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Title:
METHOD FOR PREPARING A DILUTED HYDROCARBON COMPOSITION, AND DILUTED HYDROCARBON COMPOSITIONS
Document Type and Number:
WIPO Patent Application WO/2009/126974
Kind Code:
A2
Abstract:
A diluent obtained by a) contacting a crude feed with hydrogen and one or more catalysts to produce a crude product; wherein at least one of the catalysts comprises one or more metals from Column 6 of the Periodic Table and/or one or more compounds of one or more metals from Columns 6 of the Periodic Table; and wherein contacting conditions are controlled at a partial pressure of hydrogen of least 3 MPa and a temperature of least 200 °C; b) separating the crude product into two or more portions, c) producing a diluent from at least part of at least one portion obtained in step b). Methods of preparing a diluted hydrocarbon composition using such diluent and diluted hydrocarbon compositions so obtained.

Inventors:
BHAN, Opinder, Kishan (714 Cranfield Court, Katy, TX, 77450, US)
WELLINGTON, Scott, Lee (5109 Aspen Street, Bellaire, TX, 77401, US)
Application Number:
US2009/046922
Publication Date:
October 15, 2009
Filing Date:
June 10, 2009
Export Citation:
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Assignee:
SHELL OIL COMPANY (One Shell Plaza, P.O. Box 2463Houston, TX, 77252-2463, US)
SHELL INTERNATIONALE RESEARCH MAATSCHAPPIJ B.V. (Carel Van Bylandtlaan 30, HR The Hague, Hague, NL)
BHAN, Opinder, Kishan (714 Cranfield Court, Katy, TX, 77450, US)
WELLINGTON, Scott, Lee (5109 Aspen Street, Bellaire, TX, 77401, US)
International Classes:
C10G45/04; C10G47/02; C10G49/02
Attorney, Agent or Firm:
TAYLOR, Richard, B. (Shell Oil Company, One Shell PlazaP.O. Box 246, Houston TX, 77252-2463, US)
Download PDF:
Claims:

C L A I M S

1. A method for preparing a diluted hydrocarbon composition comprising: a) contacting a hydrocarbon feed with one or more catalysts in the presence of a hydrogen source to produce a crude product; wherein at least one of the catalysts comprises one or more metals from Column 6 of the Periodic Table and/or one or more compounds of one or more metals from Columns 6 of the Periodic Table; and wherein contacting conditions are controlled at a partial pressure of hydrogen of least 3 MPa and a temperature of least 200 0 C; b) separating the crude product into two or more portions; c) mixing at least part of at least one portion obtained in step b) with a dilutable hydrocarbon composition to produce a diluted hydrocarbon composition.

2. The method of claim 1, wherein the hydrocarbon feed comprises at least 0.0001 grams of hydrocarbons of a vacuum gas oil fraction having a boiling range distribution between 343 0 C and 538 0 C at 0.101 MPA per gram of hydrocarbon feed, wherein the vacuum gas oil fraction (VGO) fraction comprises at least 0.05 grams of UV aromatics per gram of VGO fraction; and wherein the boiling range distribution is as determined by ASTM Method D5307.

3. The method of claim 2, wherein in step b) the crude product is separated into two or more portions, of which at least one portion comprises a vacuum gas oil fraction having a boiling range distribution between 343 0 C and 538 0 C at

0.101 MPA, which vacuum gas oil fraction comprises the same or a higher weight amount of total UV aromatics than the vacuum gas oil fraction in the hydrocarbon feed.

4. The method of claim 1, wherein in step b) the crude product is separated into two or more portions, of which at least one portion comprises a vacuum gas oil fraction having a boiling range distribution between 343 0 C and 538 0 C at 0.101 MPA and wherein in step c) the portion comprising the vacuum gas oil fraction is mixed with a dilutable hydrocarbon composition to produce the diluted hydrocarbon composition .

5. The method of claim 1, wherein the a crude feed is separated into at least two portions and wherein one portion is used as the hydrocarbon feed in step a) and wherein a second portion is used as a dilutable hydrocarbon composition in step c) .

6. The method of claim 1, wherein the a crude product in step a) is separated into at least two portions and wherein one portion of the crude product is fractionated into two or more fractions, of which at least one fraction comprises a vacuum gas oil fraction having a boiling range distribution between 343 0 C and 538 0 C at 0.101 MPA and wherein a second portion of the crude product is used as a dilutable hydrocarbon composition in step c) .

7. The method of claim 1, wherein in step c) at least one portion obtained in step b) is recycled and mixed with the hydrocarbon feed in step a) . 8. The method of claim 1, wherein step c) comprises mixing at least part of at least one portion obtained in step b) with a dilutable hydrocarbon composition to produce a transportation fuel.

9. A diluent obtained by a) contacting a crude feed with hydrogen and one or more catalysts to produce a crude product; wherein at least one of the catalysts comprises one or more metals from Column 6 of the Periodic Table and/or one or more compounds

of one or more metals from Columns 6 of the Periodic Table; and wherein contacting conditions are controlled at a partial pressure of hydrogen of least 3 MPa and a temperature of least 200 0 C; b) separating the crude product into two or more portions, c) producing a diluent from at least part of at least one portion obtained in step b) 10. The diluent of claim 9, wherein the crude feed comprises at least 0.0001 grams of hydrocarbons of a vacuum gas oil fraction having a boiling range distribution between 343 0 C and 538 0 C at 0.101 MPA per gram of hydrocarbon feed, wherein the vacuum gas oil fraction comprises at least 0.05 grams of total UV aromatics per gram of VGO fraction; and wherein the boiling range distribution is as determined by ASTM Method D5307.

11. A diluent having a boiling range distribution between 650 0 F and 1000 0 F (343 0 C and 538 0 C) at 0.101 MP comprising at least 20 wt% grams of UV aromatics, which diluent comprises at least 0.1 wt% mono-aromatics at least 0.1 wt% di-aromatics at least 0.1 wt% tri-aromatics; and at least 0.1 wt% tetra-aromatics

12. A diluted crude feed comprising in the range from 10 to 90 wt% of a crude feed and in the range from 10 to 90wt% of a diluent as claimed in anyone of claims 9-11.

13. A method of preparing a transportion fuel comprising processing the diluted crude feed as claimed in claim 12 in a refinery.

14. A method for diluting a hydrocarbon composition with a diluent as claimed in anyone of claims 9-11.

Description:

DILUENTS, METHOD FOR PREPARING A DILUTED HYDROCARBON COMPOSITION, AND DILUTED HYDROCARBON COMPOSITIONS

Field of the Invention The present invention relates to diluents, methods for preparing a diluted hydrocarbon composition and diluted hydrocarbon compositions.

Background of the invention

Crudes that have one or more unsuitable properties that do not allow the crudes to be economically transported or processed using conventional facilities are commonly referred to as "disadvantaged crudes".

One way of making such disadvantaged crudes transportable may be by converting components such as micro-carbon residue (MCR) of the disadvantaged crude.

Conventional methods of converting MCR include contacting the disadvantaged crude at elevated temperatures and pressure with hydrogen in the presence of a catalyst.

During such conventional contacting, ultra-violet aromatic hydrocarbons (UV aromatics) in the disadvantaged crude may be hydrogenated to form saturated hydrocarbons . The formation of saturated hydrocarbons may change the solubility properties of various hydrocarbons in the disadvantaged crudes (for example, solubility properties of polar compounds such as asphaltenes and/or high molecular weight compounds) . The change in solubility may disadvantageously result in phase separation of some of the components during processing. Formation of two phases during processing may also disadvantageously reduce the life of conventional catalysts and/or disadvantageously affect the efficiency of the process.

Additionally, processing at high temperatures and pressures tends to promote formation of coke and/or other

precipitates . Coke and/or other precipitates may accumulate in pores of the catalyst, reducing the activity of the catalyst and the life of the catalyst.

Another way of making disadvantaged crudes transportable may be by mixing the crude with a diluent.

U.S. Patent Nos . 4,225,421 to Hensley, 5,928,499 to Sherwood Jr. et al . , 6,554,994 to Reynolds et al . , 6,436,280 to Harle et al . , 5,928,501 to Sudhakar et al . , 4,937,222 to Angevine et al . , 4,886,594 to Miller, 4,746,419 to Peck et al., 4,548,710 to Simpson, 4,525,472 to Morales et al . ,

4,499,203 to Toulhoat et al., 4,389,301 to Dahlberg et al . , and 4,191,636 to Fukui et al . describe various processes, systems, and catalysts for processing crudes and/or disadvantaged crudes. U.S. Published Patent Application Nos. 20050133414 through 20050133418 to Bhan et al . ; 20050139518 through 20050139522 to Bhan et al . , 20050145543 to Bhan et al . , 20050150818 to Bhan et al . , 20050155908 to Bhan et al . , 20050167320 to Bhan et al . , 20050167324 through 20050167332 to Bhan et al . , 20050173301 through 20050173303 to Bhan et al., 20060060510 to Bhan; 20060231465 to Bhan; 20060231456 to Bhan; 20060234876 to Bhan; 20060231457 to Bhan and 20060234877 to Bhan; 20070000810 to Bhan et al . ; 20070000808 to Bhan; 20070000811 to Bhan et al . ; International Publication Nos. WO 02/32570, WO 2008/016969, and WO 2008/106979 to Bhan; and U.S. Patent Application Nos. 11/866,909; 11/866,916; 11/866,921 through 11/866,923; 11/866,926; 11/866,929 and 11/855,932 to Bhan et al., filed October 3, 2007, are related patent applications and describe various processes, systems, and catalysts for processing crudes and/or disadvantaged crudes.

