WO2007149921A1 - Procédés de production d'un produit brut à partir d'une charge d'alimentation sélectionnée - Google Patents

Procédés de production d'un produit brut à partir d'une charge d'alimentation sélectionnée Download PDF

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Publication number
WO2007149921A1
WO2007149921A1 PCT/US2007/071671 US2007071671W WO2007149921A1 WO 2007149921 A1 WO2007149921 A1 WO 2007149921A1 US 2007071671 W US2007071671 W US 2007071671W WO 2007149921 A1 WO2007149921 A1 WO 2007149921A1
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WIPO (PCT)
Prior art keywords
grams
feed
catalyst
crude product
inorganic salt
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PCT/US2007/071671
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English (en)
Inventor
Thomas Fairchild Brownscombe
William Douglas Gillespie
Weijian Mo
Eswarachandra Kumar Paruchuri
Susan Secor Pfrehm
Chen Elizabeth Ramachandran
David William Wallace
Scott Lee Wellington
Original Assignee
Shell Oil Company
Shell Internationale Research Maatschappij B.V.
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
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Publication date
Application filed by Shell Oil Company, Shell Internationale Research Maatschappij B.V. filed Critical Shell Oil Company
Priority to EP07812215A priority Critical patent/EP2029698A1/fr
Priority to JP2009516704A priority patent/JP2009541537A/ja
Priority to CA002655581A priority patent/CA2655581A1/fr
Priority to MX2008016078A priority patent/MX2008016078A/es
Publication of WO2007149921A1 publication Critical patent/WO2007149921A1/fr

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    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G47/00—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions
    • C10G47/24—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions with moving solid particles
    • C10G47/30—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions with moving solid particles according to the "fluidised-bed" technique

Definitions

  • the present invention generally relates to systems and methods for treating feed, and to compositions that are produced, for example, using such systems and methods.
  • disadvantaged crudes 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". Disadvantaged crudes often contain relatively high levels of residue. Such crudes tend to be difficult and expensive to transport and/or process using conventional facilities.
  • High residue crudes may be treated at high temperatures to convert the crude to coke.
  • high residue crudes are typically treated with water at high temperatures to produce less viscous crudes and/or crude mixtures.
  • water removal from the less viscous crudes and/or crude mixtures may be difficult using conventional means.
  • Disadvantaged crudes may include hydrogen deficient hydrocarbons. When processing hydrogen deficient hydrocarbons, consistent quantities of hydrogen generally need to be added, particularly if unsaturated fragments resulting from cracking processes are produced. Hydrogenation during processing, which typically involves the use of an active hydrogenation catalyst, may also be needed to inhibit unsaturated fragments from forming coke. Processes such as reforming that are used to produce hydrogen are generally endothermic and, typically, require additional heat. Hydrogen and/or heat is costly to produce and/or costly to transport to treatment facilities.
  • Coke may form and/or deposit on catalyst surfaces at a rapid rate during processing of disadvantaged crudes. It may be costly to regenerate the catalytic activity of a catalyst contaminated by coke. High temperatures used during regeneration may also diminish the activity of the catalyst and/or cause the catalyst to deteriorate.
  • Disadvantaged crudes may include acidic components that contribute to the total acid number ("TAN") of the feed.
  • Disadvantaged crudes with a relatively high TAN may contribute to corrosion of metal components during transporting and/or processing of the disadvantaged crudes.
  • Removal of acidic components from disadvantaged crudes may involve chemically neutralizing acidic components with various bases.
  • corrosion-resistant metals may be used in transportation equipment and/or processing equipment. The use of corrosion-resistant metal often involves significant expense, and thus, the use of corrosion-resistant metal in existing equipment may not be desirable.
  • Another method to inhibit corrosion may involve addition of corrosion inhibitors to disadvantaged crudes before transporting and/or processing of the disadvantaged crudes. The use of corrosion inhibitors may negatively affect equipment used to process the crudes and/or the quality of products produced from the crudes.
  • Disadvantaged crudes may contain relatively high amounts of metal contaminants, for example, nickel, vanadium, and/or iron.
  • metal contaminants, and/or compounds of metal contaminants may deposit on a surface of the catalyst or the void volume of the catalyst. Such deposits may cause a decline in the activity of the catalyst.
  • Organically bound heteroatoms for example, sulfur, oxygen, and nitrogen.
  • Organically bound heteroatoms may, in some situations, have an adverse effect on catalysts.
  • Alkali metal salts and/or alkaline-earth metal salts have been used in processes for desulfurization of residue. These processes tend to result in poor desulfurization efficiency, production of oil insoluble sludge, poor demetallization efficiency, formation of substantially inseparable salt-oil mixtures, utilization of large quantities of hydrogen gas, and/or relatively high hydrogen pressures.
  • Some processes for improving the quality of crude include adding a diluent to disadvantaged crudes to lower the weight percent of components contributing to the disadvantaged properties. Adding diluent, however, generally increases costs of treating disadvantaged crudes due to the costs of diluent and/or increased costs to handle the disadvantaged crudes. Addition of diluent to a disadvantaged crude may, in some situations, decrease stability of such crude.
  • disadvantaged crudes generally have undesirable properties (for example, relatively high residue, a tendency to corrode equipment, and/or a tendency to consume relatively large amounts of hydrogen during treatment).
  • Other undesirable properties include relatively high amounts of undesirable components (for example, relatively high TAN, organically bound heteroatoms, and/or metal contaminants).
  • Such properties tend to cause problems in conventional transportation and/or treatment facilities, including increased corrosion, decreased catalyst life, process plugging, and/or increased usage of hydrogen during treatment.
  • inventions described herein generally relate to systems and methods for contacting a feed with one or more catalysts to produce a total product comprising a crude product and, in some embodiments, non-condensable gas. Inventions described herein also generally relate to compositions that have novel combinations of components therein. Such compositions can be obtained by using the systems and methods described herein.
  • the invention provides a system for producing a total product, comprising: a contacting zone, the contacting zone being configured to fluidize a supported inorganic salt catalyst in the presence of a feed, steam and a hydrogen source to produce the total product; a regeneration zone configured to receive at least a portion of the supported inorganic salt catalyst from the contacting zone and remove at least a portion of contaminants from the supported inorganic salt catalyst; and a recovery zone, the recovery zone being configured to receive combustion gas from the regeneration zone, wherein the recovery zone is configured to separate at least a portion of inorganic salts from the combustion gas.
  • the invention provides a method of producing total product, comprising: providing a feed to a contacting zone; providing an inorganic salt catalyst to the contacting zone; contacting the inorganic salt catalyst with the feed in the presence of a hydrogen source and steam in the contacting zone; producing a total product and a used inorganic salt catalyst; heating the used inorganic salt catalyst to remove at least a portion of contaminants from the inorganic salt catalyst, wherein a combustion gas is produced during the heating of the used inorganic salt catalyst; and recovering inorganic salts from the combustion gas.
  • the invention provides a method of producing total product, comprising: providing a feed to a contacting zone; providing an inorganic salt catalyst to the contacting zone; contacting the inorganic salt catalyst with the feed in the presence of a hydrogen source and steam such that the inorganic salt catalyst becomes fluidized in the contacting zone; and producing a total product.
  • the invention provides a method of producing a total product, comprising: providing a feed to a contacting zone; providing a supported inorganic salt catalyst to the contacting zone; contacting the supported inorganic salt catalyst with the feed in the presence of a hydrogen source and steam in the contacting zone; and producing the total product.
  • the invention provides a method of producing a crude product, comprising: providing a feed to a contacting zone, wherein the feed has at total content, per gram of feed, of at least 0.9 grams of hydrocarbons having a boiling range distribution between 343 0 C and 538 0 C; providing a supported inorganic salt catalyst to the contacting zone; contacting the supported inorganic salt catalyst with the feed in the presence of a hydrogen source and steam such that the supported inorganic salt catalyst becomes fluidized; and producing a total product that includes a crude product, and the crude product having a total content of at least 0.2 grams per gram of crude product of hydrocarbon have a boiling range distribution between 204 0 C and 343 0 C.
  • the invention provides a method of producing a total product, comprising: contacting a feed with a hydrogen source in the presence of one or more inorganic salt catalysts and steam to produce a total product; and controlling contacting conditions such that the conversion of feed to hydrocarbon gas and hydrocarbon liquid is between 5% and 50%, based on the molar amount of carbon in the feed.
  • the invention provides a method of producing a total product, comprising: contacting a feed with light hydrocarbons in the presence of one or more inorganic salt catalysts and steam to produce a total product; and controlling contacting conditions such that at least 50% of the light hydrocarbons are recovered; and producing a total product, wherein a ratio of atomic hydrogen to carbon (H/C) in the total product is between 80% and 120% of the atomic H/C of the feed.
  • H/C ratio of atomic hydrogen to carbon
  • the invention provides a method of producing a total product, comprising: providing a feed to a contacting zone; providing a supported inorganic salt catalyst to the contacting zone; contacting the supported inorganic salt catalyst with the feed in the presence of a hydrogen source and steam in the contacting zone at a temperature of at most 1000 0 C and a total operating pressure of at most 4 MPa; and producing the total product.
  • the invention provides a method of producing a total product, comprising: continuously contacting a feed with a hydrogen source in the presence of one or more inorganic salt catalysts and steam to produce a total product, wherein the feed has at least 0.02 grams of sulfur, per gram of feed; and producing a total product that includes that includes coke and the crude product, wherein the crude product has a sulfur content of at most 90% of the sulfur content of the feed and the content of coke is at most 0.2 grams, per gram of feed.
  • features from specific embodiments may be combined with features from other embodiments.
  • features from the any one of the series of embodiments may be combined with features from any of the other series of embodiments.
  • total products are obtainable by any of the methods and systems described herein.
  • additional features may be added to the specific embodiments described herein.
  • FIG. 1 is a schematic of an embodiment of a contacting system for contacting the feed with a hydrogen source in the presence of one or more catalysts to produce the total product.
  • FIG. 2 is a schematic of another embodiment of a contacting system for contacting the feed with a hydrogen source in the presence of one or more catalysts to produce the total product.
  • FIG. 3 is a schematic of an embodiment of a contacting system for fluidly contacting the feed with a hydrogen source in the presence of one or more catalyst to produce the total product.
  • FIG. 4 is a schematic of another embodiment of a contacting system for fluidly contacting the feed with a hydrogen source in the presence of one or more catalyst to produce the total product.
  • FIG. 5 is a schematic of an embodiment of a separation zone in combination with a contacting system.
  • FIG. 6 is a schematic of an embodiment of a blending zone in combination with a contacting system.
  • FIG. 7 is a schematic of an embodiment of a separation zone, a contacting system, and a blending zone.
  • FIG. 8 is a schematic of an embodiment of multiple contacting systems.
  • FIG. 9 is a schematic of an embodiment of an ionic conductivity measurement system.
  • FIG. 10 is a graphical representation of log 10 plots of ion currents of emitted gases of an inorganic salt catalyst versus temperature, as determined by TAP.
  • FIG. 11 is a graphic representation of log plots of the resistance of inorganic salt catalysts and an inorganic salt relative to the resistance of potassium carbonate versus temperature.
  • FIG. 12 is a graphic representation of log plots of the resistance of a Na 2 CO 3 ZK 2 CO 3 ZRb 2 CO 3 catalyst relative to resistance of the potassium carbonate versus temperature.
  • FIG. 13 is a graphical representation of weight percent of coke, liquid hydrocarbons, and gas versus various hydrogen sources produced from embodiments of contacting the feed with the inorganic salt catalyst.
  • FIG. 14 is a graphical representation of weight percentage versus carbon number of crude products produced from embodiments of contacting the feed with the inorganic salt catalyst.
  • FIG. 15 is a tabulation of components produced from embodiments of contacting the feed with inorganic salt catalysts, a metal salt, or silicon carbide.
  • FIG. 16 is a graphical representation of product selectivity versus calcium oxide, magnesium oxide, zirconium oxide, and silicon carbide.
  • FIG. 17 is a tabulation of components produced from embodiments of contacting the feed with a supported inorganic salt catalyst and an E-Cat.
  • FIG. 18 is a graphical representation of components produced from embodiments of contacting the feed with a supported inorganic salt catalyst and an E-Cat. While the invention is susceptible to various modifications and alternative forms, specific embodiments thereof are shown by way of example in the drawings and will herein be described in detail. The drawings may not be to scale. It should be understood that the drawings and detailed description thereto are not intended to limit the invention to the particular form disclosed, but on the contrary, the intention is to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the present invention. Detailed Description of the Invention
  • a feed and an inorganic salt catalyst may be provided to a contacting zone.
  • Contact of the inorganic salt catalyst with the feed may be performed such that the inorganic salt catalyst becomes fluidized in the contacting zone and a total product is produced.
  • Alkali metal(s) refer to one or more metals from Column 1 of the Periodic Table, one or more compounds of one or more metals from Column 1 of the Periodic Table, or mixtures thereof.
  • Alkaline-earth metal(s) refer to one or more metals from Column 2 of the Periodic Table, one or more compounds of one or more metals from Column 2 of the Periodic Table, or mixtures thereof.
  • AMU refers to atomic mass unit.
  • ASTM American Standard Testing and Materials
  • Asphaltenes refers to organic materials that are found in crudes that are not soluble in straight-chain hydrocarbons such as n-pentane or n-heptane. Asphaltene, in some embodiments, include aromatic and naphthenic ring compounds containing heteroatoms.
  • Atomic hydrogen percentage and atomic carbon percentage of feed, crude product, naphtha, kerosene, diesel, and VGO are as determined by ASTM Method D5291.
  • API gravity refers to API gravity at 15.5 0 C. API gravity is as determined by ASTM Method D6822.
  • Boiling range distributions for the feed and/or total product are as determined by
  • “Br ⁇ nsted-Lowry acid” refers to a molecular entity with the ability to donate a proton to another molecular entity.
  • Br ⁇ nsted-Lowry base refers to a molecular entity that is capable of accepting protons from another molecular entity.
  • Examples of Br ⁇ nsted-Lowry bases include hydroxide (OH “ ), water (H 2 O), carboxylate (RCO 2 " ), halide (Br “ , Cl “ , F “ , T ), bisulfate (HSO 4 “ ), and sulfate (SO 4 2" ).
  • Catalyst refers to one or more supported catalysts, one or more unsupported catalysts, or mixtures thereof.
  • Carbon number refers to the total number of carbon atoms in a molecule.
  • Coke refers to solids containing carbonaceous solids that are not vaporized under process conditions. The content of coke is as determined by mass balance. The weight of coke is the total weight of solid minus the total weight of input catalysts.
  • Content refers to the weight of a component in a substrate (for example, a crude, a total product, or a crude product) expressed as weight fraction or weight percentage based on the total weight of the substrate.
  • Weight fraction refers to parts per million by weight.
  • Diesel refers to hydrocarbons with a boiling range distribution between 260 0 C and 343 0 C (500-650 0 F) at 0.101 MPa. Diesel content is as determined by ASTM Method D2887.
  • distillate refers to hydrocarbons with a boiling range distribution between 204 0 C and 343 0 C (400-650 0 F) at 0.101 MPa. Distillate content is as determined by ASTM Method D2887. Distillate may include kerosene and diesel.
  • DSC differential scanning calorimetry
  • Feed refers to a crude, disadvantaged crude, a mixture of hydrocarbons, or combinations thereof that are to be treated as described herein.
  • Freeze point and “freezing point” refer to the temperature at which formation of crystalline particles occurs in a liquid. A freezing point is as determined by ASTM D2386.
  • GC/MS refers to gas chromatography in combination with mass spectrometry.
  • Hard base refers to anions as described by Pearson in Journal of American Chemical Society, 1963, 85, p. 3533, which is incorporated by reference herein.
  • H/C refers to a weight ratio of atomic hydrogen to atomic carbon. H/C is as determined from the values measured for weight percentage of hydrogen and weight percentage of carbon by ASTM Method D5291.
  • Heteroatoms refer 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 nitrogen, and D4294 for sulfur.
  • Hydrocarbon source refers to hydrogen, and/or a compound and/or compounds when in the presence of a feed and the catalyst react to provide hydrogen to one or more compounds in the feed.
  • a hydrogen source may include, but is not limited to, hydrocarbons (for example, Ci to C 6 hydrocarbons such as methane, ethane, propane, butane, pentane, naphtha), water, or mixtures thereof.
  • hydrocarbons for example, Ci to C 6 hydrocarbons such as methane, ethane, propane, butane, pentane, naphtha
  • a mass balance is conducted to assess the net amount of hydrogen provided to one or more compounds in the feed.
  • Inorganic salt refers to a compound that is composed of a metal cation and an anion.
