Chevron U.s.a. Inc.

Chevron Research Company

Claire Technologies, LLC

Other

Texaco Inc.

Chevron Phillips Chemical Company LP

Chevron Chemical Company LLC

Chevrontexaco Corporation

Chervon U.s.a. Inc.

Chevon U.s.a. Inc.

Dennis John O'Rear

Russell Evan Cooper

Gunther Hans Dieckmann

Sujin Yean

Stephen Joseph Miller

Charles Kibby

Thomas Van Harris

Curtis Lee Munson

Cong-Yan Chen

Darrell Lynn Gallup

Lyman Arnold Young

Jerome F Mayer

Russell Roland Krug

Michael Moir

Guan Dao Lei

Kirk T O'Reilly

Mark R Buetzow

William L Schinski

Alexander E Kuperman

John Michael Rosenbaum

Robert James Saxton

Tapan Kumar Das

Wei Wang

Feng-Ran Sheu

Jordan Taylor Belue

Kevin John Grice

Charles R Wilson

Richard O Moore, Jr

Lawrence W Jossens

Georgieanna L Scheuerman

Christopher A Simmons

Brian Christopher Llewellyn

Alan W Klaassen

Donald Kuehne

Seyi Abiodun Odueyungbo

Gregory Hemighaus

Steven F Sciamanna

Paul A Allinson

Steven S Mathur

Cong-Yan Chan

Matthew Bernard Zielinski

Mark Anthony Emanuele

Kandaswany Jothimurugesan

Hazel C Olbrich

Robert P Hohmann

John E Sundberg

John D Bacha

Stacey Ian Zones

Sven Ivar Hommeltoft

Kandaswamy Jothimurugesan

Theodorus Ludovicus Michael Maesen

Krishniah Parimi

Daniel Chinn

Andrew Rainis

Cesar Ovalles

Shabbir Husain

Charles L Kibby

Brent K Lok

Scott R Brundage

Estrella Rogel

John A Zakarian

André Peter Steynberg

Joseph A Biscardi

Stephen Roby

Thomas Hoelen

John A Segerstrom

Lucy Melinda Bull

Jerry Max Rovner

Vasudevan Sampath

Hariprasad Janakiram Subramani

Allison Amy Evans

Ben Smith

Rodney L Porter

Thomas Francis Finger

Robert J Motal

Brian V Dorsch

A Stephen Zavell

March R Buetzow

Michelle Hart

Hosna Mogaddedi

Manuel Eduardo Quintana

Hye-Kung Timken

Vijay Ramchandra Pradhan

Rusell Evan Cooper

Nga Malekzadeh

Greg Hemighaus

Roger Van Gelder

Nicholas Brancaccio

Richard Aviani

The present disclosure relates generally to a carbon-neutral process for the generation of carbon-neutral hydrogen and carbon-neutral electricity. More specifically, the present disclosure relates to compositions, methods and apparatus employing a carbon-neutral process for generating electricity employing a liquid organic hydrogen carrier (LOHC) for supplying hydrogen for generating the carbon neutral electricity. The present disclosure also relates more specifically to carbon-neutral compositions consisting of liquid organic hydrogen carriers used for supplying hydrogen to generate electricity that may be regenerated in a carbon-neutral process using an apparatus with a net zero atmospheric emission of carbon oxides.

Carbon-neutral process for generating electricity

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

Disclosed is a process to remove neutrally buoyant metal particles composed of solid particles and droplets of oil from water such as produced water from petroleum production or refinery wastewater. In one aspect, the water is contacted with oleophilic adsorbent materials which adsorb the neutrally buoyant metal particles. Also disclosed is a process for removing metal particles from a fluid volume that includes crude oil and/or condensate. The fluid volume is washed with a volume of water to form a volume of wastewater, thereby transferring at least a portion of the metal particles from the fluid into the wastewater. The volume of wastewater including the transferred metal particles is then contacted with an oleophilic adsorbent material wherein the neutrally buoyant metal particles are adsorbed by the adsorbent material. The adsorbent material is then separated from the wastewater. Finally, the treated wastewater is used to wash the crude and/or condensate.