International Application Publication No. WO 02/32570 to Bhan describes a catalyst for hydrodemetallation of a heavy

hydrocarbon stream. The catalyst has a bimodal pore structure and is prepared by mixing at least 20% alumina fines and metal from Column 6 and Column 10 of the Periodic Table. The catalyst was found to be effective at removing metals from heavy oil fractions containing high concentrations of nickel and vanadium while exhibiting good stability. This publication does not describe ultra-violet aromatics content of the product relative to the ultraviolet aromatic content of the feed. Non-prepublished International Application Publication

No. WO2008/045757 describes in example 26 the preparation of a column 6 metal catalyst containing mineral oxide fines. In example 27 a process is described comprising contacting of a hydrocarbon feed (i.e. crude from Peace River) with the molybdenum catalyst containing mineral oxide fines of example 26 to produce a crude product. In figure 23 of WO2008/045757 the VGO portion of the product obtained in such a process is specified.

It would be desirable to have a method to economically convert disadvantaged crudes to transportable crude products .

It would further be advantageous is large amounts of disadvantaged crudes can be made transportable with limited processing . Summary of the invention

A method has now been found to convert a large amount of a crude feed, such as a disadvantaged crude, with limited processing of such same crude feed by converting at least a first part of the crude feed with a catalyst in the presence of a hydrogen source into a crude product having a lower MCR content and/or a lower viscosity; and subsequently using at least a portion of such crude product to dilute at least

part of the remaining crude feed or to dilute another crude feed.

The method that has been found is further especially advantageous as it can be used to prepare a crude product that has a reduced MCR and/or a reduced viscosity, whilst the content of ultra-violet aromatic hydrocarbons is maintained or increased. The maintained or increased content of ultra-violet aromatic hydrocarbons allows one to maintain solubility of high molecular weight compounds in the crude feed / crude product mixture formed during processing, which allows one to enhance stability of the disadvantaged feed/total product mixture during contacting. For the same reason the maintained or increased content of ultra-violet aromatic hydrocarbons makes the crude product or portions thereof very advantageous diluents for diluting further crude feed.

Accordingly, the invention provides a method for preparing a diluted hydrocarbon composition comprising: a) contacting a hydrocarbon feed with one or more catalysts in the presence of a hydrogen source to produce a crude product; wherein at least one of the catalysts comprises one or more metals from Column 6 of the Periodic Table and/or one or more compounds of one or more metals from Columns 6 of the Periodic Table; and wherein contacting conditions are controlled at a partial pressure of hydrogen of least 3 MPa and a temperature of least 200 0 C; b) separating the crude product into two or more portions; c) mixing at least part of at least one portion obtained in step b) with a dilutable hydrocarbon composition to produce a diluted hydrocarbon composition.

Preferably the hydrocarbon feed comprises at least 0.0001 grams of hydrocarbons of a vacuum gas oil fraction having a boiling range distribution between 343 0 C and 538 0 C at 0.101 MPA per gram of hydrocarbon feed and preferably this vacuum gas oil fraction (VGO) fraction comprises at least 0.05 grams of UV aromatics per gram of VGO fraction; and preferably the boiling range distribution is as determined by ASTM Method D530.

The crude product obtained in step a) or a portion of this crude product obtained in step b) may have a MCR content of at most 90% of the hydrocarbon feed MCR content and wherein the total UV aromatics content in a VGO fraction of the crude product is greater than or equal to the total UV aromatics content in the VGO fraction of the hydrocarbon feed, and wherein MCR content is as determined by ASTM Method D4530.

Further, in some embodiments, the invention provides a transportation fuel comprising one or more distillate fractions produced from the hydrocarbon composition mentioned above and/or a diluent produced from the crude product mentioned above.

Further, in some embodiments, the invention provides a diluent obtained by a) contacting a crude feed with hydrogen and one or more catalysts to produce a crude product; wherein the crude feed comprises at least 0.0001 grams of hydrocarbons of a vacuum gas oil fraction having a boiling range distribution between 343 0 C and 538 0 C at 0.101 MPA per gram of hydrocarbon feed, wherein the vacuum gas oil fraction comprises at least 0.05 grams of total UV aromatics per gram of VGO fraction; and wherein the boiling range distribution is as determined by ASTM Method D5307;

wherein at least one of the catalysts comprises one or more metals from Column 6 of the Periodic Table and/or one or more compounds of one or more metals from Columns 6 of the Periodic Table; and wherein contacting conditions are controlled at a partial pressure of hydrogen of least 3 MPa and a temperature of least 200 0 C; b) separating the crude product into two or more portions, c) producing a diluent from at least part of at least one portion obtained in step b) .

Further, in some embodiments, the invention provides a diluent, having a boiling range distribution between 650 0 F and 1000 0 F (343 0 C and 538 0 C) at 0.101 MP comprising at least 20 wt% grams of UV aromatics, which diluent comprises at least 0.1 wt% mono-aromatics at least 0.1 wt% di-aromatics at least 0.1 wt% tri-aromatics; and at least 0.1 wt% tetra-aromatics .

Further the invention provides a method wherein a hydrocarbon composition, such as a crude feed, is diluted with a diluent, which diluent has a boiling range distribution between 650 0 F and 1000 0 F (343 0 C and 538 0 C) at 0.101 MP, which diluent comprises at least 20 wt% grams of UV aromatics, and which diluent comprises at least 0.1 wt% mono-aromatics at least 0.1 wt% di-aromatics at least 0.1 wt% tri-aromatics; and at least 0.1 wt% tetra-aromatics.

In addition, the invention provides a transportation fuel comprising the diluent and/or a diluent/crude feed mixture as mentioned above.

Brief description of the drawings

The invention is illustrated by the following figures:

FIG. 1 is a schematic of an embodiment of a contacting system. FIG. 2 is a schematic of an embodiment of an embodiment of a separation system.

Detailed description of the invention

Terms used herein are defined as follows.

"ASTM" refers to American Standard Testing and Materials. "API gravity" refers to API gravity at 15.5 0 C (60 0 F) . API gravity is as determined by ASTM Method D6822.

Atomic hydrogen percentage and atomic carbon percentage of the hydrocarbon feed and the crude product are as determined by ASTM Method D5291. Boiling range distributions for the hydrocarbon feed, the total product, and/or the crude product are as determined by ASTM Method D5307 unless otherwise mentioned.

"C 5 asphaltenes" refers to asphaltenes that are insoluble in n-pentane. C 5 asphaltenes content is as determined by ASTM Method D2007.

"C 7 asphaltenes" refers to asphaltenes that are insoluble in n-heptane. C 7 asphaltenes content is as determined by ASTM Method D3279.

"Column X metal (s)" refers to one or more metals of Column X of the Periodic Table and/or one or more compounds of one or more metals of Column X of the Periodic Table, in which X corresponds to a column number (for example, 1-12) of the Periodic Table. For example, "Column 6 metal (s)" refers to one or more metals from Column 6 of the Periodic Table and/or one or more compounds of one or more metals from Column 6 of the Periodic Table.

"Column X element (s)" refers to one or more elements of Column X of the Periodic Table, and/or one or more compounds

of one or more elements of Column X of the Periodic Table, in which X corresponds to a column number (for example, 13- 18) of the Periodic Table. For example, "Column 15 element (s)" refers to one or more elements from Column 15 of the Periodic Table and/or one or more compounds of one or more elements from Column 15 of the Periodic Table.

In the scope of this application, weight of a metal from the Periodic Table, weight of a compound of a metal from the Periodic Table, weight of an element from the Periodic Table, or weight of a compound of an element from the

Periodic Table is calculated as the weight of metal or the weight of element. For example, if 0.1 grams of MoO 3 is used per gram of catalyst, the calculated weight of the molybdenum metal in the catalyst is 0.067 grams of molybdenum metal per gram of catalyst.

"Content" refers to the weight of a component in a substrate (for example, a hydrocarbon feed, a total product, or a crude product) expressed as weight fraction or weight percentage based on the total weight of the substrate. "Wtppm" refers to parts per million by weight.

"Crude feed" refers to a crude and/or disadvantaged crude that is to be treated herein.

"Crude feed/total product mixture" or "hydrocarbon feed/total product" refers to the mixture that contacts the catalyst during processing.

"Distillate" refers to hydrocarbons with a boiling range distribution between 182 0 C (360 0 F) and 343 0 C (650 0 F) at 0.101 MPa. Distillate content is as determined by ASTM Method D5307. "Heteroatoms" refers to oxygen, nitrogen, and/or sulfur contained in the molecular structure of a hydrocarbon. Heteroatoms content is as determined by ASTM Methods E385 for oxygen, D5762 for total nitrogen, and D4294 for sulfur.

"Total basic nitrogen" refers to nitrogen compounds that have a pKa of less than 40. Basic nitrogen ("bn") is as determined by ASTM Method D2896.

"Hydrocarbon feed" refers to a feed that includes hydrocarbons. Hydrocarbon feed may include, but is not limited to, crudes, disadvantaged crudes, stabilized crudes, bitumen, crude oil, pitch, hydrocarbons obtained from refinery processes, or mixtures thereof.

"Hydrogen source" refers to a source of hydrogen and includes hydrogen gas, and/or a compound and/or compounds, that when in the presence of a hydrocarbon feed and the catalyst, react to provide hydrogen. A hydrogen source may include, but is not limited to, hydrogen gas, hydrocarbons (for example, C x to C 4 hydrocarbons such as methane, ethane, propane, and butane), water, or mixtures thereof. A mass balance may be conducted to assess the net amount of hydrogen provided.