  • IP refers to the Institute of Petroleum, now the Energy Institute of London, United Kingdom.
  • Iso-paraffins refer to branched-chain saturated hydrocarbons.
  • Kerosene refers to hydrocarbons with a boiling range distribution between about
  • Kerosene content is as determined by ASTM Method D2887.
  • Lewis acid refers to a compound or a material with the ability to accept one or more electrons from another compound.
  • Lewis base refers to a compound and/or material with the ability to donate one or more electrons to another compound.
  • Light Hydrocarbons refer to hydrocarbons having carbon numbers in a range from 1 to 6.
  • 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 or more compounds that are liquid at STP with one or more compounds that are solid at STP.
  • STP standard temperature and pressure
  • MCR Micro-Carbon Residue
  • MCR refers to a quantity of carbon residue remaining after evaporation and pyrolysis of a substance. MCR content is as determined by ASTM Method D4530.
  • Naphtha refers to hydrocarbon components with a boiling range distribution between 38 0 C and 204 0 C (100-400 0 F) at 0.101 MPa. Naphtha content is as determined by ASTM Method D2887.
  • Ni/V/Fe refers to nickel, vanadium, iron, or combinations thereof.
  • Ni/V/Fe content refers to Ni/V/Fe content in a substrate. Ni/V/Fe content is as determined by ASTM Method D5863.
  • Nm 3 /m 3 refers to normal cubic meters of gas per cubic meter of feed.
  • Nonacidic refers to Lewis base and/or Br ⁇ nsted-Lowry base properties.
  • Non-condensable gas refers to components and/or a mixture of components that are gases at standard temperature and pressure (25 0 C, 0.101 MPa, hereinafter referred to as "STP").
  • n-Paraffins refer to normal (straight chain) saturated hydrocarbons.
  • Ole number refers to a calculated numerical representation of the antiknock properties of a motor fuel compared to a standard reference fuel. A calculated octane number of naphtha is as determined by ASTM Method D6730.
  • Olefins refer to compounds with non-aromatic carbon-carbon double bonds. Types of olefins include, but are not limited to, cis, trans, terminal, internal, branched, and linear.
  • Periodic Table refers to the Periodic Table as specified by the International Union of Pure and Applied Chemistry (IUPAC), November 2003.
  • Polyaromatic compounds refer to compounds that include two or more aromatic rings. Examples of polyaromatic compounds include, but are not limited to, indene, naphthalene, anthracene, phenanthrene, benzothiophene, and dibenzothiophene.
  • Residue refers to components that have a boiling range distribution above 538 0 C (1000 0 F) at 0.101 MPa, as determined by ASTM Method D5307.
  • Solid refers to a phase of a substance that has properties of a liquid phase and a solid phase of the substance.
  • semiliquid inorganic salt catalysts include a slurry and/or a phase that has a consistency of, for example, taffy, dough, or toothpaste.
  • Spent hydroprocessing catalyst refers to any catalyst that is no longer considered acceptable for use in a hydrotreating and/or a hydrocracking catalytic process. Spent hydroprocessing catalysts include, but are not limited to, nickel sulfide, vanadium sulfide, and/or molybdenum sulfide.
  • Superbase refers to a material that can deprotonate hydrocarbons such as paraffins and olefins under reaction conditions.
  • TAN refers to a total acid number expressed as milligrams ("mg") of KOH per gram ("g") of sample. TAN is as determined by ASTM Method D664.
  • TAP temporal-analysis-of-products
  • VGO refers to components with a boiling range distribution between about 343 0 C and about 538 0 C (650-1000 0 F) at 0.101 MPa. VGO content is as determined by ASTM Method D2887.
  • WHSV refers to a weight of feed/unit time divided by a volume of catalyst expressed as hours "1 .
  • Crudes may be produced and/or retorted from hydrocarbon containing formations and then stabilized. Crudes are generally solid, semi-solid, and/or liquid. Crudes may include crude oil. 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. Such stabilization may often occur at, or proximate to, the production and/or retorting site.
  • Stabilized crudes typically have not been distilled and/or fractionally distilled in a treatment facility to produce multiple components with specific boiling range distributions (for example, naphtha, distillates, VGO, and/or lubricating oils).
  • Distillation includes, but is not limited to, atmospheric distillation methods and/or vacuum distillation methods.
  • 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 are removed.
  • topped crudes typically 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 stabilized crudes have properties that allow the stabilized crudes to be transported to conventional treatment facilities by transportation carriers (for example, pipelines, trucks, or ships).
  • Other 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. The economic value may be such that a reservoir that includes the disadvantaged crude that is deemed too costly to produce, transport, and/or treat.
  • Properties of disadvantaged crudes may include, but are not limited to: a) TAN of at least 0.5; b) viscosity of at least about 0.2 Pa-s; c) API gravity of at most 19; d) a total Ni/V/Fe content of at least 0.00005 grams or at least 0.0001 grams of Ni/V/Fe per gram of crude; e) a total heteroatoms content of at least 0.005 grams of heteroatoms per gram of crude; f) a residue content of at least 0.01 grams of residue per gram of crude; g) an asphaltenes content of at least 0.04 grams of asphaltenes per gram of crude; h) a MCR content of at least 0.02 grams of MCR per gram of crude; or i) combinations thereof.
  • disadvantaged crude may include, per gram of disadvantaged crude, at least 0.2 grams of residue, at least 0.3 grams of residue, at least 0.5 grams of residue, or at least 0.9 grams of residue. In certain embodiments, disadvantaged crude has about 0.2- 0.99 grams, about 0.3-0.9 grams, or about 0.4-0.7 grams of residue per gram of disadvantaged crude. In certain embodiments, disadvantaged crudes, per gram of disadvantaged crude, may have a sulfur content of at least 0.001 grams, at least 0.005 grams, at least 0.01 grams, at least 0.02 grams, at least 0.03 grams, or at least 0.04 grams.
  • disadvantaged crudes may have a nitrogen content of at least 0.001 grams, at least 0.005 grams, at least 0.01 grams, or at least 0.02 grams per gram of disadvantaged crude.
  • Disadvantaged crudes may include a mixture of hydrocarbons having a range of boiling points.
  • Disadvantaged crudes may include, per gram of disadvantaged crude: at least 0.001 grams, at least 0.005 grams, or at least 0.01 grams of hydrocarbons with a boiling range distribution between about 200 0 C and about 300 0 C at 0.101 MPa; at least 0.001 grams, at least 0.005 grams, or at least 0.01 grams of hydrocarbons with a boiling range distribution between about 300 0 C and about 400 0 C at 0.101 MPa; and at least 0.001 grams, at least 0.005 grams, or at least 0.01 grams of hydrocarbons with a boiling range distribution between about 400 0 C and about 700 0 C at 0.101 MPa, or combinations thereof.
  • disadvantaged crudes may also include, per gram of disadvantaged crude, at least 0.001 grams, at least 0.005 grams, or at least 0.01 grams of hydrocarbons with a boiling range distribution of at most 200 0 C at 0.101 MPa in addition to higher boiling components.
  • the disadvantaged crude has, per gram of disadvantaged crude, a content of such hydrocarbons of at most 0.2 grams, or at most 0.1 grams.
  • disadvantaged crudes may include, per gram of disadvantaged crude, up to 0.9 grams, or up to 0.99 grams of hydrocarbons with a boiling range distribution of at least 300 0 C. In certain embodiments, disadvantaged crudes may also include, per gram of disadvantaged crude, at least 0.001 grams of hydrocarbons with a boiling range distribution of at least 650 0 C. In certain embodiments, disadvantaged crudes may include, per gram of disadvantaged crude, up to about 0.9 grams, or up to about 0.99 grams of hydrocarbons with a boiling range distribution between about 300 0 C and about 1000 0 C.
  • disadvantaged crudes include at least 0.1 grams, at least 0.5 grams, at least 0.8 grams, or at least 0.99 grams of asphaltenes per gram of disadvantaged crude.
  • Disadvantaged crudes may include from about 0.01 grams to about 0.99 grams, from about 0.1 grams to about 0.9 grams, or from about 0.5 grams to about 0.8 grams of asphaltenes per gram of disadvantage crude.
  • Examples of disadvantaged crudes that can be treated using the processes described herein include, but are not limited to, crudes from the following countries and regions of those countries: Canadian Alberta, Venezuelan Orinoco, U.S.
  • disadvantaged crudes may enhance the properties of the dis advantaged crudes such that the crudes are acceptable for transportation and/or treatment.
  • the feed may be topped as described herein.
  • the crude product resulting from treatment of the feed, using methods described herein is suitable for transporting and/or refining.
  • Properties of the crude product are closer to the corresponding properties of West Texas Intermediate crude than the feed, or closer to the corresponding properties of Brent crude than the feed, and thereby have enhanced economic value relative to the economic value of the feed.
  • Such crude product may be refined with less or no pre-treatment, thereby enhancing refining efficiencies.
  • Pre-treatment may include desulfurization, demetallization, and/or atmospheric distillation to remove impurities from the crude product.
  • feeds that have boiling point distributions from about 10 0 C to 1200 0 C may be contacted in accordance with the systems, methods and catalysts described herein.
  • the feed may include, per gram of feed, at least 0.01 grams, at least 0.1 grams, at least 0.5 grams or at least 0.9 grams of a mixture of hydrocarbons having boiling point distributions with an initial boiling point above 538 0 C.
  • the feed may include, per gram of feed, from about 0.01 grams to about 0.9 grams, from about 0.1 grams to about 0.8 grams, from about 0.5 grams to about 0.7 grams of a mixture of hydrocarbons having boiling point distributions with an initial boiling point above 538 0 C.
  • Hydrocarbon mixtures that have at least 0.01 grams, at least 0.1 grams, at least 0.5 grams, at least 0.8 grams, or at least 0.99 grams of VGO per gram of hydrocarbon mixture, may be treated in accordance with the system and methods described herein to produce various amounts of naphtha, kerosene, diesel, or distillate.
  • a hydrocarbon mixture having, per gram of hydrocarbon mixture, from about 0.01 grams to about 0.99 grams, from about 0.05 grams to about 0.9 grams, from about 0.1 grams to about 0.8 grams, from about 0.2 grams to about 0.7 grams, or from about 0.3 grams to about 0.6 grams of VGO may be treated to produce various products having a boiling point distribution lower than the boiling point distribution of VGO.
  • the feed may be contacted with a hydrogen source in the presence of one or more of the catalysts in a contacting zone and/or in combinations of two or more contacting zones.
  • the hydrogen source is generated in situ.
  • In situ generation of the hydrogen source may include the reaction of at least a portion of the feed with the inorganic salt catalyst at temperatures in a range from about 200-1200 0 C, about 300-1000 0 C, about 400-900 0 C, or about 500-800 0 C to form hydrogen and/or light hydrocarbons.
  • In situ generation of hydrogen may include the reaction of at least a portion of the inorganic salt catalyst that includes, for example, alkali metal formate.
  • the total product generally includes gas, vapor, liquids, or mixtures thereof produced during the contacting.
  • the total product includes the crude product that is a liquid mixture at STP and, in some embodiments, hydrocarbons that are not condensable at STP.
  • the total product and/or the crude product may include solids (such as inorganic solids and/or coke). In certain embodiments, the solids may be entrained in the liquid and/or vapor produced during contacting.
  • a contacting zone typically includes a reactor, a portion of a reactor, multiple portions of a reactor, or multiple reactors.
  • reactors that may be used to contact a feed with a hydrogen source in the presence of catalyst include a stacked bed reactor, a fixed bed reactor, a continuously stirred tank reactor (CSTR), a spray reactor, a plug-flow reactor, and a liquid/liquid contactor.
  • CSTR continuously stirred tank reactor
  • a spray reactor a plug-flow reactor
  • a liquid/liquid contactor examples include a fluidized bed reactor and an ebullating bed reactor.
  • Contacting conditions typically include temperature, pressure, feed flow, total product flow, residence time, hydrogen source flow, or combinations thereof. Contacting conditions may be controlled to produce a crude product with specified properties. Contacting temperatures may range from about 200-800 0 C, about 300-700 0 C, or about 400-600 0 C. In embodiments in which the hydrogen source is supplied as a gas (for example, hydrogen gas, methane, or ethane), a ratio of the gas to the feed will generally range from about 1-16,100 Nm 3 W, about 2-8000 Nm 3 W, about 3-4000 Nm 3 W, or about 5-320 Nm 3 W. Contacting typically takes place in a pressure range between about 0.1-20 MPa, about 1-16 MPa, about 2-10 MPa, or about 4-8 MPa.
  • a gas for example, hydrogen gas, methane, or ethane
  • a ratio of steam to feed is in a range from about 0.01-10 kilograms, about 0.03-5 kilograms, or about 0.1-1 kilogram of steam, per kilogram of feed.
  • a flow rate of feed may be sufficient to maintain the volume of feed in the contacting zone of at least 10%, at least 50%, or at least 90% of the total volume of the contacting zone.
  • the volume of feed in the contacting zone is about 40%, about 60%, or about 80% of the total volume of the contacting zone.
  • WHSV in a contacting zone ranges from about 0.1 to about 30 h "1 , about 0.5 to about 20 h "1 , or about 1 to about 10 h "1 .
  • contacting may be done in the presence of an additional gas, for example, argon, nitrogen, methane, ethane, propanes, butanes, propenes, butenes, or combinations thereof.
  • FIG. 1 is a schematic of an embodiment of contacting system 100 used to produce the total product as a vapor.
  • the feed exits feed supply 101 and enters contacting zone 102 via conduit 104.
  • a quantity of the catalyst used in the contacting zone may range from about 1 gram to 1000 grams, about 2 grams to 500 grams, about 3 grams to 200 grams, about 4 grams to 100 grams, about 5 grams to 50 grams, about 6grams to 80 grams, about 7 grams to 70 grams, or about 8 grams to 60 grams, per 100 grams of feed in the contacting zone.
  • contacting zone 102 includes one or more fluidized bed reactors, one or more fixed bed reactors, or combinations thereof.
  • a diluent may be added to the feed to lower the viscosity of the feed.
  • the feed enters a bottom portion of contacting zone 102 via conduit 104.
  • the feed may be heated to a temperature of at least 100 0 C or at least 300 0 C prior to and/or during introduction of the feed to contacting zone 102.
  • the feed may be heated to a temperature in a range from about 100- 500 0 C or about 200-400 0 C.
  • the catalyst is combined with the feed and transferred to contacting zone 102.
  • the feed/catalyst mixture may be heated to a temperature of at least 100 0 C or at least 300 0 C prior to introduction into contacting zone 102.
  • the feed may be heated to a temperature in a range from about 200-500 0 C or about 300-400 0 C.
  • the feed/catalyst mixture is a slurry.
  • TAN of the feed may be reduced prior to introduction of the feed into the contacting zone.
  • alkali salts of acidic components in the feed may be formed.
  • the formation of these alkali salts may remove some acidic components from the feed to reduce the TAN of the feed.
  • the feed is added continuously to contacting zone 102.
  • Mixing in contacting zone 102 may be sufficient to inhibit separation of the catalyst from the feed/catalyst mixture.
  • at least a portion of the catalyst may be removed from contacting zone 102, and in some embodiments, such catalyst is regenerated and re-used.
  • fresh catalyst may be added to contacting zone 102 during the reaction process.
  • the feed and/or a mixture of feed with the inorganic salt catalyst is introduced into the contacting zone as an emulsion.
  • the emulsion may be prepared by combining an inorganic salt catalyst/water mixture with a feed/surfactant mixture.
  • a stabilizer is added to the emulsion.
  • the emulsion may remain stable for at least 2 days, at least 4 days, or at least 7 days. Typically, the emulsion may remain stable for 30 days, 10 days, 5 days, or 3 days.
  • Surfactants include, but are not limited to, organic polycarboxylic acids (Tenax 2010; MeadWestvaco Specialty Product Group; Charleston, South Carolina, U.S.A.), C 21 dicarboxylic fatty acid (DIACID 1550; MeadWestvaco Specialty Product Group), petroleum sulfonates (Hostapur SAS 30; Clarient Corporation, Charlotte, North Carolina, U.S.A.), Tergital NP-40 Surfactant (Union Carbide; Danbury, Connecticut, U.S.A.), or mixtures thereof.
  • Stabilizers include, but are not limited to, diethyleneamine (Aldrich Chemical Co.; Milwaukee, Wisconsin, U.S.A.) and/or monoethanolamine (J. T. Baker; Phillipsburg, New Jersey, U.S.A.
