Exxon Research and Engineering Company

Exxonmobil Research and Engineering Company

Exxonmobil Upstream Research Company

Imperial Oil Limited

Imperial Oil Resources

Joseph L Feimer

Lawrence J Lawlor

Robert C Schucker

Bal K Kaul

Ken N Sury

Bernd A Koenitzer

Tapantosh Chakrabarty

Tan-Jen Chen

Gordon Frederick Stuntz

Donald T Bray

Robert J Falkiner

Tan Jen Chen

Ramesh R Hemrajani

Jeenok Theresa Kim

Clay R Sutton

Ashok Uppal

Charles P Darnell

Dean L Smith, Jr

David N Zinkie

Joseph T O'Bara

Randall Stephen Lachine

Scott E Hommema

Babak Adam Jajuee

Leo T DesJardine

Deborah De La Cruz

Myles W Baker

G Bryce McGarvey

David J LeClair

Frederick Vandervaart

Aaron Ortiz-Gomez

Kaul Bal K

Mcgarvey G Bryce

David J Leclair

Babak A Jajuee

Fred Vandervaart

Aaron Oritz Gomez

Described herein, is a method of dewatering a slurry, the slurry being tailings from bitumen extraction of mined oil sand. The slurry is passed through at least one electro-kinetic thickener having a voltage gradient to separate water from the slurry to produce a dewatered slurry. The electro-kinetic thickener may comprise an auger to move the slurry downstream. The auger has a conductive component in the form of a wire, ribbon or rod as an anode (positive electrode) to attract negatively-charged slurry particles and to repel the positively-charged cations and associated water. The auger is shafted or shaftless. The electro-kinetic thickener may also comprise a porous drum having the auger disposed therein. The porous drum is a cathode (negative electrode) to repel the negatively-charged slurry particles, attract the positively-charged cations and associated water, and allow the water to pass through the porous drum.

Dewatering oil sand tailings

The present disclosure relates to solvent surveillance in heavy oil production. A method includes the steps of measuring an amount of a native bitumen marker (NBM) in a heavy oil, measuring an amount of the NBM in a recovery-aid solvent, measuring an amount of the NBM in a blend including the heavy oil and the recovery-aid solvent, and applying a blending model to determine a fraction of the recovery-aid solvent in the blend.

Solvent surveillance in solvent-based heavy oil recovery processes

Described herein is a method of controlling bitumen quality in a process stream within a solvent-assisted bitumen extraction operation, for instance a hydrocarbon stream from a froth separation unit (FSU). Bitumen quality is a measure of the amount of selected contaminants in the process stream. Contaminants may include asphaltenes (comprising metal porphyrins), sulfur, and inorganic solids (comprising inorganic elements, e.g. Si, Al, Ti, Fe, Na, K, Mg, and Ca). First, the amounts of selected contaminants are measured. Next, these measured values are compared to maximum reference values. If one or more of these contaminants is higher than the maximum reference value, at least one variable of the solvent-assisted bitumen extraction is adjusted to improve bitumen quality.

Controlling bitumen quality in solvent-assisted bitumen extraction

A method and system for determining particle size distribution and/or filterable solids in bitumen-containing fluid is described. A sample of bitumen-containing fluid, such as bitumen-froth feed, bitumen-froth solvent or paraffinic-froth-treated (PFT) bitumen-solvent is obtained. An optimized diluent combination is determined, comprising an aromatic or cycloaliphatic solvent such as toluene, benzene, naphthalene, xylene, anthracene, or cyclohexane together with a C3 to C12 paraffinic solvent. The combination is considered optimized when diluting the sample with the combination maintains substantially the same level of deasphalting in the diluted sample as in the undiluted sample. Upon dilution of the sample with optimized diluent combination, particle size distribution can be accurately determined using optical instrumentation, laser diffraction instrumentation, electrical counting instrumentation, or ultrasonic instrumentation.

Method and system for determining particle size distribution and filterable solids in a bitumen-containing fluid

A process for removing elemental sulfur from liquid hydrocarbon steams such as transportation fuel streams, e.g. gasoline, diesel, kerosene, and jet, by contacting such streams with an immiscible aqueous solution under static mixing conditions. The aqueous solution contains a caustic and an effective amount of a Group I or Group II metal sulfide or polysulfide. The elemental sulfur in the stream is converted to a polysulfide that is not soluble in the hydrocarbon stream but is soluble in the aqueous solution, thus resulting in a hydrocarbon product stream having a substantially lower level of elemental sulfur.

Removal of elemental sulfur in pipelines using static mixers

The invention relates to an improved bitumen recovery process. The process includes adding water to a bitumen-froth/solvent system containing asphaltenes and mineral solids. The addition of water in droplets increases the settling rate of asphaltenes and mineral solids to more effectively treat the bitumen for pipeline transport, further enhancement, refining, or any other application of reduced-solids bitumen.