"LHSV" refers to a volumetric liquid feed rate per total volume of catalyst and is expressed in hours (h "1 ) . Total volume of catalyst is calculated by summation of all catalyst volumes in the contacting zones, as described herein .

"Liquid mixture" refers to a composition that includes one or more compounds that are liquid at standard temperature and pressure (25 0 C, 0.101 MPa, hereinafter referred to as "STP") , or a composition that includes a combination of one of more compounds that are liquid at STP with one or more compounds that are solids at STP. "Periodic Table" refers to the Periodic Table as specified by the International Union of Pure and Applied Chemistry (IUPAC), November 2003.

"Metals in metal salts of organic acids" refer to alkali metals, alkaline-earth metals, zinc, arsenic, chromium, or

combinations thereof. A content of metals in metal salts of organic acids is as determined by ASTM Method D1318. "Micro-Carbon Residue" ("MCR") content refers to a quantity of carbon residue remaining after evaporation and pyrolysis of a substrate. MCR content is as determined by ASTM Method D4530.

"Mineral-oxide fines" refers to oxides of metals ground to desired particle size. Examples of oxides of metals include, but are not limited to, alumina, silica, silica- alumina, titanium oxide, zirconium oxide, magnesium oxide, or mixtures thereof.

"Molybdenum content in the hydrocarbon feed" refers to the content of molybdenum in the feed. The molybdenum content includes the amount of inorganic molybdenum and organomolybdenum in the feed. Molybdenum content in the hydrocarbon feed is as determined by ASTM Method D5807.

"Ni/V/Fe" refers to nickel, vanadium, iron, or combinations thereof.

"Ni/V/Fe content" refers to the content of nickel, vanadium, iron, or combinations thereof. The Ni/V/Fe content includes inorganic nickel, vanadium and iron compounds and/or organonickel, organovanadium, and organoiron compounds. The Ni/V/Fe content is as determined by ASTM Method D5708. "Nm 3 /m 3 " refers to normal cubic meters of gas per cubic meter of hydrocarbon feed.

"Non-condensable gas" refers to components and/or mixtures of components that are gases at STP.

"Organometallic" refers to compound that includes an organic compound bonded or complexed with a metal of the Periodic Table. "Organometallic content" refers to the total content of metal in the organometallic compounds .

Organometallic content is as determined by ASTM Method D5807.

"P (peptization) value" or "P-value" refers to a numeral value, which represents the flocculation tendency of asphaltenes in the hydrocarbon feed. P-Value is as determined by ASTM Method D7060.

"Pore diameter", "median pore diameter", and "pore volume" refer to pore diameter, median pore diameter, and pore volume, as determined by ASTM Method D4284 (mercury porosimetry at a contact angle equal to 140°) . A micromeritics ® A9220 instrument (Micromeritics Inc., Norcross, Georgia, U.S.A.) may be used to determine these values .

"Sediment" refers to impurities and/or coke that are insoluble in the hydrocarbon feed/total product mixture. Sediment is as determined by ASTM Method D4807. Sediment may also be determined by the Shell Hot Filtration Test ("SHFST") as described by Van Kernoort et al . in the Jour. Inst. Pet., 1951, pages 596-604. "SCFB" refers to standard cubic feet of gas per barrel of hydrocarbon feed.

"Surface area" of a catalyst is as determined by ASTM Method D3663.

"VGO" refers to hydrocarbons with a boiling range distribution between 343 0 C (650 0 F) and 538 0 C (1000 0 F) at 0.101 MPa. VGO content is as determined by ASTM Method D5307.

"Viscosity" refers to kinematic viscosity at 37.8 0 C (100 0 F) . Viscosity is as determined using ASTM Method D445. "Wtppm" refers to parts per million by weight.

"UV aromatics" refer to hydrocarbons that include at least one benzene ring. "Mono-aromatics" refer to hydrocarbon compounds that include one benzene ring. "Di¬

ll

aromatics" refer to hydrocarbon compounds that include two fused benzene rings (for example, naphthalene) . "Tri- aromatics refer to hydrocarbon compounds that include three fused benzene rings (for example, phenanthrenes) . "Tetra- aromatics" refer to hydrocarbon compounds that include 4 fused benzene rings (for example, tetraphenes) . UV aromatics is as determined by the method described by Burdett et al . in "Determination of Aromatic Hydrocarbons in Lubricating Oil Fractions by Far Ultra-Violet Absorption Spectroscopy" in "Molecular Spectroscopy: Report of a Conference Organized by The Spectroscopic Panel of the Hydrocarbon Research Group of the Institute of Petroleum and Held in London, 28-29 October, 1954", pages 30-41.

"Total UV aromatics" or "total UV aromatics content" refers to the total content of UV aromatics in any specific composition such as for example a feed, product or product portion

In the context of this application, it is to be understood that if the value obtained for a property of the substrate tested is outside of limits of the test method, the test method may be modified and/or recalibrated to test for such property.

"Hydrocarbon feed" refers to a feed that includes hydrocarbons . The hydrocarbon feed may include, but is not limited to, crudes, disadvantaged crudes, stabilized crudes, bitumen, crude oil, pitch, hydrocarbons obtained from refinery processes, or mixtures thereof. Examples of hydrocarbon feed obtained from refinery processes include, but are not limited to, long residue, short residue, naphtha, gasoil and/or hydrocarbons boiling above 538 0 C (1000 0 F) , or mixtures thereof.

In one embodiment the hydrocarbon feed is a crude, herein also referred to as crude feed. Crude or crude feed refers to a feed of hydrocarbons which has been produced and/or retorted from hydrocarbon containing formations and which has not yet been fractionally distilled in a treatment facility to produce multiple components with specific boiling range distributions, such as atmospheric distillation methods and/or vacuum distillation methods. Crudes may be solid, semi-solid, and/or liquid. Crudes may include for example coal, bitumen, tar sands or crude oil. The crude or crude feed may be stabilized to form a stabilized crude, also referred to as stabilized crude feed. Stabilization may include, but is not limited to, removal of non-condensable gases, water, salts, or combinations thereof from the crude to form a stabilized crude. In addition any previously added diluent may be flashed off. Such stabilization may often occur at, or proximate to, the production and/or retorting site.

Undistilled and/or unfractionated stabilized crudes may include components that have a carbon number above 4 in quantities of at least 0.5 grams of components per gram of crude. Examples of stabilized crudes include whole crudes, topped crudes, desalted crudes, desalted topped crudes, or combinations thereof. "Topped" refers to a crude that has been treated such that at least some of the components that have a boiling point below 35 0 C at 0.101 MPa (95 0 F at 1 atm) have been removed. Topped crudes may have a content of at most 0.1 grams, at most 0.05 grams, or at most 0.02 grams of such components per gram of the topped crude. Some crudes have one or more unsuitable properties that render them disadvantaged. Disadvantaged crudes may be unacceptable to a transportation carrier and/or a treatment

facility, thus imparting a low economic value to the disadvantaged crude.

In some embodiments, the crude or disadvantaged crude (either topped or untopped) is separated prior to contact with one or more catalysts in a contacting zone. During the separation process, at least a portion of the disadvantaged crude is separated using techniques known in the art (for example, sparging, membrane separation, pressure reduction) to produce the hydrocarbon feed. For example, water may be at least partially separated from the disadvantaged crude. In another example, components that have a boiling range distribution below 95 0 C or below 100 0 C may be at least partially separated from the disadvantaged crude to produce the hydrocarbon feed. In some embodiments, at least a portion of naphtha and compounds more volatile than naphtha are separated from the crude or disadvantaged crude. The hydrocarbon feed, such as for example a crude feed, preferably has a viscosity of at least 10 cSt at 37.8 0 C, at least 100 cSt, at least 1000 cSt, or at least 2000 cSt at 37.8 0 C; preferably has an API gravity at most 19, at most 15, or at most lOand preferably has an API gravity of at least 5. The hydrocarbon feed, such as for example a crude feed, preferably has a residue content per gram of hydrocarbon feed of at least 0.01 grams, more preferably at least 0.2 grams of residue, still more preferably at least 0.3 grams of residue, even more preferably at least 0.5 grams of residue. The hydrocarbon feed, such as for example a crude feed, preferably has a C 5 asphaltenes content of at least 0.04 grams or at least 0.08 grams of C 5 asphaltenes per gram of hydrocarbon feed; and/or at least 0.02 grams or at least 0.04 grams of C 7 asphaltenes per gram of hydrocarbon feed;

and preferably it has a MCR content of at least 0.002 grams of MCR per gram of hydrocarbon feed.

Examples of crudes that might be treated using the processes described herein include, but are not limited to, crudes from of the following regions of the world: U.S. Gulf Coast and southern California, Canada Tar sands, Brazilian Santos and Campos basins, Egyptian Gulf of Suez, Chad, United Kingdom North Sea, Angola Offshore, Chinese Bohai Bay, Venezuelan Zulia, Malaysia, and Indonesia Sumatra. Treatment of a hydrocarbon feed in accordance with embodiments described herein may include contacting the hydrocarbon feed with the catalyst (s) in a contacting zone and/or combinations of two or more contacting zones. In a contacting zone, at least one property of a hydrocarbon feed may be changed by contact of the hydrocarbon feed with one or more catalysts relative to the same property of the hydrocarbon feed. Contacting is performed in the presence of a hydrogen source. In some embodiments, the hydrogen source can comprise hydrocarbons that, under certain contacting conditions, react to provide relatively small amounts of hydrogen to compound (s) in the hydrocarbon feed. Preferably the hydrogen source is hydrogen.