  • Recycle conduit 106 may couple conduit 108 and conduit 104. In some embodiments, recycle conduit 106 may directly enter and/or exit contacting zone 102. Recycle conduit 106 may include flow control valve 110. Flow control valve 110 may allow at least a portion of the material from conduit 108 to be recycled to conduit 104 and/or contacting zone 102. In some embodiments, a condensing unit may be positioned in conduit 108 to allow at least a portion of the material to be condensed and recycled to contacting zone 102. In certain embodiments, recycle conduit 106 may be a gas recycle line. Flow control valves 110 and 110' may be used to control flow to and from contacting zone 102 such that a constant volume of liquid in the contacting zone is maintained.
  • a substantially selected volume range of liquid can be maintained in the contacting zone 102.
  • a volume of feed in contacting zone 102 may be monitored using standard instrumentation.
  • Gas inlet port 112 may be used to allow addition of the hydrogen source and/or additional gases to the feed as the feed enters contacting zone 102.
  • steam inlet port 114 may be used to allow addition of steam to contacting zone 102.
  • an aqueous stream is introduced into contacting zone 102 through steam inlet port 114.
  • at least a portion of the total product is produced as vapor from contacting zone 102.
  • the total product is produced as vapor and/or a vapor containing small amounts of liquids and solids from the top of contacting zone 102.
  • the vapor is transported to separation zone 116 via conduit 108.
  • the ratio of a hydrogen source to feed in contacting zone 102 and/or the pressure in the contacting zone may be changed to control the vapor and/or liquid phase produced from the top of contacting zone 102.
  • the vapor produced from the top of contacting zone 102 includes at least 0.5 grams, at least 0.8 grams, at least 0.9 grams, or at least 0.97 grams of crude product per gram of feed.
  • the vapor produced from the top of contacting zone 102 includes from about 0.8-0.99 grams, or about 0.9-0.98 grams of crude product per gram of feed.
  • Used catalyst and/or solids may remain in contacting zone 102 as by-products of the contacting process.
  • the solids and/or used catalyst may include residual feed and/or coke.
  • separation unit 116 the vapor is cooled and separated to form the crude product and gases using standard separation techniques.
  • the crude product exits separation unit 116 and enters crude product receiver 119 via conduit 118.
  • the resulting crude product may be suitable for transportation and/or treatment.
  • Crude product receiver 119 may include one or more pipelines, one or more storage units, one or more transportation vessels, or combinations thereof.
  • the separated gas for example, hydrogen, carbon monoxide, carbon dioxide, hydrogen sulfide, or methane
  • the separated gas is transported to other processing units (for example, for use in a fuel cell or a sulfur recovery plant) and/or recycled to contacting zone 102 via conduit 120.
  • entrained solids and/or liquids in the crude product may be removed using standard physical separation methods (for example, filtration, centrifugation, or membrane separation).
  • FIG. 2 depicts contacting system 122 for treating feed with one or more catalysts to produce a total product that may be a liquid, or a liquid mixed with gas or solids.
  • the feed may enter contacting zone 102 as described herein via conduit 104.
  • Conduit 104 may include gas inlet port 112.
  • gas inlet port 112 may directly enter contacting zone 102.
  • steam inlet port 114 may be used to allow addition of the steam to contacting zone 102.
  • the feed may be contacted with the catalyst in contacting zone 102 to produce a total product.
  • conduit 106 allows at least a portion of the total product to be recycled to contacting zone 102.
  • a condensing unit may be positioned (for example, in conduit 106) to allow at least a portion of the mixture in the conduit to be condensed and recycled to contacting zone 102 for further processing.
  • recycle conduit 106 may be a gas recycle line.
  • conduit 108 may include a filter for removing particles from the total product.
  • the crude product may be separated from the total product and/or catalyst.
  • the solids may be separated from the total product using standard solid separation techniques (for example, centrifugation, filtration, decantation, membrane separation).
  • Solids include, for example, a combination of catalyst, used catalyst, and/or coke.
  • a portion of the gases is separated from the total product.
  • at least a portion of the total product and/or solids may be recycled to conduit 104 and/or, in some embodiments, to contacting zone 102 via conduit 126. The recycled portion may, for example, be combined with the feed and enter contacting zone 102 for further processing.
  • the crude product may exit separation zone 124 via conduit 128.
  • the crude product may be transported to the crude product receiver.
  • contact of a catalyst with gas and a feed may be performed under fluidization conditions. Fluidization of the catalyst may allow operation of the reaction to be preformed at less stringent conditions. For example, fluidization of the catalyst may lower the total amount of heat required to produce the total product, thus the contacting zone may be operated at reduced temperatures and pressures relative to a slurry or fixed bed process.
  • catalytic cracking and steam reformation processes may be performed at temperatures of at most 1000 0 C, at most 900 0 C, at most 800 0 C, at most 700 0 C, or at most 600 0 C and at pressures of at most 4 MPa, at most 3.5 MPa, at most, 3 MPa, or at most 2 MPa when using a supported inorganic salt catalyst in a fluidized catalyst contacting zone. Fluidization of the catalyst may also allow an increased surface area of contact for the feed with the catalyst. An increased surface area of contact may lead to increased conversion of feed to total products.
  • an inorganic salt catalyst is a supported catalyst. Supported inorganic salt catalysts may be more readily fluidized than unsupported inorganic salt catalysts.
  • FIG. 3 depicts contacting system 130 for treating a feed with one or more catalysts to produce a total product that may be gas and/or liquid.
  • Contacting zone 102 may be a fluidized reactor. The feed may enter contacting zone 102 via conduit 104. The feed may be heated as previously described, emulsified, and/or mixed with catalyst as previously described.
  • Conduit 104 may include gas inlet port 112 and steam inlet port 114. Steam inlet ports 114', 114" may directly enter contacting zone 102. In some embodiments, gas inlet port 112 may directly enter contacting zone 102. In certain embodiments, steam inlet ports 114' and 114" are not necessary.
  • the catalyst may enter contacting zone via conduit 132. A quantity of the catalyst used in the contacting zone may range from about 1 gram to 1000 grams, about 2 grams to 500 grams, about 3 grams to 200 grams, about 4 grams to 100 grams, about 5 grams to 50 grams, about 6 grams to 80 grams, about 7 grams to 70 grams, or about 8 grams to 60 grams, per 100 grams of feed in the contacting zone.
  • the catalyst may enter contacting zone at various elevations of the contacting zone (for example, bottom elevation, middle elevation, and/or upper elevation).
  • Conduit 106 allows at least a portion of the total product/feed mixture to be recycled.
  • the catalyst may be fluidized through the upward lift of gas and feed and/or recycled total product/feed mixture, which are distributed across the contacting zone through distributor 134 and a grid plate 136. Spent catalyst and/or a portion of the total product/feed mixture may exit contacting zone 102 via conduit 138.
  • Pump 140 controls the flow of fluidized liquid obtained from internal vapor/liquid separator 142. The height of the fluidized bed is adjusted by varying the speed of pump 140 using methods known in the art.
  • impurities for example, coke, nitrogen containing compounds, sulfur containing compounds, and/or metals such as nickel and/or vanadium
  • contacting impurities for example, coke, nitrogen containing compounds, sulfur containing compounds, and/or metals such as nickel and/or vanadium
  • removal of the impurities in situ may enhance contacting run times as compared to ending the run and removing all the catalyst from the contacting zone.
  • In situ removal of the impurities may be performed through combustion of the catalyst.
  • an oxygen source for example, air and/or oxygen
  • An oxygen source may be added at a rate sufficient to from a combustion front, but the formed combustion front is inhibited from entering the headspace of contacting zone 102 (for example, oxygen may be added at a rate sufficient to maintain the total mole percent of oxygen in the head-space below 7 percent). Heat from the combustion process may lessen the requirement for heat from an external source to be added to contacting zone 102 during use.
  • Feed may be fluidly contacted with hydrogen in the presence of one or more catalysts in contacting zone 102 to produce a total product.
  • Total product may exit contacting zone 102 via conduit 108 and enter separation zone 144.
  • Separation zone may be similar, or the same as, previously described separation zones or separation zones know in the art.
  • Total product may include crude product, gas, water, solids, catalyst, or combinations thereof.
  • Temperatures in contacting zone 102 may range from about 300 0 C to about 1000 0 C, about 400 0 C to about 900 0 C, from about 500 0 C to about 800 0 C, about 600 0 C to about 700 0 C or about 750 0 C.
  • separation zone 144 the total product is separated to form crude product and/or gas.
  • Crude product may exit separation zone 144 via conduit 146. Gas may exit separation zone 144 via conduit 148.
  • the crude product and/or gas may be used as is or further processed.
  • separated catalyst may be regenerated and/or combined with fresh catalyst entering contacting zone 102.
  • Fluidly contacting the feed with a hydrogen source in the presence of one or more inorganic metal salt catalysts may be an endothermic process.
  • fluidly contacting a feed with the inorganic metal salt catalyst may be up to 4 times as endothermic as a conventional fluidized catalytic cracking process.
  • an external heat source may be used to supply heat to the contacting zone.
  • the external heat supply may be a combustor, a catalyst regeneration zone, a power plant, or any source of heat known in the art.
  • FIG. 4 depicts contacting system 150.
  • Contacting system 150 may be a fluidized catalytic cracking system and/or a modified fluidized catalytic cracking system.
  • Contacting system 150 includes contacting zone 102, regeneration zone 152, and recovery zone 154. In some embodiments, contacting zone 102 and regeneration zone 152 are combined as one zone.
  • Contacting zone 102 includes fluidizer 156 and internal separators 158, 158'. Feed enters contacting zone 102 via conduit 104. Catalyst enters contacting zone 102 via inlet port 160.
  • a quantity of the catalyst used in the contacting zone may range from about 1-1000 grams, about 2-500 grams, about 3-200 grams, about 4-100 grams, about 5-50 grams, about 6-80 grams, about 7-70 grams, or about 8-60 grams, per 100 grams of feed in the contacting zone.
  • Conduit 104 may include catalyst inlet port 160, gas inlet port 112, and steam inlet port 114.
  • steam, gas, and/or a hydrogen source may be mixed with the feed and catalyst prior to entering contacting zone 102.
  • contacting zone 102 may include steam inlet port 114'.
  • Steam inlet port 114' may allow additional steam or superheated steam to be added to the contacting zone. Heat from the steam may allow more controlled heating of the fluidizer 156.
  • Fluidization of the feed and catalyst in fluidizer 156 may be performed using atomization nozzles, spray nozzles, pumps, and/or other fluidizing methods known in the art.
  • an oxygen source may be added to contacting zone 102 as described for contacting system 130.
  • Internal separators 158, 158' may separate a portion of the catalyst from the total product/feed mixture and recycle the total product/feed mixture to fluidizer 156. Separated catalyst may exit contacting zone 102 via conduit 162. Separated catalyst refers to used catalyst and/or a mixture of used catalyst and new catalyst. Used catalyst refers to catalyst that has been contacted with feed in the contacting zone.
  • Separated catalyst may enter regeneration zone 152 via conduit 166.
  • Valve 164 may regulate flow of separated catalyst as it enters regeneration zonel52.
  • An oxygen source may enter regeneration zone 152 via gas inlet port 168.
  • At least a portion of the catalyst may be regenerated by removal of impurities from the catalyst through combustion.
  • combustion gas flue gas
  • Heat generated from the combustion process may be transferred to contacting zone 102. Transferred heat may range from about 500 0 C to about 1000 0 C, from about 600 0 C to about 900 0 C, or from about 700 0 C to about 800 0 C.
  • At least a portion of regenerated catalyst may exit regeneration zone 152 via conduit 170.
  • Valve 172 may be used to regulate flow of catalyst into conduit 104.
  • new catalyst and/or spent hydroprocessing catalyst is added to conduit 170 via conduit 174.
  • New catalyst and/or spent hydroprocessing catalyst may be combined with regenerated catalyst in conduit 170.
  • the catalyst is added to conduit 170 and/or contacting zone 102 using a sprayer.
  • Combustion gas may exit regeneration zone 152 and enter recovery zone 154 via conduit 178.
  • Combustion gas may include entrained inorganic salts of the catalyst.
  • the combustion gas may include catalyst particles, which may be removed using physical separation methods.
  • the combustion gas is separated from catalyst and/or the inorganic salts.
  • the combustion gas includes a fluidized bed with particles that may combine with the inorganic salts of the catalyst.
  • the combined particle/inorganic salts may be separated from the combustion gas.
  • the separated particle/inorganic salts may be used as and/or combined with the catalyst entering contacting zone 102.
  • the combustion gas may be treated with water to partially dissolve inorganic salts entrained in the combustion gas to form an aqueous inorganic salt solution.
  • the aqueous inorganic salt solution may be separated from the combustion gas using gas/liquid separation methods known in the art.
  • the aqueous inorganic salt solution may be heated to remove the water to form an inorganic salt catalyst and/or recover the inorganic salts (for example, recover cesium, magnesium, calcium, and/or potassium salts).
  • the recovered inorganic salts and/or formed catalyst may be used as and/or combined with the catalyst entering contacting zone 102.
  • the recovered inorganic salts may be sprayed into contacting zone 102 and/or conduit 174.
  • the recovered inorganic salts may be deposited on a catalyst support and the result supported inorganic salts may enter and/or be sprayed into contacting zone 102 and/or conduit 174.
  • the total product may exit from an upper elevation of contacting zone via conduit 108.
  • the total product enters separation zone 144 and is separated into crude product and/or gas. Crude product may exit separation zone 144 via conduit 146. Gas may exit separation zone 144 via conduit 148.
  • the crude product and/or gas may be used as is or further processed.
  • the total product and/or crude product may include at least a portion of the catalyst.
  • Gases entrained in the total product and/or crude product may be separated using standard gas/liquid separation techniques, for example, sparging, membrane separation, and pressure reduction.
  • the separated gas is transported to other processing units (for example, for use in a fuel cell, a sulfur recovery plant, other processing units, or combinations thereof) and/or recycled to the contacting zone.
  • FIG. 5 is a schematic of an embodiment of a separation zone in combination with a contacting system.
  • Contacting system 190 may be contacting system 100, contacting system 122, contacting system 130, contacting system 150, or combinations thereof (shown in FIGS. 1 through 4).
  • the feed enters separation zone 192 via conduit 104.
  • separation zone 192 at least a portion of the feed is separated using standard separation techniques to produce a separated feed and hydrocarbons.
  • the separated feed in some embodiments, includes a mixture of components with a boiling range distribution of at least 100 0 C, at least 120 0 C or, in some embodiments, a boiling range distribution of at least 200 0 C.
  • the separated feed includes a mixture of components with a boiling range distribution between about 100-1000 0 C, about 120-900 0 C, or about 200-800 0 C.
  • the separated feed is VGO.
  • the hydrocarbons separated from the feed exit separation zone 192 via conduit 194 to be transported to other processing units, treatment facilities, storage facilities, or combinations thereof.
  • At least a portion of the separated feed exits separation zone 192 and enters contacting system 190 via conduit 196 to be further processed to form the crude product, which exits contacting system 130 via conduit 198.
  • the crude product produced from a feed by any method described herein is blended with a crude that is the same as or different from the feed.
  • 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.
  • the resulting blended product may be suitable for transportation and/or treatment.
  • FIG. 6 is a schematic of an embodiment of a combination of blending zone 200 and contacting system 190.
  • at least a portion of the crude product exits contacting system 190 via conduit 198 and enters blending zone 200.
  • blending zone 200 at least a portion of the crude product is combined with one or more process streams (for example, a hydrocarbon stream produced from separation of one or more feeds, or naphtha), a crude, a feed, or mixtures thereof, to produce a blended product.
  • the process streams, feed, crude, or mixtures thereof are introduced directly into blending zone 200 or upstream of the blending zone via conduit 202.
  • a mixing system may be located in or near blending zone 200.
  • the blended product may meet specific product specifications. Specific product specifications include, but are not limited to, a range of or a limit of API gravity, TAN, viscosity, or combinations thereof.
  • the blended product exits blending zone 200 via conduit 204 to be transported and/or processed.
  • methanol is generated during the contacting process using the catalyst.
  • hydrogen and carbon monoxide may react to form methanol.
  • the recovered methanol may contain dissolved salts, for example, potassium hydroxide.
  • the recovered methanol may be combined with additional feed to form a feed/methanol mixture. Combining methanol with the feed tends to lower the viscosity of the feed.
  • Heating the feed/methanol mixture to at most 500 0 C may reduce TAN of the feed to less than 1.
  • FIG. 7 is a schematic of an embodiment of a separation zone in combination with a contacting system in combination with a blending zone.
  • the feed enters separation zone 192 through conduit 104.
  • the feed is separated as previously described to form a separated feed.