Upgrading bitumen in a paraffinic froth treatment process

A method for reducing the level of elemental sulfur from sulfur-containing hydrocarbon streams as well as reducing the level of total sulfur in such streams. Preferred hydrocarbon streams include fuel streams such as naphtha streams that are transported through a pipeline. The sulfur-containing hydrocarbon stream is contacted with a mixture of water, a caustic, a surfactant, at least one metal sulfide, and optionally an aromatic mercaptan. This results in an aqueous phase and a hydrocarbon phase containing reduced levels of both elemental sulfur and total sulfur.

Method for reducing the level of elemental sulfur and total sulfur in hydrocarbon streams

A method for reducing the level of elemental sulfur from sulfur-containing hydrocarbon streams as well as reducing the level of total sulfur in such streams. Preferred hydrocarbon streams include fuel streams such as naphtha and distillate streams that are transported through a pipeline. The sulfur-containing hydrocarbon stream is blended with an aqueous solution of water, a caustic, and at least one metal sulfide thereby resulting in an organic phase and an aqueous phase. The blended stream is then passed through a bed of solids having a suitable surface area so that a substantial amount of the sulfur moieties are removed by the aqueous phase.

A process for reducing the level of elemental sulfur and organic sulfur pick-up by refined hydrocarbon streams such as gasoline, diesel, jet fuel, kerosene or fuel additives such as ethers or iso-octane that are transported through a pipeline used to transport various sulfur-containing petroleum streams. The oxygen level in the hydrocarbon stream of interest to be pipelined as well as in at least the first hydrocarbon stream sequenced immediately ahead of the hydrocarbon stream of interest is reduced.

Method for reducing the amount of sulfur pick-up by hydrocarbon streams transported through a pipeline

A process for removing relatively low levels of high molecular weight organic sulfur from hydrocarbon streams, particularly from streams that have picked-up such sulfur while being transported through a pipeline. The hydrocarbon stream containing the organic sulfur is passed through a bed of adsorbent material comprised of a high Ni content, high surface area material that also contains an effective amount of SiOor GeOand an alkaline earth metal.

Method for reducing the amount of high molecular weight organic sulfur picked-up by hydrocarbon streams transported through a pipeline

A process for removing sulfur compounds from hydrocarbon streams by contacting the hydrocarbon stream, especially a gasoline stream, with an adsorbent material. The adsorbent material is regenerated with hydrogen or a hydrogen/HS mixture.

Process to remove sulfur contaminants from hydrocarbon streams

A process for removing sulfur compounds from hydrocarbon feedstreams, particularly those boiling in the naphtha range, by contacting the feedstream with an adsorbent comprised of cobalt and one or more Group VI metals selected from molybdenum and tungsten on a refractory support. This invention also relates to a process wherein a naphtha feedstream is first subjected to selective hydrodesulfurization to remove sulfur but not appreciably saturate olefins. A product stream is produced containing mercaptans that are removed by use of the cobalt-containing adsorbents of the present invention.

Removal of sulfur compounds from hydrocarbon feedstreams using cobalt containing adsorbents in the substantial absence of hydrogen

An improved spiral wound element for separations is disclosed wherein the improvement comprises using as the feed/retentate space one or more layers of a material having an open cross-sectional area in the range 30 to 70% and as the permeate spacer material at least three layers of material two of which are fine and have an open cross-sectional area of about 10 to 50% surrounding a coarse layer having an open cross-sectional area of about 50 to 90%.

Spiral wound element for separation

This invention relates to a method for ultrafiltering heavy hydrocarbons containing detrimental qualities of metals and CCR, said method comprising feeding the heavy hydrocarbons to a first ultrafiltration stage wherein the feed is contacted with an ultrafiltration membrane thereby producing a first permeate and a first retentate and feeding the first permeate to a second ultrafiltration stage wherein the first permeate is contacted with an ultrafiltration membrane which is the same as the ultrafiltration membrane in the first ultrafiltration stage to recover a second permeate of significantly reduced metals and CCR content and a second retentate. The second permeate can be sent to subsequent ultrafiltration stages utilizing the same membrane with permeate from each such stage being used as feed to the next subsequent downstream stage. Retentate from the different stages can be recycled to the feed of the previous upstage ultrafiltration stage or can be combined with the retentate streams from the various ultrafiltration stages.

Multi-stage ultrafiltration process (OP-3711)

The separation of aromatic hydrocarbons from mixtures of aromatic and non-aromatic hydrocarbon feeds under pervaporation conditions, is improved by the control of the amount of oxygen present in the feed. The amount of oxygen in the feed, such as heavy cat naphtha or other cracked feed, should be less than 30 wppm, preferably less than 10 wppm. The oxygen level in the feed can be controlled by the addition of small amount of oxygen scavenger into the feed. Hindered phenols are representative of useful oxygen scavengers.

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Brights Grove, Canada

Joseph L Feimer