FIG. 1 is a schematic of contacting system 100 that includes contacting zone 102. The hydrocarbon feed enters upstream contacting zone 102 via hydrocarbon feed conduit 104. A contacting zone may be a reactor, a portion of a reactor, multiple portions of a reactor, or combinations thereof. Examples of a contacting zone include a stacked bed reactor, a fixed bed reactor, an ebullating bed reactor, a continuously stirred tank reactor ("CSTR") , a fluidized bed reactor, a spray reactor, and a liquid/liquid contactor. Configuration of one or more contacting zones is described in U.S. Published Patent Application No. 20050133414 to Bhan

et al . , which is incorporated herein by reference. In certain embodiments, the contacting system is on or coupled to an offshore facility. Contact of the hydrocarbon feed with catalyst (s) in contacting system 100 may be a continuous process or a batch process.

The contacting zone may include one or more catalysts (for example, two catalysts) .

In certain embodiments, a volume of catalyst in the contacting zone is in a range from 10 vol% to 60 vol%, 20 vol% to 50 vol%, or 30 vol% to 40 vol% of a total volume of hydrocarbon feed in the contacting zone. In some embodiments, a slurry of catalyst and hydrocarbon feed may include from 0.001 grams to 10 grams, 0.005 grams to 5 grams, or 0.01 grams to 3 grams of catalyst per 100 grams of hydrocarbon feed in the contacting zone.

Temperature in the contacting zone may range from 350 0 C to 450 0 C, from 360 0 C to 440 0 C, or from 370 0 C to 430 °C. LHSV of the hydrocarbon feed will generally range from 0.1 h "1 to 30 h "1 , 0.4 h "1 to 25 h "1 , 0.5 h "1 to 20 h "1 , 1 h "1 to 15 h "1 , 1.5 h "1 to 10 h "1 , or 2 h "1 to 5 h "1 . In some embodiments, LHSV is at least 5 h -1 , at least 11 h -1 , at least 15 h -1 , or at least 20 h -1 . A partial pressure of hydrogen in the contacting zone may range from 3 MPa to 8 MPa, 3 MPA to 7 MPa, 3 MPa to 6 MPa, or 3 MPa to 5 MPa. In some embodiments, a partial pressure of hydrogen may be at most 7 MPa, at most 6 MPa, at most 5 MPa, at most 4 MPa.

In embodiments in which the hydrogen source is supplied as a gas (for example, hydrogen gas) , a ratio (as determined at normal conditions of 20 0 C temperature and 1.013 bar pressure ) of the gaseous hydrogen source to the hydrocarbon feed may range from 0.1 m 3 /m 3 to 100,000 m 3 /m 3 , 0.5 m 3 /m 3 to 10,000 m 3 /m 3 , 1 m 3 /m 3 to 8,000 m 3 /m 3 , 2 m 3 /m 3 to 5,000 m 3 /m 3 , 5 m 3 /m 3 to 3,000 m 3 /m 3 , or 10 m 3 /m 3 to 800 m 3 /m 3 contacted with

the catalyst (s) . The hydrogen source, in some embodiments, is combined with carrier gas(es) and recirculated through the contacting zone. Carrier gas may be, for example, nitrogen, helium, and/or argon. The carrier gas may facilitate flow of the hydrocarbon feed and/or flow of the hydrogen source in the contacting zone(s) . The carrier gas may also enhance mixing in the contacting zone(s) . In some embodiments, a hydrogen source (for example, hydrogen, methane or ethane) may be used as a carrier gas and recirculated through the contacting zone.

The hydrogen source may enter contacting zone 102 co- currently with the hydrocarbon feed via hydrocarbon feed conduit 104 or separately via gas conduit 106. In contacting zone 102, contact of the hydrocarbon feed with a catalyst produces a total product that includes a crude product, and, in some embodiments, gas. In some embodiments, a carrier gas is combined with the hydrocarbon feed and/or the hydrogen source in conduit 106. The total product may exit contacting zone 102 and be transported to other processing zones, storage vessels, or combinations thereof via conduit 108.

The crude product preferably has a viscosity of at most 100 cSt at 37.8 0 C; preferably has at least 0.01 grams of residue per gram of crude product; preferably has at least 0.02 grams of hydrocarbons having a boiling range distribution between 204 0 C and 343 0 C at 0.101 MPa per gram of crude product; and preferably has at least 0.03 grams of hydrocarbons of a vacuum gas oil ("VGO") portion having a boiling range distribution between 343 0 C and 538 0 C at 0.101 MPA per gram of crude product, wherein the VGO fraction preferably comprises at least 0.2 grams of total UV aromatics per gram of crude product.

The crude product or a portion thereof can be blended with a crude feed that is the same as or different from crude feed. For example, the crude product may be combined with a crude having a different viscosity thereby resulting in a blended product having a viscosity that is between the viscosity of the crude product and the viscosity of the crude. In another example, the crude product may be blended with crude having a TAN, viscosity and/or API gravity that is different, thereby producing a product that has a selected property that is between that selected property of the crude product and the crude. The blended product may be suitable for transportation and/or treatment. In some embodiments, the crude product and/or the blended product are transported to a refinery and distilled and/or fractionally distilled to produce one or more distillate fractions. The distillate fractions may be processed to produce commercial products such as transportation fuel, lubricants, or chemicals. Blending and separating of the disadvantaged crude and/or hydrocarbon feed, total product and/or crude product is described U.S. Published Patent Application No. 20050133414 to Bhan et al .

Preferably the crude product has a VGO fraction that has a total UV aromatic content that may be equal to or greater than the total UV aromatic content of the VGO fraction of the hydrocarbon feed. Maintaining or increasing the total UV aromatic content may assist in maintaining the P-value above 1.0 at lower pressures and controlled temperatures. Preferably the crude product may be a liquid mixture at 25°C and 0.101 MPa. In certain embodiments, API gravity of the crude product produced from contact of the hydrocarbon feed with catalyst, at the contacting conditions, is increased by at least 2, at least 3, at least 5, or at least 10 relative to the API

gravity of the hydrocarbon feed. In certain embodiments, API gravity of the crude product ranges from 10 to 40, 11 to 30, 13 to 25, or 14 to 20.

In certain embodiments, the crude product has a viscosity of at most 90%, at most 80%, or at most 70% of the viscosity of the hydrocarbon feed. In some embodiments, the viscosity of the crude product is at most 100, at most 500, or at most 100 cSt.

In some embodiments, the crude product has a total C 5 and C 7 asphaltenes content of at most 90%, at most 80%, at most 75%, or at most 50% of the total C 5 and C 7 asphaltenes content of the hydrocarbon feed. In other embodiments, the C 5 asphaltenes content of the hydrocarbon feed is at least 10%, at least 30%, or at least 40% of the C 5 asphaltenes content of the hydrocarbon feed . In certain embodiments, the hydrocarbon feed has, per gram of hydrocarbon feed, a total C 5 and C 7 asphaltenes content ranging from 0.001 grams to 0.2 grams, 0.01 to 0.15 grams, or 0.05 grams to 0.15 grams . In certain embodiments, the crude product has a MCR content of at most 95%, at most 90%, or at most 80% of the MCR content of the hydrocarbon feed. In some embodiments, decreasing the C 5 asphaltenes content of the hydrocarbon feed while maintaining a relatively stable MCR content may increase the stability of the hydrocarbon feed/total product mixture .

The crude product has, in some embodiments, from 0.0001 grams to 0.20 grams, 0.005 grams to 0.15 grams, or 0.01 grams to 0.010 grams of MCR per gram of crude product. In some embodiments the crude product is separated into two or more portions . The crude product may for example be separated (for example by using membrane separation, or distillation techniques such as atmospheric distillation or

fractional distillation) into two, three, four, five, six, seven, eight or more portions. In one embodiment the crude product is separated into three portions. In such case the crude product may for example be separated into a first portion, boiling below 343°C (650 0 F) at 0.101 MPa, a second portion boiling in the range from 343°C to 538°C (650 to 100 0 F) at 0.101 MPa and a third portion boiling above 538°C (1000 0 F) at 0.101 MPa. The first portion is herein below also referred to as Light Hydrocarbon Fraction, the second portion is herein below also referred to as Vacuum Gas Oil or VGO fraction, and the third portion is herein below also referred to as Residue.

FIG. 2 is a schematic of a process according to the invention . The process comprises contacting a hydrocarbon feed, such as for example a crude feed (202) with a hydrogen source (204) and one or more catalysts (206) in a reactor (208) to produce a crude product (210) . The crude feed may comprise at least 0.01 wt % of a vacuum gas oil fraction having a boiling range distribution between 343 0 C and 538 0 C at

0.101 MPA. The catalyst or catalysts may comprise at least one catalyst containing one or more metals from Column 6 of the Periodic Table and/or one or more compounds of one or more metals from Columns 6 of the Periodic Table. The hydrocarbon feed (202) and hydrogen source (204) may be contacted at a partial pressure of hydrogen of least 3 MPa and a temperature of least 200 0 C.