  • the separated feed enters contacting system 190 through conduit 196.
  • the crude product exits contacting system 190 and enters blending zone 200 through conduit 198.
  • blending zone 200 other process stream and/or crudes introduced via conduit 202 are combined with the crude product to form a blended product.
  • the blended product exits blending zone 200 via conduit 204.
  • FIG. 8 is a schematic of multiple contacting system 206.
  • Contacting system 208 (for example, contacting systems shown in FIGS. 1 through 4) may be positioned before contacting system 210. In an alternate embodiment, the positions of the contacting systems can be reversed.
  • Contacting system 208 includes an inorganic salt catalyst.
  • Contacting system 210 may include one or more catalysts.
  • the catalyst in contacting system 210 may be an additional inorganic salt catalyst and/or commercial catalysts.
  • the feed enters contacting system 208 via conduit 104 and is contacted with a hydrogen source in the presence of the inorganic salt catalyst to produce the total product.
  • the total product includes hydrogen and, in some embodiments, a crude product.
  • the total product may exit contacting system 208 via conduit 108.
  • the hydrogen generated from contact of the inorganic salt catalyst with the feed may be used as a hydrogen source for contacting system 210. At least a portion of the generated hydrogen is transferred to contacting system 210 from contacting system 208 via conduit 212. In an alternate embodiment, such generated hydrogen may be separated and/or treated, and then transferred to contacting system 210 via conduit 212. In certain embodiments, contacting system 210 may be a part of contacting system 208 such that the generated hydrogen flows directly from contacting system 208 to contacting system 210. In some embodiments, a vapor stream produced from contacting system 208 is directly mixed with the feed entering contacting system 210.
  • a second feed enters contacting system 210 via conduit 214.
  • contact of the feed with at least a portion of the generated hydrogen and the catalyst produces a product.
  • the product is, in some embodiments, the total product.
  • the product exits contacting system 210 via conduit 216.
  • a system that includes contacting systems, contacting zones, separation zones, and/or blending zones, as shown in FIGS. 1-8, may be located at or proximate to a production site that produces disadvantaged feed. After processing through the catalytic system, the feed and/or crude product may be considered suitable for transportation and/or for use in a refinery process.
  • the crude product and/or the blended product are transported to a refinery and/or a treatment facility.
  • the crude product and/or the blended product may be processed to produce commercial products such as transportation fuel, heating fuel, lubricants, or chemicals.
  • Processing may include distilling and/or fractionally distilling the crude product and/or blended product to produce one or more distillate fractions.
  • the crude product, the blended product, and/or the one or more distillate fractions may be hydrotreated.
  • the total product includes, in some embodiments, at most 0.2 grams of coke, at most 0.1 grams of coke, at most 0.05 grams, at most 0.03 grams, or at most 0.01 grams of coke per gram of total product. In certain embodiments, the total product is substantially free of coke (that is, coke is not detectable). In some embodiments, the crude product may include at most 0.05 grams, at most 0.03 grams, at most 0.01 grams, at most 0.005 grams, or at most 0.003 grams of coke per gram of crude product.
  • the crude product has a coke content in a range from above 0 to about 0.05, about 0.00001- 0.03 grams, about 0.0001-0.01 grams, or about 0.001-0.005 grams per gram of crude product, or is not detectable.
  • the crude product has an MCR content that is at most 90%, at most 80%, at most 50%, at most 30%, or at most 10% of the MCR content of the feed. In some embodiments, the crude product has a negligible MCR content. In some embodiments, the crude product has, per gram of crude product, at most 0.05 grams, at most 0.03 grams, at most 0.01 grams, or at most 0.001 grams of MCR. Typically, the crude product has from about 0 grams to about 0.04 grams, about 0.000001-0.03 grams, or about 0.00001-0.01 grams of MCR per gram of crude product.
  • the total product includes non-condensable gas.
  • the non- condensable gas typically includes, but is not limited to, carbon dioxide, ammonia, hydrogen sulfide, hydrogen, carbon monoxide, methane, other hydrocarbons that are not condensable at STP, or a mixture thereof.
  • hydrogen gas, carbon dioxide, carbon monoxide, or combinations thereof can be formed in situ by contact of steam, light hydrocarbons, and feed with the inorganic salt catalyst. Certain embodiments of this kind of process are generally referred to as steam reforming. Reaction of feed, steam, hydrogen, and an inorganic salt catalyst may occur under circulating fluidization conditions.
  • the inorganic salt catalysts used may include supported and non-supported inorganic salt catalysts.
  • an inorganic salt catalyst may be selected to produce mostly gas or mostly crude product.
  • an inorganic salt catalyst that is an alkaline- earth metal oxide may be selected to produce gas and a minimal amount of crude product from a feed.
  • the produced gas may include an enhanced amount of carbon oxides.
  • An inorganic salt catalyst that is a mixture of carbonates may be selected to produce mostly crude product and a minimal amount of gas (e.g., in a catalytic cracking process).
  • a supported inorganic salt catalyst may be used in a fluidized catalytic cracking process.
  • the total amount of carbon monoxide and carbon dioxide produced may be at least 0.1 grams, at least 0.3 grams, at least 0.5 grams, at least 0.8 grams, at least 0.9 grams per gram of gas.
  • the total amount of carbon monoxide and carbon dioxide produce may range from about 0.1 grams to 0.99 grams, about 0.2 grams to about 0.9 grams, about 0.3 grams to about 0.8 grams or about 0.4 grams to about 0.7 grams per gram of gas.
  • a molar ratio of the generated carbon monoxide to the generated carbon dioxide in some embodiments, is at least 0.3, at least 0.5, at least 0.7, at least 1, at least 1.5, at least 2, or at least 3.
  • a molar ratio of the generated carbon monoxide to the generated carbon dioxide is in a range from about 1:4, about 2:3, about 3:2, or about 4:1.
  • the ability to generate carbon monoxide preferentially to carbon dioxide in situ may be beneficial to other processes located in a proximate area or upstream of the process.
  • the generated carbon monoxide may be used as a reducing agent in treating hydrocarbon formations or used in other processes, for example, syngas processes.
  • the total product as produced herein may include crude product, hydrocarbon gases, and carbon oxide gases (carbon monoxide and carbon dioxide).
  • a conversion of feed, based on molar amount of carbon in the feed, to total hydrocarbons (combined crude product and hydrocarbon gases) produced may be at most 50%, at most 40%, at most 30, at most 20%, at most 10%, at most 1%.
  • a conversion of feed, based on molar amount of carbon in the feed, to hydrocarbons produced may range from 0 to about 50%, about 0.1% to about 40%, about 1% to about 30%, about 5% to about 20% or about 3% to about 10%.
  • a conversion of feed, based on molar amount of carbon in the feed, to total carbon oxide gases (combined carbon monoxide and carbon dioxide) produced may be at least 1%, at least 10%, at least 20%, at least 50%, at least 60%, at least 70%, at least 80%, at least 90%, or at least 95%.
  • a conversion of feed, based on molar amount of carbon in the feed, to hydrocarbons produce may range from 0 to about 99%, about 1% to about 90%, about 5% to about 80%, about 10% to about 70%, about 20% to about 60%, about 30% to about 50%.
  • a content of hydrogen in the total product is less than a content of hydrogen in feed, based on molar amount of hydrogen in the feed.
  • a decreased amount of hydrogen in the total product may result in products that differ from products produced using conventional cracking, hydrotreating, and/or hydroprocessing methods.
  • the total product as produced herein may include a mixture of compounds that have a boiling range distribution between about -10 0 C and about 538 0 C.
  • the mixture may include hydrocarbons that have carbon numbers in a range from 1 to 4.
  • the mixture may include from about 0.001-0.8 grams, about 0.003-0.1 grams, or about 0.005-0.01 grams, of C 4 hydrocarbons per gram of such mixture.
  • the C 4 hydrocarbons may include from about 0.001-0.8 grams, about 0.003-0.1 grams, or about 0.005-0.01 grams of butadiene per gram of C 4 hydrocarbons.
  • iso-paraffins are produced relative to n-paraffins at a weight ratio of at most 1.5, at most 1.4, at most 1.0, at most 0.8, at most 0.3, or at most 0.1. In certain embodiments, iso-paraffins are produce relative to n-paraffins at a weight ratio in a range from about 0.00001-1.5, about 0.0001- 1.0, or about 0.001-0.1.
  • the paraffins may include iso-paraffins and/or n-paraffins.
  • the total product and/or crude product may include olefins and/or paraffins in ratios or amounts that are not generally found in crudes produced and/or retorted from a formation.
  • the olefins include a mixture of olefins with a terminal double bond ("alpha olefins") and olefins with internal double bonds.
  • the olefin content of the crude product is greater than the olefin content of the feed by a factor of about 2, about 10, about 50, about 100, or at least 200.
  • the olefin content of the crude product is greater than the olefin content of the feed by a factor of at most 1,000, at most 500, at most 300, or at most 250.
  • the hydrocarbons with a boiling range distribution between 20-400 0 C have an olefins content in a range from about 0.00001-0.1 grams, about 0.0001- 0.05 grams, or about 0.01-0.04 grams per gram of hydrocarbons having a boiling range distribution in a range between 20-400 0 C.
  • At least 0.001 grams, at least 0.005 grams, or at least 0.01 grams of alpha olefins per gram of crude product may be produced.
  • the crude product has from about 0.0001-0.5 grams, about 0.001-0.2 grams, or about 0.01-0.1 grams of alpha olefins per gram of crude product.
  • the hydrocarbons with a boiling range distribution between about 20-400 0 C have an alpha olefins content in a range from about 0.0001-0.08 grams, about 0.001-0.05 grams, or about 0.01-0.04 grams per gram of hydrocarbons with a boiling range distribution between about 20-400 0 C.
  • the hydrocarbons with a boiling range distribution between 20-204 0 C have a weight ratio of alpha olefins to internal double bond olefins of at least 0.7, at least 0.8, at least 0.9, at least 1.0, at least 1.4, or at least 1.5. In some embodiments, the hydrocarbons with a boiling range distribution between 20-204 0 C have a weight ratio of alpha olefins to internal double bond olefins in a range from about 0.7-10, about 0.8-5, about 0.9-3, or about 1-2. A weight ratio of alpha olefins to internal double bond olefins of the crudes and commercial products is typically at most 0.5.
  • the ability to produce an increased amount of alpha olefins to olefins with internal double bonds may facilitate the conversion of the crude product to commercial products.
  • contact of a feed with a hydrogen source in the presence of an inorganic salt catalyst may produce hydrocarbons with a boiling range distribution between 20-204 0 C that include linear olefins.
  • the linear olefins have cis and trans double bonds.
  • a weight ratio of linear olefins with trans double bonds to linear olefins with cis double bonds is at most 0.4, at most 1.0, or at most 1.4.
  • the weight ratio of linear olefins with trans double bonds to linear olefins with cis double bonds is in a range from about 0.001-1.4, about 0.01-1.0, or about 0.1-0.4.
  • hydrocarbons having a boiling range distribution in a range between 20-204 0 C have a n-paraffins content of at least 0.1 grams, at least 0.15 grams, at least 0.20 grams, or at least 0.30 grams per gram of hydrocarbons having a boiling range distribution in a range between 20-400 0 C.
  • the n-paraffins content of such hydrocarbons, per gram of hydrocarbons may be in a range from about 0.001-0.9 grams, about 0.1-0.8 grams, or about 0.2-0.5 grams.
  • such hydrocarbons have a weight ratio of the iso-paraffins to the n-paraffins of at most 1.5, at most 1.4, at most 1.0, at most 0.8, or at most 0.3.
  • the n-paraffins content of the crude product may be estimated to be in a range from about 0.001-0.9 grams, about 0.01-0.8 grams, or about 0.1-0.5 grams per gram of crude product.
  • the crude product has a total Ni/V/Fe content of at most 90%, at most 50%, at most 10%, at most 5%, or at most 3% of a Ni/V/Fe content of the feed.
  • the crude product includes, per gram of crude product, at most 0.0001 grams, at most 1 x 10 " grams, or at most 1 x 10 " grams of Ni/V/Fe.
  • the crude product has, per gram of crude product, a total Ni/V/Fe content in a range from about 1 x 10 "7 grams to about 5 x 10 " grams, about 3 x 10 "7 grams to about 2 x 10 "5 grams, or about 1 x 10 "6 grams to about 1 x 10 "5 grams.
  • the crude product has a TAN of at most 90%, at most 50%, or at most 10% of the TAN of the feed.
  • the crude product may, in certain embodiments, have a TAN of at most 1, at most 0.5, at most 0.1, or at most 0.05.
  • TAN of the crude product may be in a range from about 0.001 to about 0.5, about 0.01 to about 0.2, or about 0.05 to about 0.1.
  • the API gravity of the crude product is at least 10% higher, at least 50% higher, or at least 90% higher than the API gravity of the feed. In certain embodiments, API gravity of the crude product is between about 13-50, about 15-30, or about 16-20. In some embodiments, the crude product has a total heteroatoms content of at most
  • the crude product has a total heteroatoms content of at least 10%, at least 40%, or at least 60% of the total heteroatoms content of the feed.
  • the crude product may have a sulfur content of at most 90%, at most 70%, or at most 60% of a sulfur content of the feed.
  • the sulfur content of the crude product, per gram of crude product may be at most 0.02 grams, at most 0.008 grams, at most 0.005 grams, at most 0.004 grams, at most 0.003 grams, or at most 0.001 grams.
  • the crude product has, per gram of crude product, a sulfur content in a range from about 0.0001-0.02 grams or about 0.005-0.01 grams.
  • the crude product may have a nitrogen content of at most 90% or at most 80% of a nitrogen content of the feed.
  • the nitrogen content of the crude product, per gram of crude product may be at most 0.004 grams, at most 0.003 grams, or at most 0.001 grams.
  • the crude product has, per gram of crude product, a nitrogen content in a range from about 0.0001-0.005 grams, or about 0.001- 0.003 grams.
  • the crude product has, per gram of crude product, from about 0.05-0.2 grams, or about 0.09-0.15 grams of hydrogen.
  • the atomic H/C of the crude product may be at most 1.8, at most 1.7, at most 1.6, at most 1.5, or at most 1.4.
  • the atomic H/C of the crude product is about 80-120%, or about 90-110% of the atomic H/C of the feed.
  • the atomic H/C of the crude product is about 100-120% of the atomic H/C of the feed.
  • a crude product atomic H/C within 20% of the feed atomic H/C indicates that uptake and/or consumption of hydrogen in the process is minimal.
  • the crude product includes components with a range of boiling points.
  • the crude product includes: at least 0.001 grams, or from about 0.001 to about 0.5 grams of hydrocarbons with a boiling range distribution of at most 200 0 C or at most 204 0 C at 0.101 MPa; at least 0.001 grams, or from about 0.001 to about 0.5 grams of hydrocarbons with a boiling range distribution between about 200 0 C and about 300 0 C at 0.101 MPa; at least 0.001 grams, or from about 0.001 to about 0.5 grams of hydrocarbons with a boiling range distribution between about 300 0 C and about 400 0 C at 0.101 MPa; and at least 0.001 grams, or from about 0.001 to about 0.5 grams of hydrocarbons with a boiling range distribution between about 400 0 C and about 538 0 C at 0.101 MPa.
  • the crude product includes, per gram of crude product, from about 0.001 grams to about 0.9 grams, from about 0.005 grams to about 0.8 grams, from about 0.01 grams to about 0.7 grams, or from about 0.1 gram to about 0.6 grams of hydrocarbons with a boiling range distribution between about 204 0 C and 343 0 C.
  • the crude product has, per gram of crude product, a naphtha content from about 0.00001-0.2 grams, about 0.0001-0.1 grams, or about 0.001-0.05 grams.
  • the crude product has from 0.001-0.2 grams or 0.01-0.05 grams of naphtha.
  • the naphtha has at most 0.15 grams, at most 0.1 grams, or at most 0.05 grams of olefins per gram of naphtha.
  • the crude product has, in certain embodiments, from 0.00001-0.15 grams, 0.0001-0.1 grams, or 0.001-0.05 grams of olefins per gram of crude product.
  • the naphtha has, per gram of naphtha, a benzene content of at most 0.01 grams, at most 0.005 grams, or at most 0.002 grams.
  • the naphtha has a benzene content that is non-detectable, or in a range from about 1 x 10 "7 grams to about 1 x 10 ⁇ 2 grams, about 1 x 10 ⁇ 6 grams to about 1 x 10 "5 grams, about 5 x 10 "6 grams to about 1 x 10 "4 grams.
  • Compositions that contain benzene may be considered hazardous to handle, thus a crude product that has a relatively low benzene content may not require special handling.