Processes for removing metal particles from water

Elemental mercury is removed from a gas by contacting it with a halogen dissolved in an organic solvent. The mercury accumulates in the organic solvent and can be removed by extraction with an aqueous solution with a complexing agent, by adsorption, and by combinations. The absorption process can also operate by use of a series of absorbers which have successively higher concentrations of halogen in the solution and which successively remove more the mercury from the gas. A portion of the solvent in the last absorber can be cascaded to the previous absorber in the series. In one embodiment, the process is carried out at a temperature of absorber at less than or equal to 28&#xb0; C. above the higher of the water dew point and the hydrocarbon dew point. The mercury waste from the process is produced as either an aqueous solution or a small volume of mercuric sulfide.

Process, method, and system for removing mercury 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

Hydroprocessing facilities may operate for extended periods of time before detection of mercury in the inlet facilities, as mercury adsorbs onto the metallic pipelines used to transport the hydrocarbon fluids, e.g., gas, produced waters, from the wells to processing facilities ('flowlines'). Once the pipelines become 'saturated' with mercury, mercury will breakthrough and be detected at the inlet facilities. A mercury management/control scheme is disclosed wherein a chemical treatment step using aqueous sulfidic solution is integrated into a progressive pigging plan to clean the pipeline, managing mercury accumulation in the pipeline for a reduced mercury concentration in the fluid exiting the flowlines.

Process, method, and system for removing mercury from pipelines

A process for removing non-volatile, particulate mercury from crudes and condensates is disclosed. Particulate mercury in crudes can be removed by a process of first adding a halogen, such as I. The halogen converts at least 10% of the particulate mercury into an oil-soluble mercury compound that cannot be removed by filtration or centrifugation. This oil-soluble mercury compound can then be removed by adsorption onto a solid adsorbent. The process can operate at near ambient conditions. The adsorption step can be carried out by mixing a particulate adsorbent in the halogen-treated crude and then removing it by centrifugation, desalting, filtration, hydrocyclone or by settling.

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

The present invention relates to a new process which comprises the steps of hydrotreating, paraffin disproportionation and hydroisomerization to convert biological hydrocarbonaceous oxygenated oils comprising triglycerides into biologically-derived paraffinic jet/diesel fuels, solvents and base oils. A combination of conventional hydrogenation/dehydrogenation catalysts, such as Pt/AlO, and conventional olefin metathesis catalysts, such as WO/SiO, or inexpensive variations thereof, is generally employed in the paraffin disproportionation step.

Paraffinic jet and diesel fuels and base oils from vegetable oils via a combination of hydrotreating, paraffin disproportionation and hydroisomerization

A process and system are described for the processing of gas associated with crude oil production, i.e. associated gas. A separation complex is used to separate produced fluids produced from a hydrocarbon reservoir into crude oil, liquefied petroleum gas, water, and natural gas. At least a portion of the natural gas is converted into synthesis gas in a synthesis gas generator. A combination of a synthesis gas conversion catalysts and hydroconversion catalysts are used in a synthesis gas reactor to convert the synthesis gas into a liquid effluent stream containing liquefied petroleum gas and a synthetic crude oil. The liquefied petroleum gas and synthetic crude oil from the synthesis gas reactor is sent to the separation complex. Liquefied petroleum gas is separated both from the synthetic crude oil and a natural crude oil obtained from the produced fluids. The system and process permits synthetic crude oil to be blended with the natural crude oil producing a blended stabilized crude oil having 2 wt % or more of the synthetic crude oil and with a pour point of 60&#xb0; C. or less. Use of a common facility for separation operations on the natural crude oil and synthetic crude oil thus reduces capital costs and allows converted associated gases to be shipped with the natural crude oil on a conventional crude oil tanker.

System for blending synthetic and natural crude oils derived from offshore 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

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Petaluma, CA, United States of America

Dennis John O'Rear