The produced crude product (210) may be fractionated into three distillate fractions in a distillation tower or flasher (212) . A first fractionated portion (214) may comprise residue. A second fractionated portion (216) may comprise vacuum gas oil, and a third fractionated portion (218) may contain lighter distillates. The fractionated

portions, and especially the second (vacuum gas oil) fraction (216) may be used as a diluent to dilute for example a crude or another hydrocarbon composition, such as a short or long residue. In a further embodiment of a continuous process (shown by broken line) the vacuum gas oil may be recycled and combined with the crude feed (202) to the process. Such may be especially advantageous to maintain the stability of the crude feed/crude product mixture in the reactor (208) . The stability and P-value of the crude feed/ product mixture in reactor (208) may be improved by such recycle

Further the viscosity of the crude feed may be reduced by mixing it with the vacuum gas oil, thereby obtaining a crude feed/ vacuum gas oil mixture with a reduced viscosity, which may be easier to pipeline.

The third fractionated portion (218) may be separated into a liquid and a gas in a gas-liquid separator (220), whereafter a liquid fraction (222) and a gas fraction (224) may be obtained. The liquid fraction (222) is again especially useful as a diluent.

One or more fractions obtained in a fractionation of the crude product may be used to produce a transportation fuel. In some embodiments, the Vacuum Gas Oil that may be obtained in the fractionation is used wholly or in part to produce a transportation fuel. Such a transportation fuel may have an advantageously high total UV aromatics content.

Further, as also indicated above, one or more fractions obtained in a fractionation may be used to produce a diluent. In some embodiments, a Vacuum Gas Oil fraction that may be obtained in the fractionation is used wholly or in part to produce a diluent. Such a diluent may have an advantageously high total UV aromatics content. In a further embodiment the vacuum gas oil fraction obtained in the

fractionation is used to dilute a crude feed. The later is especially advantageous as the high total UV aromatics content of the gas oil fraction may help to maintain the stability of the crude feed/crude product mixture. In some embodiments, fractions boiling between 260 0 C and 594 0 C (500 0 F and 1100 0 F), 287 0 C and 538 0 C (550 0 F and 1000 0 F) 315 0 C and 482 0 C (600 0 F and 900 0 F) are obtained. Such fractions may be used in a diluent or as a diluent by itself. Such diluent may have a high total UV aromatics content.

In some embodiments, the crude product has a distillate content of at least 110%, at least 120%, or at least 130% of the Distillate content of the hydrocarbon feed. Such Distillate, boiling between 182°C and 343°C (360 0 F and 650 0 F) at 0.101 MPa, may be contained in a Light Hydrocarbon

Fraction. The Distillate content of the crude product may be, per gram of crude product, in a range from 0.00001 grams to 0.6 grams (0.001-60wt%) , 0.001 grams to 0.5 grams (0.1- 50wt%) , or 0.01 grams to 0.4 grams (l-40wt%) . In some embodiments, the Distillate of the crude product includes UV aromatics. The Distillate, boiling between 182°C and 343°C (360°F and 650 0 F) at 0.101 MPa or respectively Light Hydrocarbon Fraction (boiling below 343°C or 650 0 F at 0.101 MPa) of the crude product may further include a similar or a higher amount of total UV aromatics as the Distillate or respectively Light Hydrocarbon Fraction of the crude feed. The UV aromatics may include, but are not limited to, mono, di, tri and/or tetra aromatics or mixtures thereof. The total UV aromatics content in the Distillate or respectively Light Hydrocarbon Fraction may range from 0.001 grams to 0.9 grams (0.1-90 wt%) , from 0.01 grams to 0.5 grams (l-50wt%), from 0.05 grams to 0.4 grams (5-40wt%) , from 0.1 grams to 0.3 grams (10-30 wt%) , or from 0.1 grams

to 0.2 grams (10-20wt%) of total UV aromatics per gram of Distillate or respectively Light Hydrocarbon Fraction.

In some embodiments, the fractionated Light Hydrocarbon Fraction (boiling below 343°C or 650 0 F) includes at least 0.001 grams (0.1 wt %) of mono-aromatics per gram of Light Hydrocarbon Fraction. A total content of mono-aromatics in the Light Hydrocarbon Fraction may range from 0.001 grams to 0.9 grams (0.1-90 wt%) , from 0.005 grams to 0.5 grams (0.5- 50wt%) , from 0.01 grams to 0.3 grams (l-30wt%) , from 0.02 grams to 0.2 grams (2-20 wt%) , or from 0.05 grams to 0.15 grams (5-15wt%) of mono aromatics per gram of Light Hydrocarbon Fraction .

In some embodiments, the UV aromatic content in the Light Hydrocarbon Fraction of the crude product comprises mono aromatics, and the mono aromatic content of the Light

Hydrocarbon Fraction is at least 110% of the mono aromatic content of the Light Hydrocarbon Fraction of the of the crude feed.

In some embodiments, the fractionated Light Hydrocarbon Fraction includes at least 0.001 grams (0.1 wt %) of di- aromatics per gram of Light Hydrocarbon Fraction. A total content of di-aromatics in the Light Hydrocarbon Fraction may range from 0.001 grams to 0.9 grams (0.1-90 wt%) , from 0.005 grams to 0.5 grams (0.5-50wt%), from 0.01 grams to 0.2 grams (l-20wt%), from 0.02 grams to 0.1 grams (2-10 wt%) , or from 0.02 grams to 0.1 grams (2-10wt%) of di aromatics per gram of Light Hydrocarbon Fraction.

In some embodiments the total UV aromatic content in the Light Hydrocarbon Fraction of the crude product includes di- aromatics, and the di-aromatic content of the Light

Hydrocarbon Fraction is at most 90% of the di-aromatic content of the Light Hydrocarbon Fraction of the crude feed.

In some embodiments the fractionated Light Hydrocarbon Fraction comprises at least 0.001 grams (0.1 wt %) of tri- aromatics per gram of Light Hydrocarbon Fraction. A total content of tri-aromatics in the Light Hydrocarbon Fraction may range from 0.001 grams to 0.9 grams (0.1-90 wt%) , from 0.002 grams to 0.5 grams (0.2-50wt%), from 0.005 grams to 0.1 grams (0.5-10wt%), from 0.01 grams to 0.03 grams (1-3 wt%) of tri aromatics per gram of Light Hydrocarbon Fraction . In some embodiments the total UV aromatic content in the Light Hydrocarbon Fraction of the crude product includes tri-aromatics, and the tri-aromatic content of the Light Hydrocarbon Fraction is at most 90% of the tri-aromatic content of the Light Hydrocarbon Fraction of the crude feed. In some embodiments the fractionated Light Hydrocarbon

Fraction includes at least 0.001 grams (0.1 wt %) of tetra- aromatics per gram of Light Hydrocarbon Fraction. A total content of tri-aromatics in the Light Hydrocarbon Fraction may range from 0.001 grams to 0.9 grams (0.1-90 wt%) , from 0.002 grams to 0.5 grams (0.2-50wt%), from 0.005 grams to 0.1 grams (0.5-10wt%) , from 0.01 grams to 0.03 grams (1-3 wt%) of tri aromatics per gram of Light Hydrocarbon Fraction .

In certain embodiments, the crude product has a VGO content, boiling between 343°C to 538°C at 0.101 MPa, of 70% to 130%, 80% to 120%, or 90% to 110% of the VGO content of the hydrocarbon feed. In some embodiments, the crude product has, per gram of crude product, a VGO content in a range from 0.00001 grams to 0.8 grams, 0.001 grams to 0.7 grams, 0.01 grams to 0.6 grams, or 0.1 grams to 0.5 grams.

In some embodiments, the VGO fraction of the crude product includes UV aromatics. The VGO fraction of the crude product may further include the same or a higher

amount of UV aromatics as the Vacuum gas oil fraction of the crude feed. The UV aromatics may include, but are not limited to, mono, di, tri and/or tetra aromatics or mixtures thereof. A total content of UV aromatics in the VGO fraction may range from 0.001 grams to 0.9 grams (0.1-90 wt%), from 0.01 grams to 0.6 grams (l-60wt%) , from 0.05 grams to 0.5 grams (5-50wt%) , from 0.1 grams to 0.4 grams (10-40 wt%), or from 0.2 grams to 0.3 grams (20-30wt%) of UV aromatics per gram of VGO fraction. In some embodiments, the total UV aromatic content in the VGO fraction is at least 101 %, at least 105%, at least 110%, at most 150%, at most 140% or at most 125% of the total UV aromatic content of the VGO fraction of the hydrocarbon feed. In some embodiments the fractionated VGO fraction includes at least 0.001 grams (0.1 wt %) of mono-aromatics per gram of VGO fraction. A total content of mono-aromatics in the VGO fraction may range from 0.001 grams to 0.9 grams (0.1-90 wt%), from 0.005 grams to 0.5 grams (0.5-50wt%), from 0.01 grams to 0.3 grams (l-30wt%) , from 0.02 grams to 0.2 grams (2-20 wt%) , or from 0.05 grams to 0.1 grams (5- 10wt%) of mono aromatics per gram of VGO fraction.

In some embodiments, the total UV aromatic content in the VGO fraction of the crude product comprises mono aromatics, and the mono aromatic content of the VGO fraction is at most 90% of the mono aromatic content of the vacuum gas oil fraction of the of the crude feed.

In some embodiments the fractionated VGO fraction includes at least 0.001 grams (0.1 wt %) of di-aromatics per gram of VGO fraction. A total content of di-aromatics in the VGO fraction may range from 0.001 grams to 0.9 grams (0.1-90 wt%), from 0.005 grams to 0.5 grams (0.5-50wt%), from 0.01 grams to 0.3 grams (l-30wt%) , from 0.02 grams to 0.2 grams

(2-20 wt%) , or from 0.05 grams to 0.1 grams (5-10wt%) of di aromatics per gram of VGO fraction.