  • naphtha may include aromatic compounds.
  • Aromatic compounds may include monocyclic ring compounds and/or polycyclic ring compounds.
  • the monocyclic ring compounds may include, but are not limited to, benzene, toluene, ortho-xylene, meta-xylene, para- xylene, ethyl benzene, l-ethyl-3-methyl benzene; 1-ethyl- 2-methyl benzene; 1,2,3-trimethyl benzene; 1,3,5-trimethyl benzene; l-methyl-3 -propyl benzene; l-methyl-2-propyl benzene; 2-ethyl-l,4-dimethyl benzene; 2-ethyl-2,4-dimethyl benzene; 1,2,3,4-tetra-methyl benzene; ethyl, pentylmethyl benzene; 1,3 diethyl-2,4,5,6- tetramethyl benz
  • the crude product has, per gram of crude product, a toluene content from about 0.001-0.2 grams, about 0.05-0.15 grams, or about 0.01-0.1 grams.
  • the crude product has, per gram of crude product, a meta-xylene content from about 0.001-0.1 grams, about 0.005-0.09 grams, or about 0.05-0.08 grams.
  • the crude product has, per gram of crude product, an ortho-xylene content from about 0.001-0.2 grams, about 0.005- 0.1 grams, or about 0.01-0.05 grams.
  • the crude product has, per gram of crude product, a para- xylene content from about 0.001-0.09 grams, about 0.005-0.08 grams, or about 0.001- 0.06 grams.
  • Crudes may be valued based on an estimation of a gasoline potential of the crudes.
  • Gasoline potential may include, but is not limited to, a calculated octane number for the naphtha portion of the crudes.
  • Crudes typically have calculated octane numbers in a range of about 35-60.
  • the octane number of gasoline tends to reduce the requirement for additives that increase the octane number of the gasoline.
  • the crude product includes naphtha that has an octane number of at least 60, at least 70, at least 80, or at least 90.
  • the octane number of the naphtha is in a range from about 60- 99, about 70-98, or about 80-95.
  • the crude product has a higher total aromatics content in hydrocarbons having a boiling range distribution between 204 0 C and 500 0 C (total "naphtha and kerosene") relative to the total aromatics content in the total naphtha and kerosene of the feed by at least 5%, at least 10%, at least 50%, or at least 99%.
  • the total aromatics content in the total naphtha and kerosene of feed is about 8%, about 20%, about 75%, or about 100% greater than the total aromatics content in the total naphtha and kerosene of the feed.
  • the kerosene and naphtha may have a total polyaromatic compounds content in a range from about 0.00001-0.5 grams, about 0.0001-0.2 grams, or about 0.001-0.1 grams per gram of total kerosene and naphtha.
  • the crude product has, per gram of crude product, a distillate content in a range from about 0.0001-0.9 grams, from about 0.001-0.5 grams, from about 0.005-0.3 grams, or from about 0.01-0.2 grams.
  • a weight ratio of kerosene to diesel in the distillate is in a range from about 1:4 to about 4:1, about 1:3 to about 3:1, or about 2:5 to about 5:2.
  • crude product has, per gram of crude product, at least 0.001 grams, from above 0 to about 0.7 grams, about 0.001-0.5 grams, or about 0.01-0.1 grams of kerosene. In certain embodiments, the crude product has from 0.001-0.5 grams or 0.01-0.3 grams of kerosene. In some embodiments, the kerosene has, per gram of kerosene, an aromatics content of at least 0.2 grams, at least 0.3 grams, or at least 0.4 grams. In certain embodiments, the kerosene has, per gram of kerosene, an aromatics content in a range from about 0.1-0.5 grams, or from about 0.2-0.4 grams.
  • a freezing point of the kerosene may be below -30 0 C, below -40 0 C, or below -50 0 C.
  • An increase in the content of aromatics of the kerosene portion of the crude product tends to increase the density and reduce the freezing point of the kerosene portion of the crude product.
  • a crude product with a kerosene portion having a high density and low freezing point may be refined to produce aviation turbine fuel with the desirable properties of high density and low freezing point.
  • the crude product has, per gram of crude product, a diesel content in a range from about 0.001-0.8 grams or from about 0.01-0.4 grams.
  • the diesel has, per gram of diesel, an aromatics content of at least 0.1 grams, at least 0.3 grams, or at least 0.5 grams. In some embodiments, the diesel has, per gram of diesel, an aromatics content in a range from about 0.1-1 grams, about 0.3-0.8 grams, or about 0.2-0.5 grams.
  • the crude product has, per gram of crude product, a VGO content in a range from about 0.0001-0.99 grams, from about 0.001-0.8 grams, or from about 0.1-0.3 grams.
  • the VGO content in the crude product is in a range from 0.4-0.9 grams, or about 0.6-0.8 grams per gram of crude product.
  • the VGO has, per gram of VGO, an aromatics content in a range from about 0.1-0.99 grams, about 0.3-0.8 grams, or about 0.5-0.6 grams.
  • the crude product has a residue content of at most 70%, at most 50%, at most 30%, at most 10%, or at most 1% of the feed. In certain embodiments, the crude product has, per gram of crude product, a residue content of at most 0.1 grams, at most 0.05 grams, at most 0.03 grams, at most 0.02 grams, at most 0.01 grams, at most 0.005 grams, or at most 0.001 grams. In some embodiments, the crude product has, per gram of crude product, a residue content in a range from about 0.000001-0.1 grams, about 0.00001-0.05 grams, about 0.001-0.03 grams, or about 0.005-0.04 grams.
  • the crude product may include at least a portion of the catalyst.
  • a crude product includes from greater than 0 grams, but less than 0.01 grams, about 0.000001-0.001 grams, or about 0.00001-0.0001 grams of catalyst per gram of crude product.
  • the catalyst may assist in stabilizing the crude product during transportation and/or treatment in processing facilities.
  • the catalyst may inhibit corrosion, inhibit friction, and/or increase water separation abilities of the crude product.
  • a crude product that includes at least a portion of the catalyst may be further processed to produce lubricants and/or other commercial products.
  • the catalyst used for treatment of a feed in the presence of a hydrogen source to produce the total product may be a single catalyst or a plurality of catalysts.
  • the catalysts of the application may first be a catalyst precursor that is converted to the catalyst in the contacting zone when hydrogen and/or a feed containing sulfur is contacted with the catalyst precursor.
  • the catalysts used in contacting the feed with a hydrogen source to produce the total product may assist in the reduction of the molecular weight of the feed.
  • the catalyst in combination with the hydrogen source may reduce a molecular weight of components in the feed through the action of basic (Lewis basic or Br ⁇ nsted-Lowry basic) and/or superbasic components in the catalyst.
  • basic Lewis basic or Br ⁇ nsted-Lowry basic
  • superbasic components in the catalyst examples include catalysts described herein.
  • the catalyst is an inorganic salt catalyst.
  • the anion of the inorganic salt catalyst may include an inorganic compound, an organic compound, or mixtures thereof.
  • the inorganic salt catalyst includes alkali metal carbonates, alkali metal hydroxides, alkali metal hydrides, alkali metal amides, alkali metal sulfides, alkali metal acetates, alkali metal oxalates, alkali metal formates, alkali metal pyruvates, alkaline-earth metal carbonates, alkaline-earth metal hydroxides, alkaline-earth metal hydrides, alkaline- earth metal amides, alkaline-earth metal sulfides, alkaline-earth metal acetates, alkaline- earth metal oxalates, alkaline-earth metal formates, alkaline-earth metal pyruvates, or mixtures thereof.
  • Inorganic salt catalysts include, but are not limited to, mixtures of:
  • the inorganic salt catalyst is limestone (CaCO 3 ) or dolomite (CaMg(CO 3 ) 2 ).
  • the inorganic salt catalyst is a alkaline-earth metal oxide or a combination of alkaline- metal oxidesln
  • the inorganic salt catalyst also includes alkaline-earth metal oxides andZor oxides of metals from Column 13 of the Periodic Table. Metals from Column 13 include, but are not limited to, boron or aluminum.
  • Non-limiting examples of metal oxides include lithium oxide (Li 2 O), potassium oxide (K 2 O), calcium oxide (CaO), magnesium oxide (MgO), or aluminum oxide (AI 2 O3).
  • an inorganic salt catalyst includes one or more alkali metal salts that include an alkali metal with an atomic number of at least 11.
  • An atomic ratio of an alkali metal having an atomic number of at least 11 to an alkali metal having an atomic number greater than 11, in some embodiments, is in a range from about 0.1 to about 10, about 0.2 to about 6, or about 0.3 to about 4 when the inorganic salt catalyst has two or more alkali metals.
  • the inorganic salt catalyst may include salts of sodium, potassium, and rubidium with the ratio of sodium to potassium being in a range from about 0.1-6; the ratio of sodium to rubidium being in a range from about 0.1-6; and the ratio of potassium to rubidium being in a range from about 0.1-6.
  • the inorganic salt catalyst includes a sodium salt and a potassium salt with the atomic ratio of sodium to potassium being in a range from about 0.1 to about 4.
  • an inorganic salt catalyst also includes metals from Columns
  • the inorganic salt catalyst includes about 0.1-0.5 grams, or about 0.2-0.4 grams of Raney nickel per gram of inorganic salt catalyst.
  • the inorganic salt catalyst contains at most 0.00001 grams, at most 0.001 grams, or at most 0.01 grams of lithium, calculated as the weight of lithium, per gram of inorganic salt catalyst.
  • the inorganic salt catalyst has, in some embodiments, from about 0 but less than 0.01 grams, about 0.0000001-0.001 grams, or about 0.00001- 0.0001 grams of lithium, calculated as the weight of lithium, per gram of inorganic salt catalyst.
  • the inorganic salt catalyst is, in certain embodiments, free of or substantially free of Lewis acids (for example, BCI 3 , AICI 3 , and SO 3 ), Br ⁇ nsted-Lowry acids (for example, H 3 O "1" , H 2 SO 4 , HCl, and HNO 3 ), glass-forming compositions (for example, borates and silicates), and halides.
  • Lewis acids for example, BCI 3 , AICI 3 , and SO 3
  • Br ⁇ nsted-Lowry acids for example, H 3 O "1" , H 2 SO 4 , HCl, and HNO 3
  • glass-forming compositions for example, borates and silicates
  • the inorganic salt may contain, per gram of inorganic salt catalyst: from about 0 grams to about 0.1 grams, about 0.000001-0.01 grams, or about 0.00001- 0.005 grams of: a) halides; b) compositions that form glasses at temperatures of at least 350 0 C, or at most 1000 0 C; c) Lewis acids; d) Br ⁇ nsted-Lowry acids; or e) mixtures thereof.
  • the inorganic salt catalyst may be prepared using standard techniques. For example, a desired amount of each component of the catalyst may be combined using standard mixing techniques (for example, milling and/or pulverizing).
  • inorganic compositions are dissolved in a solvent (for example, water or a suitable organic solvent) to form an inorganic composition/solvent mixture.
  • the solvent may be removed using standard separation techniques to produce the inorganic salt catalyst.
  • inorganic salts of the inorganic salt catalyst may be incorporated into a support to form a supported inorganic salt catalyst.
  • the support in some embodiments, exhibits chemical resistance to the basicity of the inorganic salt at high temperatures.
  • the support may have the ability to absorb heat (for example, have a high heat capacity).
  • the ability of the support of the inorganic salt catalyst to absorb heat may allow temperatures in the contacting zone to be reduced as compared to the temperature of the contacting zone when an unsupported inorganic salt catalyst is used.
  • supports include, but are not limited to, zirconium oxide, calcium oxide, magnesium oxide, titanium oxide, hydrotalcite, germania, iron oxide, nickel oxide, zinc oxide, cadmium oxide, antimony oxide, calcium magnesium carbonate, aluminosilicate, limestone, dolomite, activated carbon, nonvolatile charcoal, and mixtures thereof.
  • an inorganic salt, a Columns 6-10 metal, and/or a compound of a Columns 6-10 metal may be impregnated in the support.
  • the compound of a Columns 6-10 metal is a metal sulfide (for example, nickel sulfide, vanadium sulfide, molybdenum sulfide, tungsten sulfide, iron sulfide).
  • inorganic salts may be melted or softened with heat and forced in and/or onto a metal support or metal oxide support to form a supported inorganic salt catalyst.
  • a spent hydroprocessing catalyst is combined with the inorganic salt catalyst support and/or used with an inorganic salt catalyst.
  • metals and/or compounds of metals recovered from a total product/feed mixture is combined the inorganic salt catalyst support and/or used with an inorganic salt catalyst.
  • an inorganic salt catalyst is mixed with a Column 4 metal oxide.
  • Column 4 metal oxides include, but are not limited to, ZrO 2 and/or TiO 2 .
  • a molar ratio of inorganic salt catalyst to Column 4 metal oxide may range from about 0.01 to about 5, from about 0.5 to about 4, or from about 1 to about 3.
  • the supported inorganic salt catalyst is characterized using particle size.
  • the particle size of a supported inorganic salt catalyst may range from about 20 micrometers to about 500 micrometers, from about 30 micrometers to about 400 micrometers, from about 50 micrometers to about 300 micrometers, or from about 100 to 200 micrometers.
  • a structure of the inorganic salt catalyst typically becomes nonhomogenous, permeable, and/or mobile at a determined temperature or in a temperature range when loss of order occurs in the catalyst structure.
  • the inorganic salt catalyst may become disordered without a substantial change in composition (for example, without decomposition of the salt). Not to be bound by theory, it is believed that the inorganic salt catalyst becomes disordered (mobile) when distances between ions in the lattice of the inorganic salt catalyst increase. As the ionic distances increase, a feed and/or a hydrogen source may permeate through the inorganic salt catalyst instead of across the surface of the inorganic salt catalyst.
  • Permeation of the feed and/or hydrogen source through the inorganic salt often results in an increase in the contacting area between the inorganic salt catalyst and the feed and/or the hydrogen source.
  • An increase in contacting area and/or reactivity area of the inorganic salt catalyst may often increase the yield of crude product, limit production of residue and/or coke, and/or facilitate a change in properties in the crude product relative to the same properties of the feed.
  • Disorder of the inorganic salt catalyst (for example, nonhomogeneity, permeability, and/or mobility) may be determined using DSC methods, ionic conductivity measurement methods, TAP methods, visual inspection, x-ray diffraction methods, or combinations thereof. The use of TAP to determine characteristics of catalysts is described in U.S. Patent
  • a TAP system may be obtained from Mithra Technologies (Foley, Missouri, U.S.A.). The TAP analysis may be performed in a temperature range from about 25-850 0 C, about 50-500 0 C, or about 60-400 0 C, at a heating rate in a range from about 10-50 0 C, or about 20-40 0 C, and at a vacuum in a range from about 1 x 10 "13 to about 1 x 10 "8 torr.
  • the temperature may remain constant and/or increase as a function of time. As the temperature of the inorganic salt catalyst increases, gas emission from the inorganic salt catalyst is measured. Examples of gases that evolve from the inorganic salt catalyst include carbon monoxide, carbon dioxide, hydrogen, water, or mixtures thereof.
  • the temperature at which an inflection (sharp increase) in gas evolution from the inorganic salt catalyst is detected is considered to be the temperature at which the inorganic salt catalyst becomes disordered.
  • an inflection of emitted gas from the inorganic salt catalyst may be detected over a range of temperatures as determined using TAP. The temperature or the temperature range is referred to as the "TAP temperature".
  • the initial temperature of the temperature range determined using TAP is referred to as the "minimum TAP temperature".
  • the emitted gas inflection exhibited by inorganic salt catalysts suitable for contact with a feed is in a TAP temperature range from about 100-600 0 C, about 200-500 0 C, or about 300-400 0 C. Typically, the TAP temperature is in a range from about 300-500 0 C.
  • suitable inorganic salt catalysts also exhibit gas inflections, but at different TAP temperatures.
  • the magnitude of the ionization inflection associated with the emitted gas may be an indication of the order of the particles in a crystal structure.
  • ions are not associated to each other as strongly as ions in a highly ordered crystal structure. Due to the lower ion association, less energy is generally required to release ions, molecules, and/or gases from a disordered crystal structure, and thus, a quantity of ions and/or gas released from a disordered crystal structure is typically greater than a quantity of ions and/or gas released from a highly ordered crystal structure at a selected temperature.
  • a heat of dissociation of the inorganic salt catalyst may be observed in a range from about 50 0 C to about 500 0 C at a heating rate or cooling rate of about 10 0 C, as determined using a differential scanning calorimeter.
