat from other existing process streams. In other embodiments of the present disclosure, plant processing efficiency is improved for processing of high temperature associated gas streams by using high temperature tolerant polymer membranes. Oil and/or gas production is increased.

Systems and methods to manage heat in an integrated oil and gas processing plant with sour gas injection

Disclosed are systems and methods for processing gas produced from oil and gas reservoirs while removing mercaptans from the gas. Mercaptan-selective membranes are used to debottleneck known systems and methods by removing mercaptans from bottlenecked plant process steps including LPG fractionation and mercaptan sweetening. Hydrogen sulfide can be simultaneously removed by the membranes. Production of on specification LPG and sales gases can be increased.

Systems and methods to remove mercaptans from sour gas using membranes

Disclosed are systems and methods for producing oil and gas while removing hydrogen sulfide from fluids produced from oil and gas reservoirs and injecting a sour gas stream containing the hydrogen sulfide into an underground formation. Hydrogen sulfide-selective membranes are used to debottleneck known systems and methods by removing hydrogen sulfide from bottlenecked plant process steps including sour gas compression, hydrogen sulfide removal and sour gas injection. Pressure ratio across the membranes can also be manipulated to provide further debottlenecking. Gas-gas eductors are also disclosed for use in leveraging relatively high-pressure streams to boost the pressure of low pressure streams. Oil production is thus increased.

Systems and methods to debottleneck an integrated oil and gas processing plant with sour gas injection

Disclosed are systems and methods for increasing oil production in an integrated oil and gas production plant including hydrogen sulfide removal and sour-gas injection into an underground formation. Hydrogen sulfide-selective membranes are used to debottleneck known systems and methods by removing hydrogen sulfide from bottlenecked plant process steps including sour gas compression, hydrogen sulfide removal and sour gas injection. A method of retrofitting an integrated plant includes adding a hydrogen sulfide-selective membrane upstream of an amine unit to remove hydrogen sulfide from an associated gas stream and form a permeate stream enriched in hydrogen sulfide and a retentate stream depleted in hydrogen sulfide and enriched in hydrocarbon gases. Less hydrogen sulfide is sent to the amine unit and oil production is higher than in the integrated plant without the hydrogen sulfide-selective membrane.

Disclosed are systems and methods for producing oil and gas in a plant while removing hydrogen sulfide and water from fluids produced from oil and gas reservoirs and injecting a sour gas stream containing the hydrogen sulfide into an underground formation. Water-selective membranes are used to debottleneck known systems and methods by removing water from bottlenecked sections of the plant including pretreatment of a sour gas feed to one or more gas processing plants. In other aspects, water-selective membranes are used to debottleneck the pretreatment of an acid gas feed to a Claus unit to convert hydrogen sulfide to sulfur in a gas processing plant. The water-selective membranes pretreat the acid gas feed.

Systems and methods to dehydrate high acid gas streams using membranes in an oil and gas processing plant

A method is provided for recovering mercury from a crude oil into an alkaline ammonium sulfide contacting solution. Soluble mercury complexes in the contacting solution are converted to particulate mercury. The particulate mercury can be recovered by filtering, and the ammonium sulfide in the contacting solution recycled to the aqueous contacting solution.

Method for removing mercury from crude oil

A crude oil which contains at least 0.1 wt % unstable sulfur compounds is treated in a reaction zone at low temperature to convert at least 50 wt % of the unstable sulfur compounds contained therein. The reaction and removal of sulfur from the crude may be facilitated by contacting the crude oil with a catalytic material in the presence of a stripping fluid.

Removing unstable sulfur compounds from crude oil

A system and process for producing synthetic crude oil from produced fluids of an oil well is disclosed. The system comprises a separation plant for producing an associated gas stream from produced fluids a membrane unit comprising a plurality of polymer membranes to provide a COenriched permeate stream and a COdepleted product gas stream, a gas conversion plant for converting the COdepleted product gas stream into a synthetic crude oil and a heat exchanger adding heat to the associated gas stream so that the membrane unit operates at a temperature of at least 80&#xb0; C. during separation of the associated gas stream using the membrane unit. A process using the aforementioned components, including separation of the associated gas stream using the membrane unit at a temperature &#x3e;80&#xb0; C., into a COenriched stream and a COdepleted product stream, is also described.

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A synthesis gas conversion process and system are disclosed. Fresh syngas from a methane reformer is used as a sweep zone gas feed which is caused to flow across a water permselective membrane in a membrane reactor. The water permselective membrane is adjacent a synthesis gas conversion reaction zone in which synthesis gas is contacted with a catalyst and converted to effluent including water. Water is removed from the reaction zone through the membrane and passes out of the reactor with the sweep zone gas. The water is then removed from the sweep zone gas forming a modified gas feed which is fed to the reaction zone. The modified gas feed has a preferred H/CO ratio to feed into the reaction zone.

System, process and reactor for conducting a synthesis gas conversion reaction

Disclosed are embodiments relating to a process for reducing the total acid number of a hydrocarbon feed by contacting the feed with a metal titanate catalyst having an MTiOstructure wherein M is a metal having a valence of 2+, resulting in a hydrocarbon product having a final total acid number lower than the initial total acid number of the feed. The process is useful for pretreating high acid crudes prior to further processing thus avoiding corrosion of equipment used in refining operations. The process can be integrated into conventional refining operations in order to treat various refinery streams. In one embodiment, a process is provided for refining a low acid crude oil and a high acid crude oil by separately introducing a relatively low acid crude oil feed and a relatively high acid crude oil feed to an atmospheric distillation column, wherein the relatively high acid crude oil feed is contacted with a metal titanate catalyst prior to introduction to the atmospheric distillation column.

Process for reducing the total acid number of a hydrocarbon feed

Disclosed herein is a method for preparing a crosslinked hollow fiber membrane. The method involves spinning a one phase solution comprising a monoesterified polyimide polymer, acetone as a volatile solvent, a spinning solvent, a spinning non-solvent, and optionally an organic and/or inorganic additive, wherein the volatile solvent is present in an amount of greater than 25 wt. % to about 50 wt. %, based on the total weight of the solution.

Methods of preparing a crosslinked fiber membrane

A synthesis gas conversion process for carrying out the process is disclosed. A hydrogen-containing sweep gas is caused to flow across a water permselective membrane adjacent a synthesis gas conversion reaction zone in which synthesis gas is contacted with a catalyst and converted to effluent including water. Water is removed from the reaction zone through the membrane. The sweep gas has sufficient hydrogen partial pressure to cause hydrogen to pass through the membrane into the reaction zone.

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Emeryville, CA, United States of America

Shabbir Husain