In some embodiments the fractionated VGO fraction includes at least 0.001 grams (0.1 wt %) of tri-aromatics per gram of VGO fraction. A total content of tri-aromatics in the VGO fraction may range from 0.001 grams to 0.9 grams (0.1-90 wt%), from 0.005 grams to 0.5 grams (0.5-50wt%), from 0.01 grams to 0.3 grams (l-30wt%) , from 0.02 grams to 0.2 grams (2-20 wt%) , or from 0.05 grams to 0.1 grams (5- 10wt%) of tri aromatics per gram of VGO fraction.

In some embodiments the total UV aromatic content in the VGO fraction of the crude product includes tri-aromatics, and the tri-aromatic content of the VGO fraction is at least 110% of the tri-aromatic content of the vacuum gas oil fraction of the of the crude feed.

In some embodiments the fractionated VGO fraction includes at least 0.001 grams (0.1 wt %) of tetra-aromatics per gram of VGO fraction. A total content of tetra-aromatics in the VGO fraction may range from 0.001 grams to 0.9 grams (0.1-90 wt%), from 0.005 grams to 0.5 grams (0.5-50wt%), from 0.01 grams to 0.3 grams (l-30wt%) , from 0.02 grams to 0.2 grams (2-20 wt%) , or from 0.03 grams to 0.1 grams (3- 10wt%) of tetra aromatics per gram of VGO fraction.

In some embodiments the total UV aromatic content in the VGO fraction of the crude product comprises tetra-aromatics, and the tetra-aromatic content of the VGO fraction is at least 110% of the tetra-aromatic content of the vacuum gas oil fraction of the of the crude feed.

In some embodiments, the crude product has a residue content of at most 90%, at most 80%, or at most 50% of the residue content of the hydrocarbon feed. The crude product may have, per gram of crude product, a residue content in a range from in a range from 0.00001 grams to 0.8 grams, 0.001

grams to 0.7 grams, 0.01 grams to 0.6 grams, 0.05 grams to 0.5 grams, or 0.1 to 0.3 grams.

In some embodiments, the residue portion of the crude product includes UV aromatics . The UV aromatics may include, but are not limited to, mono, di, tri and/or tetra aromatics. A total content of UV aromatics in the residue portion may range from 0.001 grams to 0.9 grams, from 0.01 grams to 0.6 grams or from 0.1 grams to 0.5 grams of UV aromatics per gram of Residue. In some embodiments, the fractionated Residue comprises at least 0.001 grams (0.1 wt%) of mono-aromatics per gram of Residue. A total content of mono-aromatics in the Residue may range from 0.001 grams to 0.9 grams (0.1-90 wt%) , from 0.005 grams to 0.5 grams (0.5-50 wt%) , from 0.01 grams to 0.3 grams (1-30 wt%) , from 0.02 grams to 0.2 grams (2-20 wt%) , or from 0.03 grams to 0.1 grams (3-10 wt%) of mono aromatics per gram of Residue.

In some embodiments, the fractionated Residue comprises at least 0.001 grams (0.1 wt %) of di-aromatics per gram of Residue. A total content of di-aromatics in the Residue may range from 0.001 grams to 0.9 grams (0.1-90 wt%) , from 0.005 grams to 0.5 grams (0.5-50wt%) , from 0.01 grams to 0.3 grams (l-30wt%), from 0.02 grams to 0.2 grams (2-20 wt%) , or from 0.03 grams to 0.1 grams (3-10wt%) of di aromatics per gram of Residue.

In some embodiments, the fractionated Residue comprises at least 0.001 grams (0.1 wt%) of tri-aromatics per gram of Residue. A total content of tri-aromatics in the Residue may range from 0.001 grams to 0.9 grams (0.1-90 wt%) , from 0.005 grams to 0.5 grams (0.5-50 wt%), from 0.01 grams to 0.3 grams (1-30 wt%) , from 0.02 grams to 0.2 grams (2-20 wt%) , or from 0.05 grams to 0.1 grams (5-10 wt%) of tri aromatics per gram of Residue.

In some embodiments, the fractionated Residue comprises at least 0.001 grams (0.1 wt%) of tetra-aromatics per gram of Residue. A total content of tetra-aromatics in the Residue may range from 0.001 grams to 0.9 grams (0.1-90 wt%), from 0.005 grams to 0.5 grams (0.5-50 wt%) , from 0.01 grams to 0.4 grams (1-40 wt%) , from 0.05 grams to 0.3 grams (5-30 wt%) , or from 0.1 grams to 0.2 grams (10-20 wt%) of tetra aromatics per gram of Residue.

Catalysts used in one or more embodiments of the inventions may include one or more bulk metals and/or one or more metals on a support. The metals may be in elemental form or in the form of a compound of the metal . The catalysts described herein may be introduced into the contacting zone as a precursor, and then become active as a catalyst in the contacting zone (for example, when sulfur and/or a hydrocarbon feed containing sulfur is contacted with the precursor) . The catalyst may for example be a catalyst as described in non-prepublished international patent application publication No. WO2008/045757, which is incorporated herein by reference.

At least one of the catalysts used in the current invention comprises one or more metals from Column 6 of the Periodic Table and/or one or more compounds of one or more metals from Columns 6 of the Periodic Table. Columns 6 metal (s) include chromium, molybdenum and tungsten. The catalyst may have, per gram of catalyst, a total Column 6 metal(s) content of at least 0.00001, at least 0.01 grams, at least 0.02 grams and/or in a range from 0.0001 grams to 0.6 grams, 0.001 grams to 0.3 grams, 0.005 grams to 0.2 grams, 0.01 grams to 0.1 grams, or 0.01 grams to 0.08 grams. In some embodiments, the catalyst includes from 0.0001 grams to 0.06 grams of Column 6 metal (s) per gram of catalyst. In some embodiments, compounds of Column 6 metal (s) include

oxides. For example, the Column 6 metal oxides are molybdenum trioxide and/or tungsten trioxide. In some embodiments the catalyst may in addition include column 15 elements, such as phosphorus, and/or column 7-10 metal (s), such as manganese, technetium, rhenium, iron, cobalt, nickel, ruthenium, palladium, rhodium, osmium, iridium, platinum, or mixtures thereof. Preferably the catalyst includes essentially only Column 6 metals. Most preferably the catalyst includes essentially only molybdenum and/or molybdenum oxides .

In some embodiments, the Column 6 metal and optionally any further metals are incorporated with a support to form the catalyst. In embodiments in which the metal (s) and/or element (s) are supported, the weight of the catalyst includes all support, all metal (s) , and all element (s) . The support may be porous and may include refractory oxides, porous carbon based materials, zeolites, or combinations thereof. Refractory oxides may include, but are not limited to, alumina, silica, silica-alumina, titanium oxide, zirconium oxide, magnesium oxide, or mixtures thereof.

Supports may be obtained from a commercial manufacturer such as Criterion Catalysts and Technologies LP (Houston, Texas, U.S.A.) . Porous carbon based materials include, but are not limited to, activated carbon and/or porous graphite. Examples of zeolites include Y-zeolites, beta zeolites, mordenite zeolites, ZSM-5 zeolites, and ferrierite zeolites. Zeolites may be obtained from a commercial manufacturer such as Zeolyst (Valley Forge, Pennsylvania, U.S.A.) .

In certain embodiments, the support includes gamma alumina, delta alumina, alpha alumina, or combinations thereof. The amount of gamma alumina, delta alumina, alpha alumina, or combinations thereof, per gram of catalyst support, may be in a range from 0.0001 grams to 0.99 grams,

0.001 grams to 0.5 grams, 0.01 grams to 0.1 grams, or at most 0.1 grams as determined by x-ray diffraction.

The metal (s) and support may be mixed (for example, co- mulled) with suitable mixing equipment to form a metal (s) /support mixture. The metal (s ) /support mixture may be mixed using suitable mixing equipment. Examples of suitable mixing equipment include tumblers, stationary shells or troughs, Muller mixers (for example, batch type or continuous type), impact mixers, and any other generally known mixer, or generally known device, that will suitably provide the metal (s) /support mixture. In certain embodiments, the materials are mixed until the metal (s) is (are) substantially homogeneously dispersed in the support. Dispersion of the metal (s) may inhibit coking of the metal (s) at high temperatures and/or pressures, thus allowing hydrocarbon feeds containing significant amounts of residue and/or high viscosities to be processed at rates, temperatures, and pressures not obtainable by using conventional catalysts made using impregnation techniques. In some embodiments, an acid and/or water is added to the mixture to assist in formation of the mixture into particles. The water and/or dilute acid are added in such amounts and by such methods as required to give the mixture a desired consistency suitable to be formed into particles. Examples of acids include, but are not limited to, nitric acid, acetic acid, sulfuric acid, and hydrochloric acid.

The paste may be formed into particles using known techniques in the art such as an extruder. The particles (extrudates) may be cut using known catalyst cutting methods to form particles . The particles may be heat treated at a temperature in a range from 65 0 C to 260 0 C or from 85 0 C to 235 0 C for a period of time (for example, for 0.5 hours to 8

hours) and/or until the moisture content of the particle has reached a desired level.

The catalyst may be heat treated (calcined) in the presence of hot air and/or oxygen rich air at a temperature in a range between 400 0 C and 1000 0 C, between 450 0 C and 760 0 C, or between 500 0 C and 680 0 C for a period of time (for example 0.5 to 8 hours or 1 to 5 hours) to remove volatile matter such that at least a portion of the metals are converted to the corresponding metal oxide. The temperature conditions at which the particles are calcined may be such that the pore structure of the final calcined mixture is controlled to form the pore structure and surface areas of the catalysts described herein. Calcining at temperatures below 650 0 C may change the distribution of pores and the surface area such that the catalyst is even more effective in removing compounds that contribute to high viscosity and/or residue.