  • a sample may be heated to a first temperature, cooled to room temperature, and then heated a second time. Transitions observed during the first heating generally are representative of entrained water and/or solvent and may not be representative of the heat of dissociations. For example, easily observed heat of drying of a moist or hydrated sample may generally occur below 250 0 C, typically between 100-150 0 C. The transitions observed during the cooling cycle and the second heating correspond to the heat of dissociation of the sample.
  • Heat transition refers to the process that occurs when ordered molecules and/or atoms in a structure become disordered when the temperature increases during the DSC analysis.
  • Cool transition refers to the process that occurs when molecules and/or atoms in a structure become more homogeneous when the temperature decreases during the DSC analysis.
  • the heat/cool transition of the inorganic salt catalyst occurs over a range of temperatures that are detected using DSC.
  • the temperature or temperature range at which the heat transition of the inorganic salt catalyst occurs during a second heating cycle is referred to as "DSC temperature”.
  • the lowest DSC temperature of the temperature range during a second heating cycle is referred to as the "minimum DSC temperature”.
  • the inorganic salt catalyst may exhibit a heat transition in a range between about 200-500 0 C, about 250-450 0 C, or about 300-400 0 C.
  • a shape of the peak associated with the heat absorbed during a second heating cycle may be relatively narrow.
  • a shape of the peak associated with heat absorbed during a second heating cycle may be relatively broad.
  • Homogeneity of an inorganic mixture may be related to the ionic radius of the cations in the mixtures. For cations with smaller ionic radii, the ability of a cation to share electron density with a corresponding anion increases and the acidity of the corresponding anion increases. For a series of ions of similar charges, a smaller ionic radius results in higher interionic attractive forces between the cation and the anion if the anion is a hard base. The higher interionic attractive forces tend to result in higher heat transition temperatures for the salt and/or more homogeneous mixture of particles in the salt (sharper peak and increased area under the DSC curve).
  • Mixtures that include cations with small ionic radii tend to be more acidic than cations of larger ionic radii, and thus acidity of the inorganic salt mixture increases with decreasing cationic radii.
  • contact of a feed with a hydrogen source in the presence of an inorganic mixture that includes lithium cations tends to produce increased quantities of gas and/or coke relative to contact of the feed with a hydrogen source in the presence of an inorganic salt catalyst that includes cations with a larger ionic radii than lithium.
  • the ability to inhibit generation of gas and/or coke increases the total liquid product yield of the process.
  • the inorganic salt catalyst may include two or more inorganic salts.
  • a minimum DSC temperature for each of the inorganic salts may be determined.
  • the minimum DSC temperature of the inorganic salt catalyst may be below the minimum DSC temperature of at least one of the inorganic metal salts in the inorganic salt catalyst.
  • the inorganic salt catalyst may include potassium carbonate and cesium carbonate. Potassium carbonate and cesium carbonate exhibit DSC temperatures greater than 500 0 C.
  • a K 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst exhibits a DSC temperature in a range from about 290-300 0 C.
  • the TAP temperature may be between the DSC temperature of at least one of the inorganic salts and the DSC temperature of the inorganic salt catalyst.
  • the TAP temperature of the inorganic salt catalyst may be in a range from about 350-500 0 C.
  • the DSC temperature of the same inorganic salt catalyst may be in a range from about 200-300 0 C, and the DSC temperature of the individual salts may be at least 500 0 C or at most 1000 0 C.
  • An inorganic salt catalyst that has a TAP andZor DSC temperature between about 150-500 0 C, about 200-450 0 C, or about 300-400 0 C, and does not undergo decomposition at these temperatures, in many embodiments, can be used to catalyze conversion of high molecular weight andZor high viscosity compositions (for example, feed) to liquid products.
  • the inorganic salt catalyst may exhibit increased conductivity relative to individual inorganic salts during heating of the inorganic salt catalyst in a temperature range from about 200-600 0 C, about 300-500 0 C, or about 350- 450 0 C.
  • Increased conductivity of the inorganic salt catalyst is generally attributed to the particles in the inorganic salt catalyst becoming mobile.
  • the ionic conductivity of some inorganic salt catalysts changes at a lower temperature than the temperature at which ionic conductivity of a single component of the inorganic salt catalyst changes. Ionic conductivity of inorganic salts may be determined by applying Ohm's law: V
  • the inorganic salt catalyst may be placed in a quartz vessel with two wires (for example, copper wires or platinum wires) separated from each other, but immersed in the inorganic salt catalyst.
  • FIG. 9 is a schematic of a system that may be used to measure ionic conductivity.
  • Quartz vessel 220 containing sample 222 may be placed in a heating apparatus and heated incrementally to a desired temperature. Voltage from source 224 is applied to wire 226 during heating. The resulting current through wires 226 and 228 is measured at meter 230.
  • Meter 230 may be, but is not limited to, a multimeter or a Wheatstone bridge. As sample 222 becomes less homogeneous (more mobile) without decomposition occurring, the resistivity of the sample should decrease and the observed current at meter 230 should increase.
  • the inorganic salt catalyst may have a different ionic conductivity after heating, cooling, and then heating.
  • the difference in ionic conductivities may indicate that the crystal structure of the inorganic salt catalyst has been altered from an original shape (first form) to a different shape (second form) during heating.
  • the ionic conductivities, after heating, are expected to be similar or the same if the form of the inorganic salt catalyst does not change during heating.
  • the inorganic salt catalyst has a particle size in a range of about 10-1000 micrometers, about 20-500 micrometers, or about 50-100 micrometers, as determined by passing the inorganic salt catalyst through a mesh or a sieve.
  • the inorganic salt catalyst may soften when heated to temperatures above 50 0 C and below 500 0 C. As the inorganic salt catalyst softens, liquids and catalyst particles may co-exist in the matrix of the inorganic salt catalyst.
  • the catalyst particles may, in some embodiments, self-deform under gravity, or under a pressure of at least 0.007 MPa, or at most 0.101 MPa, when heated to a temperature of at least 300 0 C, or at most 800 0 C, such that the inorganic salt catalyst transforms from a first form to a second form.
  • the second form of the inorganic salt catalyst Upon cooling of the inorganic salt catalyst to about 20 0 C, the second form of the inorganic salt catalyst is incapable of returning to the first form of the inorganic salt catalyst.
  • the temperature at which the inorganic salt transforms from the first form to a second form is referred to as the "deformation" temperature.
  • the deformation temperature may be a temperature range or a single temperature.
  • the particles of the inorganic salt catalyst self-deform under gravity or pressure upon heating to a deformation temperature below the deformation temperature of any of the individual inorganic metal salts.
  • an inorganic salt catalyst includes two or more inorganic salts that have different deformation temperatures. The deformation temperature of the inorganic salt catalyst differs, in some embodiments, from the deformation temperatures of the individual inorganic metal salts.
  • the inorganic salt catalyst is liquid and/or semiliquid at, or above, the TAP and/or DSC temperature. In some embodiments, the inorganic salt catalyst is a liquid or a semiliquid at the minimum TAP and/or DSC temperature. At or above the minimum TAP and/or DSC temperature, liquid or semiliquid inorganic salt catalyst mixed with the feed may, in some embodiments, form a separate phase from the feed.
  • the liquid or semiliquid inorganic salt catalyst has low solubility in the feed (for example, from about 0 grams to about 0.5 grams, about 0.0000001-0.2 grams, or about 0.0001-0.1 grams of inorganic salt catalyst per gram of feed) or is insoluble in the feed (for example, from about 0 grams to about 0.05 grams, about 0.000001-0.01 grams, or about 0.00001-0.001 grams of inorganic salt catalyst per gram of feed) at the minimum TAP temperature.
  • powder x-ray diffraction methods are used to determine the spacing of the atoms in the inorganic salt catalyst.
  • a shape of the Dooi peak in the x-ray spectrum may be monitored and the relative order of the inorganic salt particles may be estimated. Peaks in the x-ray diffraction represent different compounds of the inorganic salt catalyst. In powder x-ray diffraction, the Dooi peak may be monitored and the spacing between atoms may be estimated. In an inorganic salt catalyst that contains highly ordered inorganic salt atoms, a shape of the D O oi peak is relatively narrow. In an inorganic salt catalyst (for example, a K 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst) that contains randomly ordered inorganic salt atoms, the shape of the D O oi peak may be relatively broad or the D O oi peak may be absent.
  • an x-ray diffraction spectrum of the inorganic salt catalyst may be taken before heating and compared with an x-ray diffraction spectrum taken after heating.
  • the D O oi peak (corresponding to the inorganic salt atoms) in the x-ray diffraction spectrum taken at temperatures above 50 0 C may be absent or broader than the D O oi peaks in the x-ray diffraction spectrum taken at temperatures below 50 0 C.
  • the x-ray diffraction pattern of the individual inorganic salt may exhibit relatively narrow D O oi peaks at the same temperatures.
  • Contacting conditions may be controlled such that the total product composition (and thus, the crude product) may be varied for a given feed in addition to limiting andZor inhibiting formation of by-products.
  • the total product composition includes, but is not limited to, paraffins, olefins, aromatics, or mixtures thereof. These compounds make up the compositions of the crude product and the non-condensable hydrocarbon gases.
  • Controlling contacting conditions in combination with the catalyst described herein may produce a total product with lower than predicted coke content.
  • Comparison of the MCR content of various crudes may allow crudes to be ranked based on their tendency to form coke. For example, a crude with a MCR content of about 0.1 grams of MCR per gram of crude would be expected to form more coke than a crude with a MCR content of about 0.001 grams of MCR per gram of crude.
  • Disadvantaged crudes typically have MCR contents of at least 0.05 grams of MCR per gram of disadvantaged crude.
  • the residue content and/or coke content deposited on the catalyst during a reaction period may be at most 0.2 grams, at most 0.1 grams, at most 0.05 grams, or at most 0.03 grams of residue and/or coke per gram of catalyst.
  • the weight of residue and/or coke deposited on the catalyst is in a range from about 0.0001-0.1 grams, 0.001-0.05 grams, or about 0.01-0.03 grams.
  • used catalyst is substantially free of residue and/or coke.
  • contacting conditions are controlled such that at most 0.2 grams, at most 0.1 grams, at most 0.05 grams, at most 0.015 grams, at most 0.01 grams, at most 0.005 grams, or at most 0.003 grams of coke is formed per gram of crude product.
  • Contacting a feed with the catalyst under controlled contacting conditions produces a reduced quantity of coke and/or residue relative to a quantity of coke and/or residue produced by heating the feed in the presence of a refining catalyst, or in the absence of a catalyst, using the same contacting conditions.
  • the contacting conditions may be controlled, in some embodiments, such that, per gram of feed, at least 0.5 grams, at least 0.7 grams, at least 0.8 grams, or at least 0.9 grams of the feed is converted to the crude product. Typically, between about 0.5-0.99 grams, about 0.6-0.9 grams, or about 0.7-0.8 grams of the crude product per gram of feed is produced during contacting. Conversion of the feed to a crude product with a minimal yield of residue and/or coke, if any, in the crude product allows the crude product to be converted to commercial products with a minimal amount of pre-treatment at a refinery.
  • per gram of feed at most 0.2 grams, at most 0.1 grams, at most 0.05 grams, at most 0.03 grams, or at most 0.01 grams of the feed is converted to non- condensable hydrocarbons. In some embodiments, from about 0 to about 0.2 grams, about 0.0001-0.1 grams, about 0.001-0.05 grams, or about 0.01-0.03 grams of non-condensable hydrocarbons per gram of feed is produced.
  • Controlling a contacting zone temperature, rate of feed flow, rate of total product flow, rate and/or amount of catalyst feed, rate of steam flow, or combinations thereof, may be performed to maintain desired reaction temperatures.
  • control of the temperature in the contacting zone may be performed by changing a flow of a gaseous hydrogen source and/or inert gas through the contacting zone to dilute the amount of hydrogen and/or remove excess heat from the contacting zone.
  • the temperature in the contacting zone may be controlled such that a temperature in the contacting zone is at, above, or below desired temperature "Ti".
  • the contacting temperature is controlled such that the contacting zone temperature is below the minimum TAP temperature and/or the minimum DSC temperature.
  • Ti may be about 30 0 C below, about 20 0 C below, or about 10 0 C below the minimum TAP temperature and/or the minimum DSC temperature.
  • the contacting temperature may be controlled to be about 370 0 C, about 380 0 C, or about 390 0 C during the reaction period when the minimum TAP temperature and/or minimum DSC temperature is about 400 0 C.
  • the contacting temperature is controlled such that the temperature is at, or above, the catalyst TAP temperature and/or the catalyst DSC temperature.
  • the contacting temperature may be controlled to be about 450 0 C, about 500 0 C, or about 550 0 C during the reaction period when the minimum TAP temperature and/or minimum DSC temperature is about 450 0 C.
  • Controlling the contacting temperature based on catalyst TAP temperatures and/or catalyst DSC temperatures may yield improved crude product properties. Such control may, for example, decrease coke formation, decrease non-condensable gas formation, or combinations thereof.
  • the inorganic salt catalyst may be conditioned prior to addition of the feed. In some embodiments, the conditioning may take place in the presence of the feed. Conditioning the inorganic salt catalyst may include heating the inorganic salt catalyst to a first temperature of at least 100 0 C, at least 300 0 C, at least 400 0 C, or at least 500 0 C, and then cooling the inorganic salt catalyst to a second temperature of at most 250 0 C, at most 200 0 C, or at most 100 0 C.
  • the inorganic salt catalyst is heated to a temperature in a range from about 150-700 0 C, about 200-600 0 C, or about 300-500 0 C, and then cooled to a second temperature in a range from about 25-240 0 C, about 30-200 0 C, or about 50-90 0 C.
  • the conditioning temperatures may be determined by determining ionic conductivity measurements at different temperatures.
  • conditioning temperatures may be determined from DSC temperatures obtained from heat/cool transitions obtained by heating and cooling the inorganic salt catalyst multiple times in a DSC. Conditioning of the inorganic salt catalyst may allow contact of a feed to be performed at lower reaction temperatures than temperatures used with conventional hydroprocessing catalysts.
  • varying a ratio of catalyst to feed may affect the amount of gas, crude product, and/or coke formed during contacting.
  • a ratio supported inorganic catalyst to feed may range from 2-10 or be greater than 10.
  • the conversion of feed to total product may be at least 50%, at least 60%, at least 80%, at least 90%, at least 99%.
  • the content of gas in the total product may range be, per gram of feed, at least 0.1 grams, at least 0.5 grams, at least 0.7 grams, at least 0.9 grams or at least 0.95 grams.
  • the content of produced product may range, per gram of feed, from about 0.1 grams to 0.99 grams, 0.3 grams to 0.9 grams, or from about 0.5 gram to about 0.7 grams.
  • the content crude product in the total product may range be, per gram of feed, at least 0.1 grams, at least 0.5 grams, at least 0.7 grams, at least 0.9 grams or at least 0.95 grams.
  • the content of produced crude product may range, per gram of feed, from about 0.1 grams to 0.99 grams, 0.3 grams to 0.9 grams, or from about 0.5 gram to about 0.7 grams. At most, per gram of feed, 0.2 grams, at most 0.1 grams, at most 0.05 grams of coke may be formed.
  • a content of naphtha, distillate, VGO, or mixtures thereof, in the total product may be varied by changing a rate of total product removal from a contacting zone. For example, decreasing a rate of total product removal tends to increase contacting time of the feed with the catalyst. Alternately, increasing pressure relative to an initial pressure may increase contacting time, may increase a yield of a crude product, may increase incorporation of hydrogen from the gases into a crude product for a given mass flow rate of feed or hydrogen source, or may alter combinations of these effects.
  • Increased contacting times of the feed with the catalyst may produce an increased amount of diesel, kerosene, or naphtha and a decreased amount of VGO relative to the amounts of diesel, kerosene, naphtha, and VGO produced at shorter contacting times.
  • Increasing the contacting time of the total product in the contacting zone may also change the average carbon number of the crude product. Increased contacting time may result in a higher weight percentage of lower carbon numbers (and thus, a higher API gravity).
  • the contacting conditions may be changed over time. For example, the contacting pressure and/or the contacting temperature may be increased to increase the amount of hydrogen that the feed uptakes to produce the crude product.
  • the ability to change the amount of hydrogen uptake of the feed, while improving other properties of the feed increases the types of crude products that may be produced from a single feed. The ability to produce multiple crude products from a single feed may allow different transportation and/or treatment specifications to be satisfied.
  • H/C of the crude product An increase in the atomic H/C of the crude product relative to the atomic H/C of the feed indicates incorporation of hydrogen into the crude product from the hydrogen source. Relatively low increase in the atomic H/C of the crude product (about 20%, as compared to the feed) indicates relatively low consumption of hydrogen gas during the process. Significant improvement of the crude product properties, relative to those of the feed, obtained with minimal consumption of hydrogen is desirable.
