Chevron U.s.a. Inc.

University of South Alabama

Nov Subsea Products As

Chevon U.s.a. Inc.

Russell Evan Cooper

Dennis John O'Rear

Sujin Yean

Dennis John O'rear

Daniel Chinn

Michael Sean Driver

James Hillard Davis, Jr

Zunqing He

Darrell Lynn Gallup

Lyman Arnold Young

Kevin N West

Hye Kyung Timken

Feng-Ran Sheu

Jordan Taylor Belue

Michael S Driver

Brian Christopher Llewellyn

Seyi Abiodun Odueyungbo

Mark Anthony Emanuele

Matthew Bernard Zielinski

Jr Davis James H

Cesar Ovalles

Shabbir Husain

Joshua Allen Thompson

Stephen Roby

Thomas Hoelen

Christopher John Kalli

Wei Wang

Jerry Max Rovner

Kevin John Grice

Jan-Otto Reimers

Gudmund Roger Totland

Christine Marie Long

Carl W Lam

Manuel Eduardo Quintana

Hye Hyung Timken

Hosna Mogaddedi

Adam J Dassey

Janelle L Lewis

Jinhua Bai

Eirik Bjerve Sund

James H Davis

The present invention is directed to a method for removing elemental mercury from liquid natural gas comprising changing the stabilizer column operating conditions to beneficially transfer mercury from the stabilized condensate phase to the overhead gas phase, where it may be compressed and recycled with the gas going to the existing feed gas mercury removal units.

Method of reducing mercury in stabilized condensate

Disclosed are systems and methods for treating contaminated material. The material is heated by nonconductive and nonconvective heating in a vacuum chamber such that the surface of the material is heated without significant heating of the air within the chamber. The surface of the material is heated to at least a volatilization temperature of the contaminants or to a decomposition temperature of one or more compounds in intimate contact with the contaminants, so that the concentration of contaminants in the material is reduced. Exhaust is removed from the chamber and cooled. A solids and/or liquids collector removes condensed solids and/or liquids and has a gas outlet connected to a vacuum pump.

Systems and methods for treating contaminated solid material

Method and system for separation of produced water into a water fraction, a solids fraction and a hydrocarbon fraction, comprising feeding produced water into a collapsible flexible bag maintained subsea by a protection structure; operating the flexible bag at an overpressure and thereby providing a predefined geometry of the flexible bag; maintaining the produced water in the flexible bag to allow for gravitational separation of the solids fraction with a higher density than water in a lower section and optionally separation of the hydrocarbon fraction with a lower density than water in an upper section; removing the water fraction from a section above the lower section; optionally removing hydrocarbons from the upper section and replacing the flexible bag to remove the solids fraction.

Method and system for subsea separation of produced water

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

Particulate mercury, in the form of metacinnabar, is removed from crude oil by thermally treating the crude oil at temperatures in a range from 150&#xb0; C. to 350&#xb0; C. and at a pressure sufficient to limit the amount of crude vaporizing to no more than 10 wt. %. In the thermal treatment, the particulate mercury is converted into elemental mercury, which can be removed by directly adsorption from the crude onto a support. In one embodiment, the elemental mercury can be removed by stripping the crude with a gas, and then adsorbing the mercury onto a support. The crude oil can be optionally treated prior to stabilization and contains 0.1 wt. % or more of C-hydrocarbons. Following the thermal treatment, the treated crude is cooled and the pressure is reduced. The C-hydrocarbons then vaporize from the crude and carry the elemental mercury with them. The elemental mercury in this hydrocarbon gas stream may then be removed by a solid adsorbent.

Process, method, and system for removing heavy metals from fluids

A predictive tool is provided for estimating the mercury content of hydrocarbons to be produced from a wellbore in a newly investigated subterranean hydrocarbon producing formation based on the mercury content of an inorganic sample recovered from the wellbore. The mercaptans content of liquid hydrocarbons and/or the hydrogen sulfide content of natural gas produced from the formation may also be used to enhance the prediction. Based on the predicted value, a mercury mitigation treatment may be provided to mitigate the mercury content of hydrocarbons produced from the formation.

Process for mercury removal

A process and system for separating COfrom a flue gas stream is disclosed. The process involves (a) contacting a flue gas stream containing water vapor and COwith an ionic absorbent under absorption conditions to absorb at least a portion of the COfrom the flue gas stream and form a CO-absorbent complex; wherein the ionic absorbent comprises a cation and an anion comprising an amine moiety; and (b) recovering a gaseous product having a reduced COcontent.