In some embodiments, the support (either a commercial support or a support prepared as described herein) may be combined with a supported catalyst and/or a bulk metal catalyst. In some embodiments, the supported catalyst may include Column 15 metal (s) . For example, the supported catalyst and/or the bulk metal catalyst may be crushed into a powder with an average particle size from 1 microns to 50 microns, 2 microns to 45 microns, or 5 microns to 40 microns. The powder may be combined with support as described herein to form an embedded metal catalyst. In some embodiments, the powder maybe combined with the support and then extruded using standard techniques. Combining the catalyst with the support (for example, co- mulling) allows, in some embodiments, at least a portion of the metal to reside under the surface of the embedded metal catalyst (for example, embedded in the support), leading to

less metal on the surface than would otherwise occur in the unembedded metal catalyst. In some embodiments, having less metal on the surface of the catalyst extends the life and/or catalytic activity of the catalyst by allowing at least a portion of the metal to move to the surface of the catalyst during use. The metals may move to the surface of the catalyst through erosion of the surface of the catalyst during contact of the catalyst with a hydrocarbon feed.

Preferably, the catalyst is prepared by combining one or more metal (s), mineral oxides having a particle size of at most 500 micrometers, and a support. The mineral oxides may include alumina, silica, silica-alumina, titanium oxide, zirconium oxide, magnesium oxide, or mixtures thereof. The mineral oxides may be obtained from an extrudate process to produce support. For example, alumina fines can be obtained from an alumina extrudate production to produce catalyst supports. In some embodiments, mineral oxide fines may have a particle size of at most 500 micrometers, at most 150 micrometers, at most 100 micrometers, or at most 75 micrometers. The particle size of the mineral oxides may range from 0.2 micrometers to 500 micrometers, 0.3 micrometers to 100 micrometers, or 0.5 micrometers to 75 micrometers. Combining mineral oxides with one or more metal (s) and a support may allow less metal to reside on the surface of the catalyst.

In some embodiments, the catalyst may be prepared by combining a supported catalyst with a support and one or more metal (s) to produce the catalyst. In some embodiments, the metal (s) (for example, molybdenum oxides and/or tungsten oxides) have a particle size of at most 500 micrometers, at most 150 micrometers, at most 100 micrometers, or at most 75 micrometers. The particle size of the metal (s) may range from 0.1 micrometers to 500 micrometers, 1 micrometers to

100 micrometers, or 10 micrometers to 75 micrometers. In some embodiments, at least 50 percent of the particles have a particle size between 2 micrometers to 15 micrometers. The mixture of the supported catalyst with a support and one or more metal (s) is dried at temperatures of at least 100 0 C to remove any low boiling components and then heated to at least 500 0 C, at least 1000 0 C, at least 1200 0 C, or at least 1300 0 C to convert at least a portion of the Columns 6-10 metal (s) to metal oxides. Hence, in some embodiments the catalyst of the application may be prepared by combining a support with one or more Columns 6 metal (s) and optionally one or more 7-10 metal (s), mineral oxides having a particle size of at most 500 micrometer, and/or a supported catalyst. Without wishing to be bound by any kind of theory, intercalation and/or mixing (for example, co-mulling) of the components of the catalysts changes, in some embodiments, the structured order of the Column 6 metal in the Column 6 oxide crystal structure to a substantially random order of Column 6 metal in the crystal structure of the embedded catalyst. The order of the Column 6 metal may be determined using powder x-ray diffraction methods. The order of elemental metal in the catalyst relative to the order of elemental metal in the metal oxide may be determined by comparing the order of the Column 6 metal peak in an x-ray diffraction spectrum of the Column 6 oxide to the order of the Column 6 metal peak in an x-ray diffraction spectrum of the catalyst. From broadening and/or absence of patterns associated with Column 6 metal in an x-ray diffraction spectrum, it is possible to estimate that the Column 6 metal (s) are substantially randomly ordered in the crystal structure .

For example, molybdenum trioxide and the alumina support having a median pore diameter of at least 180 A may be combined to form an alumina/molybdenum trioxide mixture. The molybdenum trioxide has a definite pattern (for example, definite D O oi, D002 and/or D O o3 peaks) . The alumina/molybdenum trioxide mixture may be heat treated at a temperature of at least 538 0 C (1000 0 F) to produce a catalyst that does not exhibit a pattern for molybdenum dioxide in an x-ray diffraction spectrum (for example, an absence of the D O oi peak) .

The catalyst prepared with supported catalyst fines and/or mineral oxide fines when analyzed using scanning electron microscopy, may exhibit a significantly lower degree of molybdenum disulfide (M0S 2 ) slab stacking with the stacks having reduced heights and length as compared to alternative molybdenum-containing hydroprocessing catalysts.

In some embodiments, catalysts may be characterized by pore structure. Various pore structure parameters include, but are not limited to, pore diameter, pore volume, surface areas, or combinations thereof. The catalyst may have a distribution of total quantity of pore sizes versus pore diameters. The catalyst may have a pore size distribution with a median pore diameter of at least 60 A, at least 90 A, or at most 200 A. In some embodiments, the catalyst has a pore size distribution with a median pore diameter in a range from 70 A to 200 A, 90 A to 150 A, or 100 A to 120 A, in further embodiment at least 60% of a total number of pores in the pore size distribution has a pore diameter within 45 A, 35 A, or 25 A of the median pore diameter. In some embodiments, pore volume of pores may be at least 0.3 cm 3 /g, at least 0.7 cm 3 /g, or at least 0.9 cm 3 /g. In certain embodiments, pore volume of pores may range from 0.3

cm 3 /q to 0.99 cm 3 /g, 0.4 cm 3 /g to 0.8 cm 3 /g, or 0.5 cm 3 /g to 0.7 cmVg.

The pore volume of the catalyst may include pores having a pore diameter between 1 A and 5000 A and pores having a pore diameter greater than 5000 A. In some embodiments, the catalyst has a majority of its pore volume in pores having a pore diameter of at most 300 A, at most 200 A, or at most 100 A. The catalyst may have at most 95% of its pore volume in pores having a pore diameter of at most 300 A, at most 200 A, or at most 100 A, with the balance of the pore volume being in pores having a pore diameter of at least 300 A.

In some embodiments, the catalyst has at most 80% of its pore volume in pores having a pore diameter of at most 200 A, with the balance of the pore volume being in pores having a pore diameter of at least 300 A.

In other embodiments, the catalyst has two distinct pore distributions (for example, a bimodal pore distribution with a pore size distribution comprising two peaks) . The catalyst may have a portion of its pore volume in pores having a pore diameter of at most 500 A, at most 300 A, or at most 200 A and a portion of its pore volume in pores having a pore diameter of at least 1000 A, at least 3000 A, or least 5000 A. In some embodiments, the catalyst has at most 40%, or at most 30% of its pore volume in pores having a pore diameter of at least 5000 A, from 10% to 60% of its pore volume in pores having a pore diameter from about 70 A to about 130 A, and the balance of the pore volume being in pores having a pore diameter between 130 A and 5000 A. In some embodiments, the catalyst having a pore size distribution with a median pore diameter in a range from about 50 A to 150 A, may have a surface areas of at least 200 m 2 /g. Such surface area may be in a range from 200 m 2 /g to 500 m 2 /g, 210 m 2 /g to 450 m 2 /g, or 225 m 2 /g to 425 m 2 /g.

Catalysts having specific surface topology, large surface areas and pore distributions described above may exhibit enhanced run times in commercial applications at low pressures and elevated temperatures. For example, the catalyst does not deactive after at least 1 year of run time. The enhanced run times may be attributed to the high surface area of the catalyst and/or the narrow distribution of pore diameter in the pore volume of the catalyst. Thus, the metals of the catalyst remain exposed for longer periods of time, thus plugging of the pores of the catalyst is minimal. The high surface area and selected distribution of pores in the pore volume of the catalyst allows processing of high viscosity and/or high residue crudes that would not be able to be processed with conventional catalysts having the same pore distribution, but smaller surface area.

In certain embodiments, the catalyst exists in shaped forms, for example, pellets, cylinders, and/or extrudates . In some embodiments, the catalyst and/or the catalyst precursor is sulfided to form metal sulfides (prior to use) using techniques known in the art (for example, ACTICAT™ process, CRI International, Inc.) . In some embodiments, the catalyst may be dried then sulfided. Alternatively, the catalyst may be sulfided in situ by contact of the catalyst with a hydrocarbon feed that includes sulfur-containing compounds. In-situ sulfurization may utilize either gaseous hydrogen sulfide in the presence of hydrogen, or liquid- phase sulfurizing agents such as organosulfur compounds (including alkylsulfides, polysulfides , thiols, and sulfoxides) . Ex-situ sulfurization processes are described in U.S. Patent Nos . 5,468,372 to Seamans et al . , and

5,688,736 to Seamans et al . , all of which are incorporated herein by reference. Liquid sulfiding processes are described in U.S. Patent No. 6,290,841 to Gabrielov et al .

which liquid sulfiding processes are incorporated herein by reference .

The crude product produced by contacting a hydrocarbon feed with one or more catalysts described herein may be useful in a wide range of applications including, but not limited to, use a feed to refineries, feed for producing transportation fuel, a diluent, or an enhancing agent for underground oil recovery processes.