  • the amount of steam may be varied.
  • more steam may be added to the contacting zone.
  • a weight ratio of steam to feed may range from 0.001 to 100 from 0.01 to 10, from 0.05 to 5, or from 1 to 3 depending on the properties of the feed.
  • a steam to feed ratio may be at least 0.001, at least 0.01, at least 0.02, or at least 1.
  • a steam to feed ratio may be at least 1, at least 2, at least 3, at least 5 or at least 10. Varying the amount of steam also changes the ratio of carbon monoxide to carbon dioxide.
  • the ratio of carbon monoxide to carbon dioxide in the produced gas may be varied from 0.01 to 10, or from 0.02 to 6, or from 0.03 to 5, or from 1 to 4 by altering the weight ratio of steam to feed in the contacting zone. For example, by increasing the ratio of steam to feed in the contacting zone the ratio of carbon monoxide to carbon dioxide is decreased.
  • the ratio of hydrogen source to feed may also be altered to alter the properties of the crude product. For example, increasing the ratio of the hydrogen source to feed may result in crude product that has an increased VGO content per gram of crude product.
  • the feed may include significant amounts of sulfur as described herein which may be converted to hydrogen sulfide during contacting of the feed using systems, method and/or catalysts described herein.
  • the feed may also include entrained hydrogen sulfide gas prior to contacting.
  • Sulfur, present as organosulfur or hydrogen sulfide is known to poison and/or reduce the activity of catalysts used in processing of feeds to make commercial products.
  • feeds are treated to remove sulfur prior to treatment to obtain commercial products such as transportation fuel, thus a sulfur resistant catalyst are desirable.
  • contact of the feed with a hydrogen source in the presence of the inorganic salt catalyst and a sulfur-containing compound may produce a total product that includes a crude product and/or gas.
  • the feed in some embodiments, is contacted in the presence of hydrogen sulfide for at least 500 hours, at least 1000 hours, or at least 2000 hours without replacement of the inorganic salt catalyst.
  • the presence of sulfur in some embodiments, may enhance the production of carbon oxide gases (for example, carbon monoxide and carbon dioxide) when a feed is contacted with a hydrogen source and steam in the presence of sulfur containing compounds relative to contacting under the same conditions in the absence of sulfur.
  • contact of the feed with a hydrogen source in the presence of the inorganic salt catalyst and hydrogen sulfide produces a total product that has a carbon oxide gases content, per gram of feed, of at least 0.2 grams, at least 0.5 grams, at least 0.8 grams, or at least 0.9 grams of carbon oxide gases.
  • contact of the feed with the inorganic salt catalyst in the presence of light hydrocarbons and/or steam yields more liquid hydrocarbons and less coke in a crude product than contact of a feed with an inorganic salt catalyst in the presence of hydrogen and steam.
  • at least a portion of the components of the crude product may include atomic carbon and hydrogen (from the methane), which has been incorporated into the molecular structures of the components.
  • the volume of crude product produced from a feed contacted with the hydrogen source in the presence of the inorganic salt catalyst is at least 5% greater, at least 10% greater, or at least 15%, or at most 100% greater than a volume of crude product produced from a thermal process at STP.
  • the total volume of crude product produced by contact of the feed with the inorganic salt catalyst may be at least 110 vol% of the volume of the feed at STP.
  • the increase in volume is believed to be due to a decrease in density. Lower density may generally be at least partially caused by hydrogenation of the feed.
  • a feed having, per gram of feed, at least 0.02 grams, at least 0.05 grams, or at least 0.1 grams of sulfur, and/or at least 0.001 grams of Ni/V/Fe is contacted with a hydrogen source in the presence of an inorganic salt catalyst without diminishing the activity of the catalyst.
  • the inorganic salt catalyst can be regenerated, at least partially, by removal of one or more components that contaminate the catalyst. Contaminants include, but are not limited to, metals, sulfides, nitrogen, coke, or mixtures thereof. Sulfide contaminants may be removed from the used inorganic salt catalyst by contacting steam and carbon dioxide with the used catalyst to produce hydrogen sulfide.
  • Nitrogen contaminants may be removed by contacting the used inorganic salt catalyst with steam to produce ammonia.
  • Coke contaminants may be removed from the used inorganic salt catalyst by contacting the used inorganic salt catalyst with steam and/or methane to produce hydrogen and carbon oxides.
  • one or more gases are generated from a mixture of used inorganic salt catalyst and residual feed.
  • a mixture of used inorganic salt catalyst for example, a supported inorganic salt catalyst, a mixture Of ZrO 2 and CaO, a mixture Of ZrO 2 and MgO, K 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 ; KOHZAl 2 O 3 ; Cs 2 CO 3 ZCaCO 3 ; Or NaOHZKOHZLiOHZZrO 2
  • unreacted feed andZor residue andZor coke may be heated to a temperature in a range from about 700-1000 0 C or from about 800-900 0 C until the production of gas andZor liquids is minimal in the presence of steam, hydrogen, carbon dioxide, andZor light hydrocarbons to produce a liquid phase andZor gas.
  • the gas may include an increased quantity of hydrogen andZor carbon dioxide relative to reactive gas.
  • the gas may include from about 0.1-99 moles or from about 0.2-8 moles of hydrogen andZor carbon dioxide per mole of reactive gas.
  • the gas may contain a relatively low amount of light hydrocarbons and/or carbon monoxide. For example, less than about 0.05 grams of light hydrocarbons per gram of gas and less than about 0.01 grams of carbon monoxide per gram of gas.
  • the liquid phase may contain water, for example, greater than 0.5-0.99 grams, or greater than 0.9-0.9 grams of water per gram of liquid.
  • the used catalyst and/or solids in the contacting zone may be treated to recover metals (for example, vanadium and/or nickel) from the used catalyst and/or solids.
  • the used catalyst and/or solids may be treated using generally known metal separation techniques, for example, heating, chemical treating, and/or gasification.
  • Non-limiting examples of catalyst preparations, testing of catalysts, and systems with controlled contacting conditions are set forth below.
  • Example 1 TAP Testing of a K?.CO ⁇ /Rb?.CO.VCs?.CO ⁇ Catalyst and the Individual Inorganic Salts.
  • a 300 mg sample was heated in a reactor of a TAP system from room temperature (about 27 0 C) to 500 0 C at a rate of about 50 0 C per minute. Emitted water vapor and carbon dioxide gas were monitored using a mass spectrometer of the TAP system.
  • the K 2 CO 3 /Rb 2 CO 3 /Cs 2 CO 3 catalyst supported on alumina showed a current inflection of greater than 0.2 volts for emitted carbon dioxide and a current inflection of 0.01 volts for emitted water from the inorganic salt catalyst at about 360 0 C.
  • the minimum TAP temperature was about 360 0 C, as determined by plotting the log 10 of the ion current versus temperature.
  • FIG. 10 is a graphical representation of log 10 plots of ion current of emitted gases from the K 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst ("log (I)") versus temperature ("T").
  • Curves 232 and 234 are log 10 values for the ion currents for emitted water and CO 2 from the inorganic salt catalyst. Sharp inflections for emitted water and CO 2 from the inorganic salt catalyst occurs at about 360 0 C.
  • potassium carbonate and cesium carbonate had non-detectable current inflections at 360 0 C for both emitted water and carbon dioxide.
  • the substantial increase in emitted gas for the K 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst demonstrates that inorganic salt catalysts composed of two or more different inorganic salts may be more disordered than the individual pure carbonate salts.
  • a 10 mg sample was heated to 520 0 C at a rate of 10 0 C per min, cooled from 520 0 C to 0.0 0 C at rate of 10 0 C per minute, and then heated from 0 0 C to 600 0 C at a rate of 10.0 0 C per min using a differential scanning calorimeter (DSC) Model DSC-7, manufactured by Perkin-Elmer (Norwalk, Connecticut, U.S.A.).
  • DSC differential scanning calorimeter
  • FIG. 11 is a graphical representation of log plots of the sample resistance relative to potassium carbonate resistance ("log (rK 2 CO 3 )") versus temperature ("T").
  • Curves 240, 242, 244, 246, and 248 are log plots of K 2 CO 3 resistance, CaO resistance, K 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst resistance, Li 2 CO 3 ZK 2 CO 3 ZRb 2 CO 3 ZCs2CO 3 catalyst resistance, and Na 2 CO 3 ZK 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst resistance, respectively.
  • CaO (curve 242) exhibits relatively large stable resistance relative to K 2 CO 3 (curve 240) at temperatures in a range between 380-500 0 C.
  • a stable resistance indicates an ordered structure and/or ions that tend not to move apart from one another during heating.
  • the K 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst, Li 2 CO 3 ZK 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst, and Na 2 CO 3 ZK 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst show a sharp decrease in resistivity relative to K 2 CO 3 at temperatures in a range from 350-500 0 C.
  • a decrease in resistivity generally indicates that current flow was detected during application of voltage to the wires embedded in the inorganic salt catalyst.
  • the data from FIG. 11 demonstrate that the inorganic salt catalysts are generally more mobile than the pure inorganic salts at temperatures in a range from 350-600 0 C.
  • FIG. 12 is a graphical representation of log plots of
  • Curve 250 is a plot of a ratio of Na 2 CO 3 ZK 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst resistance relative to K 2 CO 3 resistance (curve 240) versus temperature during heating of the Na 2 CO 3 ZK 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst. After heating, the Na 2 CO 3 ZK 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst was cooled to room temperature and then heated in the conductivity apparatus.
  • Curve 252 is a log plot of Na 2 CO 3 ZK 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst resistance relative to K 2 CO 3 resistance versus temperature during heating of the inorganic salt catalyst after being cooled from 600 0 C to 25 0 C.
  • the ionic conductivity of the reheated Na 2 CO 3 ZK 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst increased relative to the ionic conductivity of the original Na 2 CO 3 ZK 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst.
  • the inorganic salt catalyst forms a different form (a second form) upon cooling that is not the same as the form (a first form) before any heating.
  • Example 4 Flow Property Testing of an Inorganic Salt Catalyst.
  • a 1-2 cm thick layer of powdered K 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst was placed in a quartz dish.
  • the dish was placed in a furnace and heated to 500 0 C for about 1 hour.
  • To determine flow properties of the catalyst the dish was manually tilted in the oven after heating. The
  • K 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst did not flow.
  • the catalyst When pressed with a spatula, the catalyst had a consistency of taffy.
  • the individual carbonate salts were free flowing powders under the same conditions.
  • a Na 2 CO 3 ZK 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst became liquid and readily flowed (similar, for example, to water) in the dish under the same conditions.
  • Examples 5 and 6 Contact of a Feed with a Hydro2en Source in the Presence of a K 2 CO ⁇ /Rb2CO.VCs2CO ⁇ Catalyst and Steam. The following equipment and general procedure was used in Examples 5-23 except where variations are described.
  • a 250 mL Hastelloy C Parr Autoclave (Parr Model #4576) rated at 35 MPa working pressure (5000 psi) at 500 0 C, was fitted with a mechanical stirrer and an 800 watt Gaumer band heater on a Eurotherm controller capable of maintaining the autoclave at + 5 0 C from ambient to 625 0 C, a gas inlet port, a steam inlet port, one outlet port, and a thermocouple to register internal temperature. Prior to heating, the top of the autoclave was insulated with glass cloth.
  • Addition Vessel An addition vessel (a 250 mL, 316 stainless steel hoke vessel) was equipped with a controlled heating system, suitable gas control valving, a pressure relief device, thermocouples, a pressure gauge, and a high temperature control valve (Swagelok Valve # SS-4UW) capable of regulating flow of a hot, viscous, andZor pressurized feed at a flow rate from 0-500 gZmin. An outlet side of the high temperature control valve was attached to the first inlet port of the reactor after feed was charged to the addition vessel. Prior to use, the addition vessel line was insulated.
  • the gas stream was collected in a gas bag (a Tedlar gas collection bag) for analysis.
  • the gas was analyzed using GCZMS (Hewlett-Packard Model 5890, now Agilent Model 5890; manufactured by Agilent Technologies, Zion Illinois, U.S.A.).
  • the liquid condensate stream was removed from the cold traps and weighed. Crude product and water were separated from the liquid condensate stream. The crude product was weighed and analyzed.
  • the feed had, per gram of feed, a sulfur content of 0.042 grams, a nitrogen content of 0.011 grams, and a total Ni/V content of 0.009 grams.
  • the feed was heated to 150 0 C.
  • the K 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst (31.39 grams) was charged to the reactor.
  • the K 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst was prepared by combining of 16.44 grams of K 2 CO 3 , 19.44 grams of Rb 2 CO 3 , and 24.49 grams of Cs 2 CO 3 .
  • the K 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst had a minimum TAP temperature of 360 0 C.
  • the K 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst had a DSC temperature of 250 0 C.
  • the individual salts (K 2 CO 3 , Rb 2 CO 3 , and Cs 2 CO 3 ) did not exhibit DSC temperatures in a range from 50-500 0 C. This TAP temperature is above the DSC temperature of the inorganic salt catalyst and below the DSC temperature of the individual metal carbonates.
  • the catalyst was heated rapidly to 450 0 C under an atmospheric pressure flow of methane of 250 cm 3 Zmin. After reaching the desired reaction temperature, steam at a rate of 0.4 mLZmin, and methane at rate of 250 cm 3 Zmin, was metered to the reactor. The steam and methane were continuously metered during the addition of the feed to the reactor over about 2.6 hours.
  • the feed was pressurized into the reactor using 1.5 MPa (229 psi) of CH 4 over 16 minutes. Residual feed (0.56 grams) remained in the addition vessel after the addition of the feed was complete. A decrease in temperature to 370 0 C was observed during the addition of the feed.
  • the catalyst/feed mixture was heated to a reaction temperature of 450 0 C and maintained at that temperature for about 2 hours. After two hours, the reactor was cooled and the resulting residueZcatalyst mixture was weighed to determine a percentage of coke produced andZor not consumed in the reaction. From a difference in initial catalyst weight and cokeZcatalyst mixture weight, 0.046 grams of coke remained in the reactor per gram of feed.
  • the total product included 0.87 grams of a crude product with an average API gravity of 13 and gas.
  • the gas included unreacted CH 4 , hydrogen, C 2 and C 4 -C 6 hydrocarbons, and CO 2 (0.08 grams of CO 2 per gram of gas).
  • the crude product had, per gram of crude product, 0.01 grams of sulfur and
  • Example 6 the reaction procedures, conditions, feed, and catalyst were the same as in Example 5.
  • the crude product of Example 6 was analyzed to determine boiling range distributions for the crude product.
  • the crude product had, per gram of crude product, 0.14 grams of naphtha, 0.19 grams of distillate, 0.45 grams of VGO, and residue content of 0.001 grams, and non-detectable amounts of coke.
  • Examples 5 and 6 demonstrate that contact of the feed with a hydrogen source in the presence of at most 3 grams of catalyst per 100 grams of feed produces a total product that includes a crude product that is a liquid mixture at STP.
  • the crude product had a residue content of at most 30% of the residue content of the feed.
  • the crude product had a sulfur content and total Ni/V content of at most 90% of the sulfur content and Ni/V content of the feed.
  • the crude product included at least 0.001 grams of hydrocarbons with a boiling range distribution of at most 200 0 C at 0.101 MPa, at least 0.001 grams of hydrocarbons with a boiling range distribution between 200-300 0 C at 0.101 MPa, at least 0.001 grams of hydrocarbons with a boiling range distribution between 400-538 0 C (1000 0 F) at 0.101 MPa.
  • Examples 7-8 Contact of a Feed with a Hydrogen Source in the Presence of the
  • Example 7 methane was used as the hydrogen source.
  • Example 8 hydrogen gas was used as the hydrogen source.
  • a graphical representation of the amounts of non-condensable gas, crude product, and coke is depicted in FIG. 13.
  • Bars 254 and 256 represent wt% coke produced
  • bars 258 and 260 represent wt% liquid hydrocarbons produced
  • bars 262 and 264 represent wt% gas produced, based on the weight of the feed.
  • Example 8 84 wt% of crude product (bar 258), 7 wt% of gas (bar 262), and 9 wt% of coke were produced (bar 254), based on the weight of the Cerro Negro.
  • Examples 7 and 8 provide a comparison of the use of methane as a hydrogen source to the use of hydrogen gas as a hydrogen source.
  • Methane is generally less expensive to produce andZor transport than hydrogen, thus a process that utilizes methane is desirable.
  • methane is at least as effective as hydrogen gas as a hydrogen source when contacting a feed in the presence of an inorganic salt catalyst to produce a total product.
