Exxonmobil Research and Engineering Company

Exxon Research and Engineering Company

Exxonmobil Technology and Engineering Company

Richard A Demmin

John P Greeley

Bruce R Cook

Thomas R Halbert

Garland B Brignac

Stuart Leon Soled

Ian A Cody

Kenneth L Riley

Benjamin S Umansky

James William Gleeson

Edward John Blok

Sabato Miseo

Edward Stanley Ellis

William John Murphy

Keith K Aldous

Alberto Ravella

Douglas R Boate

Richard Harry Ernst

John E Gallagher

Craig A McKnight

Stephen Harold Brown

Roby Bearden, Jr

William C Baird, Jr

Daniel Paul Leta

Gary Brice McVicker

Lei Zhang

Michael C Clark

Shifang Luke Luo

William E Winter, Jr

Michael F Raterman

Jonathan Martin McConnachie

Randolph John Smiley

Brenda Anne Raich

Gary Paul Schleicher

James Ronald Bielenberg

Chris A Wright

Walter David Vann

Janet Renee Clark

Samia Ilias

Howard J Freund

James Ronald Rigby

Sandra J Alward

James P Glass, Jr

Robert Charles Welch

Teck-Mui Hoo

Tomas R Melli

Douglas Wayne Hissong

David Lee Vannauker

Sandra J Linek

Keith Wilson

Brandon T Stone

James W Gleeson

Jesse R McManus

William Edward Winter, Jr

Fengrong Chen

Darlene Schuette, Legal Representative

Aldrin G Cuevas

Charles Alfred Euker, Jr

Suisheng M Dou

Tech-Mui Hoo

Richard Ernest

Kenneth Lloyd Riley

A method of upgrading refining streams with high polynucleararomatic hydrocarbon (PNA) concentrations can include: hydrocracking a PNA feed in the presence of a catalyst and hydrogen at 380&#xb0; C. to 430&#xb0; C., 2500 psig or greater, and 0.1 hrto 5 hrliquid hourly space velocity (LSHV), wherein the weight ratio of PNA feed to hydrogen is 30:1 to 10:1, wherein the PNA feed comprises 25 wt % or less of hydrocarbons having a boiling point of 700&#xb0; F. (371&#xb0; C.) or less and having an aromatic content of 50 wt % or greater to form a product comprising 50 wt % or greater of the hydrocarbons having a boiling point of 700&#xb0; F. (371&#xb0; C.) or less and having an aromatic content of 20 wt % or less.

Upgrading polynucleararomatic hydrocarbon-rich feeds

Systems and methods are provided for producing upgraded raffinate and extract products from lubricant boiling range feeds and/or other feeds having a boiling range of 400&#xb0; F. (204&#xb0; C.) to 1500&#xb0; F. (816&#xb0; C.) or more. The upgraded raffinate and/or extract products can have a reduced or minimized concentration of sulfur, nitrogen, metals, or a combination thereof. The reduced or minimized concentration of sulfur, nitrogen, and/or metals can be achieved by hydrotreating a suitable feed under hydrotreatment conditions corresponding to relatively low levels of feed conversion. Optionally, the feed can also dewaxed, such as by catalytic dewaxing or by solvent dewaxing. Because excessive aromatic saturation is not desired, the pressure for hydrotreatment (and optional dewaxing) can be 500 psig (&#x2dc;3.4 MPa) to 1200 psig (&#x2dc;8.2 MPa).

Production of upgraded extract and raffinate

A process for producing high yields of higher quality (API Group II, Group III') lubricating oil basestock fractions which allows the production of two or more types of high quality lubes in continuous mode (no blocked operation mode) without transition times and feed or intermediate product tankage segregation. Two consecutive hydroprocessing steps are used: the first step processes a wide cut feed at a severity needed to match heavy oil lube properties. The second step hydroprocesses a light oil after fractionation of the liquid product from the first step at a severity higher than for the heavy oil fraction. The two hydroprocessing steps will normally be carried out in separate reactors but they may be combined in a single reactor which allows for the two fractions to be processed with different degrees of severity.

Hydrocracking process for high yields of high quality lube products

Fuels hydrocracking can be used to generate a variety of product slates. Varying the temperature can allow an amount of naphtha product and an amount of unconverted product to be varied. The method can be enabled by a hydrocracking catalyst that includes a combination of metals with activity for hydrodesulfurization.