When the crude product or a portion of the crude product is used as a diluent for diluting a crude feed, a diluted crude feed can be obtained that preferably comprises in the range from 10 to 90 wt% of a crude feed and in the range from 10 to 90wt% of a diluent as described herein, more preferably in the range from 30 to 80 wt% of a crude feed and in the range from 20 to 70 wt% of a diluent as described herein. The diluted crude may further preferably have a viscosity in the range from 10 to 5000 cSt, more preferably from 30 to 300OcSt at 37.8C; and/or preferably have an API in the range from 10 to 30, more preferably from 14 to 24; and/or preferably have a P-value of at least 1, more preferably at least 1.2; and/or preferably commprise at least a total UV aromatics content of at least 15 wt% .

For example, hydrocarbon feeds having an API gravity of at most 10 (for example, bitumen and/or heavy oil/tar sands crude) may be converted into various hydrocarbon streams through a series of processing steps using cracking units (for example, an ebullating bed cracking unit, a fluid catalytic cracking unit, thermal cracking unit, or other units known to convert hydrocarbon feed to lighter components) .

Reduction of the MCR content of a hydrocarbon feed to produce a feed stream that may be processed in cracking units may enhance the processing rate of hydrocarbon feed.

A system using the methods and catalysts described herein to change properties of a hydrocarbon feed may be positioned upstream of one or more cracking units . Treatment of the hydrocarbon feed in one or more systems described herein may produce a feed that improves the processing rate of the cracking unit by at least a factor of 2, at least a factor of 4, at least a factor of 10, or at least a factor of 100. For example, a system for treating a hydrocarbon feed having a MCR content of at least 0.01 grams per gram of hydrocarbon feed at least 0.0001 grams of hydrocarbons of a VGO fraction per gram of hydrocarbon feed, wherein the VGO fraction comprises at least 0.05 grams of UV aromatics per gram of VGO fraction may include one or more contacting systems described herein positioned upstream of a cracking unit. The contacting system may include one or more catalysts described herein capable of producing a crude product having MCR content of at most 90% of the hydrocarbon feed MCR content and wherein a total UV aromatic content in a VGO fraction of the crude product is greater than or equal to the total UV aromatics content of the hydrocarbon feed VGO fraction. The crude product and/or a mixture of the crude product and hydrocarbon feed may enter a cracking unit. Since the crude product and/or mixture of the crude product and hydrocarbon feed have less components that contribute to coking (MCR content) , than the original hydrocarbon feed, the processing rate through the cracking unit may be improved. Examples Non-limiting examples of a catalyst preparation and methods of using such catalyst under controlled contacting conditions are set forth below.

Example 1. Preparation of Column 6 Metal (s) Catalyst Containing Mineral Oxide Fines .

The catalyst was prepared in the following manner. M0O3 (94.44 grams) was combined with alumina (2742.95 grams) and crushed and sieved alumina fines having a particle size between 5 and 10 micrometers (1050.91 grams) in a muller. With the muller running, nitric acid (43.04 grams, 69.7 M) and deionized water (4207.62 grams) were added to the mixture and the resulting mixture was mulled for 5 minutes . Superfloc® 16 (30 grams, Cytec Industries, West Paterson,

New Jersey, USA) was added to the mixture in the muller, and the mixture was mulled for a total of 25 minutes. The resulting mixture had a pH of 6.0 and a loss on ignition of 0.6232 grams per gram of mixture. The mulled mixture was extruded using 1.3 mm trilobe dies to form 1.3 trilobe extrudate particles. The extrudate particles were dried at 125 0 C for several hours and then calcined at 676 0 C (1250 0 F) for two hours to produce the catalyst. The catalyst contained, per gram of catalyst, 0.02 grams of molybdenum, with the balance being mineral oxide and support. The catalyst had a pore size distribution with a median pore diameter of 117 A with 60% of the total number of pores in the pore size distribution having a pore diameter within 33 A of the median pore diameter, a surface area of 249 m 2 /g, and a total pore volume of 0.924 cc/g.

The pore size distribution measured using mercury porosimetry at a contact angle of 140 is shown in TABLE 1.

TABLE 1

This example demonstrates a catalyst that includes a support, mineral oxides, and one or more metals from Column 6 of the Periodic Table and/or one or more compounds of one or more metals from Column 6 of the Periodic Table. The catalyst has a pore size distribution with a median pore diameter of at least 80 A and the catalyst is obtainable by combining: mineral oxide fines; one or more metals from

Column 6 of the Periodic Table and/or one or more compounds of one or more metals from Column 6 of the Periodic Table; and a support.

Example 2. Contact Of A Hydrocarbon Feed With Example 1 Catalyst.

A tubular reactor with a centrally positioned thermowell was equipped with thermocouples to measure temperatures throughout a catalyst bed. The catalyst bed was formed by filling the space between the thermowell and an inner wall of the reactor with catalysts and silicon carbide (20-grid, Stanford Materials; Aliso Viejo, CA) . Such silicon carbide is believed to have low, if any, catalytic properties under

the process conditions described herein. All catalysts were blended with an equal volume amount of silicon carbide before placing the mixture into the contacting zone portions of the reactor. The crude feed flow to the reactor was from the top of the reactor to the bottom of the reactor. Silicon carbide was positioned at the bottom of the reactor to serve as a bottom support .

A volume of Column 6 metal catalyst (24 cm 3 ) prepared as described in Example 1 was mixed with silicone carbide (24 cm 3 ) and the mixture positioned in the bottom contacting zone .

A Column 6 metal catalyst (6 cm 3 ) prepared as described in Example 1 was mixed with silicone carbide (6 cm 3 ) and the mixture positioned on top of the contacting zone to form a top contacting zone.

Silicon carbide was positioned on top of the top contacting zone to fill dead space and to serve as a preheat zone. The catalyst bed was loaded into a Lindberg furnace that included four heating zones corresponding to the preheat zone, the top and bottom contacting zones, and the bottom support .

The catalysts were sulfided using the liquid sulfiding method as described in U.S. Patent No. 6,290,841 to Gabrielov et al. which is incorporated herein by reference. After sulfidation of the catalysts, the temperature of the contacting zones was raised to a temperature of 418 0 C. A hydrocarbon feed (Peace River) having the properties listed in Table 2. The hydrocarbon feed flowed through the preheat zone, top contacting zone, bottom contacting zone, and bottom support of the reactor. The hydrocarbon feed was contacted with each of the catalysts in the presence of hydrogen gas . Contacting conditions were as follows : ratio

of hydrogen gas to feed was 318 Nm 3 /m 3 (2000 SCFB) and LHSV was about 0.5 h "1 . The two contacting zones were heated to 400 0 C and maintained between 400 0 C and 420 0 C at a pressure of 3.5 MPa (500 psig) for 4200 hours as the hydrocarbon feed flowed through the reactor.

After its production the crude product was distilled into three fractions, a first fraction boiling below 650 0 F, a second fraction boiling between 650-1000 0 F and a third fraction boiling above 1000 0 F. The results of analyzing the fractions are listed in Table 2.

As shown in Table 2, the crude product had a viscosity of 70 at 37.8 0 C, a residue content of 0.244 grams, per gram of crude product, a Ni/V/Fe content of 258.2 wtppm, a molybdenum content of 0.4 wtppm, and a MCR content of 0.099 grams per gram of crude product. The increase in the total amount of UV aromatics in the VGO fraction indicate that hydrogenation of the heavier asphaltenes is not occurring. The increase in aromatic compounds in the VGO may allow solubilization of the polar compounds in the mixture. The solubilization of polar compounds may enhance the life of the catalyst by preventing plugging of the catalyst pores. This example demonstrates that contact of a hydrocarbon feed with one or more catalysts, where at least one of the catalyst includes one or more metals from Column 6 of the Periodic Table and/or one or more compounds of one or more metals from Columns 6 of the Periodic Table produces a crude product having a MCR content of at most 90% of MCR content of the hydrocarbon feed; and having total content of UV aromatics in a VGO fraction of the crude product which is greater than or equal to the total UV aromatics content of the hydrocarbon feed VGO fraction of the hydrocarbon feed.

This example also demonstrates the production of a crude product that has a viscosity of at most 100 cSt at 37.8 0 C,

a Ni/Fe/V content of between 100 wtppm and 300 wtppm; at least 0.01 grams of residue per gram of crude product; at least 0.2 grams of hydrocarbons having a boiling range distribution between 204 0 C and 343 0 C at 0.101 MPa per gram of crude product; at least 0.3 grams of hydrocarbons of a vacuum gas oil ("VGO") portion having a boiling range distribution between 343 0 C and 538 0 C at 0.101 MPA per gram of crude product, where the VGO fraction comprises at least 0.2 grams of UV aromatics per gram of crude product. Example 3. Blend.

A blend of the VGO fraction of the crude product with hydrocarbon feed was made in the following manner.

The crude product obtained in example 2 was distilled using the method described in ASTM Method D-1160 to obtain the VGO fraction. A sample of a hydrocarbon feed (processed Peace River crude feed) having a P-value of less than 1.0 was obtained. 10 ml of the hydrocarbon feed sample was mixed with 3 ml of the VGO fraction.

The mixture was shaken and allowed to stand. The P-value of the mixture of the hydrocarbon feed sample and the VGO fraction was 1.2.

This example demonstrates that a separated portion of the crude product, such as the VGO fraction, may advantageously be used to increase the P-value of a hydrocarbon composition by diluting such hydrocarbon composition with it. Hence, a relatively unstable hydrocarbon composition may be stabilized by mixing it with a separated portion of the crude product, such as a VGO fraction, having a high total content of UV aromatics.

TABLE 2

^Not Determined