Process for the separation of carbon dioxide from flue gas

Mercury in distilled products from a distillation column is removed and extracted as soluble mercury compounds with the injection of a complexing agent into the overhead sections of the column. Examples of complexing agents include polysulfides such as sodium polysulfide or ammonium polysulfide. In one embodiment, the complexing agent is injected into the inlet pipe just before the overhead condenser, converting the volatile elemental mercury into a species that is soluble in the sour water stream that collected in the overhead sections.

Methods and systems relate to the in-situ removal of heavy metals such as mercury, arsenic, etc., from produced fluids such as gases and crudes from a subterranean hydrocarbon-bearing formation. A sufficient amount of a fixing agent is injected into formation with a dilution fluid. The fixing agent reacts with the heavy metals forming precipitate, or is extracted heavy metals into the dilution fluid as soluble complexes. In one embodiment, the heavy metal precipitates remain in the formation. After the recovery of the produced fluid, the dilution fluid containing the heavy metal complexes is separated from the produced fluid, generating a treated produced fluid having a reduced concentration of heavy metals. In one embodiment, the dilution fluid is water, and the wastewater containing the heavy metal complexes after recovery can be recycled by injection into a reservoir.

In-situ method and system for removing heavy metals from produced fluids

Oil is recovered from a mercury containing Hg-containing solids containing abradants by mixing the solids with a sulfidic compound in a molar ratio of sulfur compound to mercury from 5:1 to 5,000:1, and the sulfidic compound when dissolved in water, yields S2-, SH&#x2014;, Sx2-, or SxH&#x2014; anions, and optionally a solvent, forming a mixture. The mixture is then separated to recover a first phase containing treated oil in water, and a second phase containing treated abradants having a reduced concentration of mercury. In one embodiment, the treated abradants contain less than 100 ppmw mercury. The abradants are provided by removing at least a portion of a mercury-containing coating from a surface by abradant blasting, laser ablation, laser thermal desorption, and sponge jet blasting.

Process, method, and system for removing heavy metals from oily solids

Disclosed herein is a method for improving the total energy demand required to separate carbon dioxide (CO) from an aqueous ionic absorbent solution in a post-combustion carbon capture process. The method involves (a) contacting a flue gas stream containing COwith an aqueous ionic absorbent solution under absorption conditions to absorb at least a portion of the COfrom the flue gas stream and form a CO-aqueous ionic absorbent solution stream, wherein the aqueous ionic absorbent solution comprises one or more diluents and an ionic absorbent containing a cation and an anion comprising an amine moiety; and (b) subjecting at least a portion of the CO-aqueous ionic absorbent solution stream to desorption conditions to form a CO-rich stream and an aqueous ionic absorbent solution stream having a reduced COcontent.

Method for improving total energy demand in a post-combustion carbon capture process with ionic absorbent

A method for concurrently transporting and removing trace amount levels of heavy metals such as mercury from produced fluids such as natural gas, with the injection of a complexing agent and a hydrate inhibitor into the pipeline for use in transporting the produced fluid. Volatile mercury in the natural gas is removed while the produced fluid is being transported in the pipeline, with the hydrate inhibitor suppressing or decreasing the formation of the hydrate that would cause plugging in the pipeline. The complexing agent reacts with the volatile mercury in the natural gas, forming precipitate or soluble mercury complexes in the aqueous phase. The aqueous phase containing the hydrate inhibitor, unreacted complexing agent, and mercury complexes is subsequently recovered and can be re-used in the pipeline.

An aqueous ionic absorbent solution is disclosed containing (a) about 15 wt. % to about 80 wt. % of one or more diluents, based on the total weight of the aqueous ionic absorbent solution; and (b) an ionic absorbent containing a cation and an anion comprising an amine moiety.

Aqueous solutions of amine functionalized ionic compounds for carbon capture processes

Trace amount levels of non-volatile mercury in crude oil are reduced by contacting the crude oil with a water stream containing at least a monatomic water-soluble sulfur species such as sulfides and hydrosulfides. The non-volatile mercury is extracted into the water phase forming a mercury rich wastewater, yielding a treated crude oil having at less than 50% of the original non-volatile mercury level. The wastewater can disposed or recycled by injection into a reservoir. In one embodiment, the water stream consists essentially of produced water.

Process, method, and system for removing mercury from fluids

Growing community of inventors

Martinez, CA, United States of America

Russell Evan Cooper