Catalyst and method for fuels hydrocracking

Hydrocarbon feedstreams are desulfurized using an alkali metal reagent, optionally in the presence of hydrogen. Improved control over reaction conditions can be achieved in part by controlling the particle size of the alkali metal salt and by using multiple desulfurization reactors. The processes herein allow a simple and effective method for removing the majority of coke formed in the alkali metal reagent reactions with the hydrocarbon feedstreams. This makes it cost effective to run such processes at higher severities (which result in higher coke production) thereby resulting in increased amounts of valuable converted hydrocarbon product yields. The process improvements herein may also be used to increase total throughput through a unit due to the ability to effectively manage higher coke content in the reaction products.

Alkali metal hydroprocessing of heavy oils with enhanced removal of coke products

The invention relates to a hydrocracking process for hydrocracking petroleum and chemical feedstocks using bulk Group VIII/VIB catalysts. Preferred catalysts include those comprised of Ni&#x2014;Mo&#x2014;W.

Hydrocracking process using bulk group VIII/Group VIB catalysts

Naphtha hydrodesulfurization selectivity is increased by reducing the amount of CO(CO plus &#xbd; CO) in the hydrodesulfurization reaction zone to less than 100 vppm. While this is useful for non-selective hydrodesulfurization, it is particularly useful for selectively desulfurizing an olefin-containing naphtha without octane loss due to olefin saturation by hydrogenation. The COreduction is achieved by removing COfrom the treat gas before it is passed into the reaction zone.

Low CO for increased naphtha desulfurization

A process for the selective hydrodesulfurization of naphtha streams containing a substantial amount of olefins and organically bound sulfur. The naphtha stream is selectively hydrodesulfurized by passing it through a first reaction zone containing a bed of a first hydrodesulfurization catalyst, then passing the resulting product stream through a second reaction zone containing a bed of a second hydrodesulfurization catalyst, which second hydrodesulfurization catalyst contains a lower level of catalytic metals than the first hydrodesulfurization catalyst.

Multi-stage hydrodesulfurization of cracked naphtha streams with a stacked bed reactor

A process for hydrofining a lubricating oil feedstock comprising contacting the feedstock with a hydrofining catalyst in a hydrofining zone under hydrofining conditions wherein the hydrofining catalyst comprises a bulk metal catalyst containing non-noble Group VIII metal molybdate in which at least a portion but less than all of the molybdenum is replaced by tungsten.

Hydrofining process using bulk group VIII/Group VIB catalysts

A process for reducing the amount of mercaptan sulfur in a petroleum stream without significantly changing its octane value. The process comprising a three-phase system wherein the petroleum stream to be treated is passed through a fixed bed of catalyst in the presence of a stripping gas. The stripping gas can be either hydrogen containing gas or an method wherein the composition of the catalyst utilized varies according to the stripping gas.

Catalytic stripping for mercaptan removal (ECB-0004)

Hydroconversion process of petroleum and chemical feedstocks using bulk Group VIII/Group VIB catalysts. Preferred catalysts include those comprised of Ni&mdash;Mo&mdash;W.

Hydroconversion process using bulk group VIII/Group VIB catalysts

The invention relates to naphtha hydrodesulfurization incorporating either high temperature depressurization or controlled heating for mercaptan removal. More particularly, the invention relates to a naphtha hydrodesulfurization process, wherein the hot naphtha exiting the desulfurization reactor contains mercaptans, most of which are removed without olefin loss, by depressurizing the hot naphtha, thermally treating the hot naphtha, or some combination thereof. The desulfurized naphtha may be cooled and condensed to a liquid, separated from the gaseous H S, stripped and sent to a mogas pool.

High temperature depressurization for naphtha mercaptan removal

A process for producing a lubricating oil basestock having at least 90 wt. % saturates and a VI of at least 105 by selectively hydroconverting a raffinate from a solvent extraction zone in a two step hydroconversion zone followed by a hydrofinishing zone, and a lubricating oil basestock produced by said process.

Hydroconversion process for making lubricating oil basestocks

A high temperature naphtha desulfurization process with reduced olefin saturation employs a partially spent and low metals content hydrodesulfurization catalyst having from 2-40% the activity of a new catalyst. The catalytic metals preferably include Co and Mo in an atomic ratio of from 0.1 to 1. The catalyst is preferably at least partially regenerable, has less than 500 wppm of a total of one or more of nickel, iron and vanadium and preferably has no more than 12 wt. % catalytic metal calculated as the oxide. This permits selective deep desulfurization, with reduced olefin saturation, low product mercaptan levels and little or need for downstream mercaptan removal.

High temperature naphtha desulfurization using a low metal and partially deactivated catalyst

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Highland Park, NJ, United States of America

Richard A Demmin