  • Examples 9-10 Producing a Crude Product with Selected API Gravity.
  • the apparatus, reaction procedure and the inorganic salt catalyst were the same as in Example 5, except that the reactor pressure was varied.
  • Example 9 the reactor pressure was 0.1 MPa (14.7 psi) during the contacting period. A crude product with API gravity of 25 at 15.5 0 C was produced. The total product had hydrocarbons with a distribution of carbon numbers in a range from 5 to 32
  • Example 10 the reactor pressure was 3.4 MPa (514.7 psi) during the contacting period. A crude product with API gravity of 51.6 at 15.5 0 C was produced. The total product had hydrocarbons with a distribution of carbon numbers in a range from 5 to 15
  • Examples 11-12 Contact of a Feed in the Presence of a KaCOVRbaCOVCsaCOa
  • Example 5 except that the feed and catalyst (or silicon carbide) were directly charged into the reactor at the same time. Carbon dioxide (CO 2 ) was used as a carrier gas.
  • CO 2 Carbon dioxide
  • Example 12 K 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst (same catalyst as in Example 5).
  • 132 g of Cerro Negro was combined with 83.13 grams of silicon carbide (40 mesh, Stanford
  • Such silicon carbide is believed to have low, if any, catalytic properties under the process conditions described herein.
  • Example 11 36.82 grams (26.68 wt%, based on the weight of the feed) of a colorless hydrocarbon liquid with API gravity of at least 50 was produced from contact of the feed with the inorganic salt catalyst in the carbon dioxide atmosphere.
  • Example 12 15.78 grams (11.95 wt%, based on the weight of the feed) of a yellow hydrocarbon liquid with an API gravity of 12 was produced from contact of the feed with silicon carbide in the carbon dioxide atmosphere.
  • Example 11 Although the yield in Example 11 is low, the in-situ generation of a hydrogen source in the presence of the inorganic salt catalyst is greater than the in-situ generation of hydrogen under non-catalytic conditions.
  • the yield of crude product in Example 12 is one- half of the yield of crude product in Example 11.
  • Example 11 also demonstrates that hydrogen is generated during contact of the feed in the presence of the inorganic salt and in the absence of a gaseous hydrogen source.
  • Examples 13-16 Contact of a Feed with a Hydro2en Source in the Presence of K?COi/Rb?COi/Cs?COi Catalyst, Calcium Carbonate, and Silicon Carbide at Atmospheric Conditions.
  • the apparatus, reaction procedure, feed and the inorganic salt catalyst were the same as in Example 5, except that the Cerro Negro was added directly to the reactor instead of addition through the addition vessel and hydrogen gas was used as the hydrogen source.
  • the reactor pressure was 0.101 MPa (14.7 psi) during the contacting period.
  • the hydrogen gas flow rate was 250 cm 3 /min. Reaction temperatures, steam flow rates, and percentages of crude product, gas, and coke produced are tabulated in Table 1 in FIG. 15.
  • Example 13 the K 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst was used.
  • the contacting temperature was 375 0 C.
  • the contacting temperature was in a temperature range from 500-600 0 C.
  • Table 1 shown in Table 1 (FIG. 15)
  • Coke production however, decreased from 0.17 grams to 0.09 grams of coke per gram of feed at the higher temperature.
  • the sulfur content of the crude product also decreased from 0.01 grams to 0.008 grams of sulfur per gram of crude product at the higher temperature. Both crude products had atomic HZC of 1.8.
  • Example 15 a feed was contacted with CaCO 3 under conditions similar to the conditions described for Example 14. Percentages of crude product, gas, and coke production are tabulated in Table 1 in FIG. 13. Gas production increased in Example 15 relative to the gas production in Example 14. Desulfurization of the feed was not as effective as in Example 14. The crude product produced in Example 15 had, per gram of crude product, 0.01 grams of sulfur as compared to the sulfur content of 0.008 grams per gram of crude product for the crude product produced in Example 14.
  • Example 16 is a comparative example for Example 14. In Example 16, 83.13 grams of silicon carbide instead of the inorganic salt catalyst was charged to the reactor. Gas production and coke production significantly increased in Example 16 relative to the gas production and coke production in Example 14.
  • Example 16 Under these non-catalytic conditions, 0.22 grams of coke per gram of crude product, 0.25 grams of non-condensable gas, and 0.5 grams of crude product were produced.
  • the crude product produced in Example 16 had 0.036 grams of sulfur per gram of crude product, compared to of 0.01 grams of sulfur per gram of crude product produced in Example 14.
  • Example 17 Apparatus in Examples 17 and 18 were the same as in Example 5 except that hydrogen gas was used as the hydrogen source.
  • Example 17 130.4 grams of Cerro Negro was combined with 30.88 grams of the K 2 C(VRb 2 C(VCs 2 CCb catalyst to form a feed mixture.
  • Example 18 139.6 grams of Cerro Negro was combined with 80.14 grams of silicon carbide to form the feed mixture.
  • the feed mixture was charged directly into the reactor.
  • the hydrogen gas was metered at 250 cm 3 /min into the reactor during the heating and holding periods.
  • the feed mixture was heated to 300 0 C over about 1.5 hours and maintained at 300 0 C for about 1 hour.
  • the reaction temperature was increased to 400 0 C over about 1 hour and maintained at 400 0 C for about 1 hour.
  • water was introduced into the reactor at a rate of 0.4 g/min in combination with the hydrogen gas. Water and hydrogen were metered into the reactor for the remaining heating and holding periods.
  • the reaction temperature was increased to 500 0 C and maintained at 500 0 C for about 2 hours.
  • Generated vapor from the reactor was collected in the cold traps and a gas bag. Liquid product from the cold traps was consolidated and analyzed.
  • Example 17 86.17 grams (66.1 wt%, based on the weight of the feed) of a dark reddish brown hydrocarbon liquid (crude product) and water (97.5 g) were produced as a vapor from contact of the feed with the K 2 C ⁇ 3 /Rb 2 C ⁇ 3 /Cs 2 C ⁇ 3 catalyst in the hydrogen atmosphere.
  • Example 18 water vapor and a small amount of gas was produced from the reactor. The reactor was inspected, and a dark brown viscous hydrocarbon liquid was removed from the reactor. Less than 50 wt% of the dark brown viscous liquid was produced from contact of the feed with silicon carbide in the hydrogen atmosphere. A 25% increase in yield of crude product was observed in Example 17 relative to a yield of crude product produced in Example 18.
  • Example 17 demonstrates an improvement of the properties of the crude product produced using methods described herein relative to a crude product produced using hot water. Specifically, the crude product in Example 17 was lower boiling than the crude product from Example 18, as demonstrated by the crude product produced in Example 18 not being able to be produced as a vapor. The crude product produced in Example 17 had enhanced flow properties relative to the crude product produced in Example 18, as determined by visual inspection.
  • Examples 19- 20 Contact of a Feed with a Hydrogen Source in the Presence of a Ko.CO ⁇ /Rbo.CO.VCso.CO ⁇ Catalyst to Produce a Crude Product with Increased Volume Relative to a Crude Product Volume Produced under Non-Catalytic Conditions.
  • the apparatus, feed, inorganic catalyst, and reaction procedure was the same as described in Example 5, except the feed was directly charged to the reactor and hydrogen gas was used as the hydrogen source.
  • the feed (Cerro Negro) had an API gravity 6.7 and a density of 1.02 g/mL at 15.5 0 C.
  • Example 19 102 grams of the feed (about 100 mL of feed) and 31 grams of K 2 C(VRb 2 C(VCs 2 CCb catalyst were charged to the reactor. A crude product (87.6 grams) with an API gravity of 50 and a density of 0.7796 g/mL at 15.5 0 C (112 mL) was produced. In Example 20, 102 grams of feed (about 100 mL of feed) and 80 grams of silicon carbide were charged to the reactor. A crude product (70 grams) of with an API gravity of 12 and a density of 0.9861 g/mL at 15.5 0 C (about 70 mL) was produced.
  • Example 21 Contact of a Feed with a Hydro2en Source in the Presence of a The apparatus and reaction procedure were the same as in Example 5, except that the steam was metered into the reactor at 300 cm 3 /min.
  • the K 2 CO 3 /Rb 2 CO 3 /Cs 2 CO 3 catalyst was prepared by combining 27.2 grams of K 2 CO 3 , 32.2 grams of Rb 2 CO 3 and 40.6 grams of Cs 2 CO 3 .
  • the feed (130.35 grams) and K 2 CO 3 /Rb 2 CO 3 /Cs 2 CO 3 catalyst (31.6 grams) was charged to the reactor.
  • the Cerro Negro crude included, per gram of feed, 0.04 grams total aromatics content in a boiling range distribution between 149-260 0 C (300-500 0 F),
  • the crude product was analyzed using a combination of gas chromatography and mass spectrometry.
  • the crude product included a mixture of hydrocarbons with a boiling range between 100-538 0 C.
  • the total liquid product mixture included 0.006 grams ethyl benzene (a monocyclic ring compound with a boiling point of 136.2 0 C at 0.101 MPa) per gram of mixture. This product was not detected in the feed.
  • the used catalyst (“first used catalyst”) was removed from the reactor, weighed, and then analyzed.
  • the first used catalyst had an increase in weight from 31.6 grams to a total weight of 37.38 grams (an increase of 18 wt%, based on the weight of the original K 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst).
  • the first used catalyst included 0.15 grams of additional coke, 0.0035 grams of sulfur, 0.0014 grams of NiZV, and 0.845 grams of K 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 per gram of used catalyst.
  • Additional feed (152.71 grams) was contacted with the first used catalyst (36.63 grams) to produce 150 grams of recovered total product after losses.
  • the total product included, per gram of total product, 0.92 grams of liquid crude product, 0.058 grams of additional coke, and 0.017 grams of gas.
  • the gas included, per mole of gas, 0.18 moles of hydrogen, 0.07 grams of carbon dioxide, and 0.035 moles of C 2 -C 6 hydrocarbons.
  • the balance of the gas was methane, nitrogen, some air, and traces of evaporated oil product ( ⁇ 1% mole).
  • the crude product included a mixture of hydrocarbons with a boiling range between 100-538 0 C.
  • the portion of the mixture with a boiling range distribution below 149 0 C included, per mole of total liquid hydrocarbons, 0.018 mole% of ethyl benzene, 0.04 mole% of toluene, 0.03 mole% of meta- xylene, and 0.060 mole% of para- xylene (monocyclic ring compounds with a boiling points below 149 0 C at 0.101 MPa). These products were not detectable in the feed.
  • the used catalyst (“second used catalyst”) was removed from the reactor, weighed, and then analyzed.
  • the second used catalyst had an increase in weight from 36.63 grams to a total weight of 45.44 grams (an increase of 43 wt%, based on the weight of the original K 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst).
  • the second used catalyst included 0.32 grams of coke, and 0.01 grams of sulfur, and 0.67 grams per gram of second used catalyst.
  • the total product included, per gram of total product, 0.86 grams of crude product and 0.025 grams of hydrocarbon gas.
  • the crude product included a mixture of hydrocarbons with a boiling range between 100-538 0 C.
  • the portion of the mixture with a boiling range distribution below 149 0 C included, per gram of hydrocarbon mixture, 0.021 grams ethyl benzene, 0.027 grams of toluene, 0.042 grams of meta- xylene, and 0.020 grams of para- xylene, determined as before by GC/MS.
  • the used catalyst (“third used catalyst”) was removed from the reactor, weighed, and then analyzed.
  • the third used catalyst had an increase in weight from 44.84 grams to a total weight of 56.59 grams (an increase of 79 wt%, based on the weight of the original K 2 CO 3 ZRb 2 CO 3 ZCs 2 CO 3 catalyst).
  • Detailed elemental analysis of the third used catalyst was performed.
  • the third used catalyst included, per gram of additional matter, 0.90 grams of carbon, 0.028 grams of hydrogen, 0.0025 grams of oxygen, 0.046 grams of sulfur, 0.017 grams of nitrogen, 0.0018 grams of vanadium, 0.0007 grams of nickel, 0.0015 grams of iron, and 0.00025 grams of chloride with the balance being other transition metals such as chromium, titanium, and zirconium.
  • coke, sulfur, andZor metals deposited on andZor in the inorganic salt catalyst do not affect the overall yield of crude product (at least 80% for each run) produced by contact of a feed with a hydrogen source in the presence of the inorganic salt catalyst.
  • the crude product had a monocyclic aromatics content at least 100 times the monocyclic ring aromatics content of the feed in a boiling range distribution below 149 0 C.
  • the average crude product yield (based on the weight of the feed) was 89.7 wt%, with a standard deviation of 2.6%; the average coke yield was 7.5 wt% (based on the weight of the feed), with a standard deviation of 2.7%, and the average weight yield of gaseous cracked hydrocarbons was 2.3 wt% (based on the weight of the feed) with a standard deviation of 0.46%.
  • the comparatively large standard deviation of both liquid and coke was due to the third trial, in which the temperature controller of the feed vessel failed, overheating the feed in the addition vessel. Even so, there is no apparent significant deleterious effect of even the large amounts of coke tested here on the activity of the catalyst system.
  • the ratio of C 2 olefins to total C 2 was 0.19.
  • the ratio of C 3 olefin to total C 3 was 0.4.
  • the alpha olefins to internal olefins ratio of the C 4 hydrocarbons was 0.61.
  • the C 4 cis/trans olefins ratio was 6.34. This ratio was substantially higher than the predicted thermodynamic C 4 cis/trans olefins ratio of 0.68.
  • the alpha olefins to internal olefins ratio of the C 5 hydrocarbons was 0.92. This ratio was greater than the predicted thermodynamic C 5 alpha olefins to C 5 internal olefins ratio of 0.194.
  • Example 22 Contact of a Relatively Hi2h Sulfur Containing Feed with a Hydro2 ⁇ n Source in the Presence of the K 7 COVRb 7 CCWCs 7 CCh Catalyst.
  • the apparatus and reaction procedure were the same as described in Example 5, except that the feed, methane, and steam were continuously fed to the reactor.
  • the level of feed in the reactor was monitored using a change in weight of the reactor.
  • Methane gas was continuously metered at 500 cm 3 /min to the reactor.
  • Steam was continuously metered at 6 g/min to the reactor.
  • the inorganic salt catalyst was prepared by combining 27.2 grams of K 2 CO 3 , 32.2 grams of Rb 2 CO 3 and 40.6 grams of Cs 2 CO 3 .
  • the K 2 CO 3 /Rb 2 CO 3 /Cs 2 CO 3 catalyst (59.88 grams) was charged to the reactor.
  • a feed (bitumen, Lloydminster, Canada) having an API gravity of 9.4, a sulfur content of 0.02 grams of sulfur, and a residue content of 0.40 grams, per gram of feed, was heated in the addition vessel to 150 0 C.
  • the hot bitumen was continuously metered from the addition vessel at 10.5 g/min to the reactor in an attempt to maintain the feed liquid level of 50% of the reactor volume, however, the rate was insufficient to maintain that level.
  • the methane/steam/feed was contacted with the catalyst at an average internal reactor temperature of 456 0 C. Contacting of the methane/steam/feed with the catalyst produced a total product (in this example in the form of the reactor effluent vapor).
  • a total of 1640 grams of feed was processed over 6 hours. From a difference in initial catalyst weight and residue/catalyst mixture weight, 0.085 grams of coke per gram of feed remained in the reactor. From contact of the feed with the methane in the presence of the K 2 CO 3 /Rb 2 CO 3 /Cs 2 CO 3 catalyst, 0.93 grams of total product per gram of feed was produced. The total product included, per gram of total product, 0.03 grams of gas and 0.97 grams of crude product, excluding the amount of methane and water used in the reaction.
  • the gas included, per gram of gas, 0.014 grams of hydrogen, 0.018 grams of carbon monoxide, 0.08 grams of carbon dioxide, 0.13 grams of hydrogen sulfide, and 0.68 grams of non-condensable hydrocarbons. From the amount of hydrogen sulfide generated, it may be estimated that the sulfur content of the feed was reduced by 18 wt%. As shown in this example, hydrogen, carbon monoxide, and carbon dioxide were produced. The molar ratio of carbon monoxide to carbon dioxide was 0.4.
  • the C 2 -Cs hydrocarbons included, per gram of hydrocarbons, 0.30 grams of C 2 compounds, 0.32 grams of C 3 compounds, 0.26 grams of C 4 compounds, and 0.10 grams of C 5 compounds.
  • the weight ratio of iso-pentane to n-pentane in the non-condensable hydrocarbons was 0.3.
  • the weight ratio of isobutane to n-butane in the non-condensable hydrocarbons was 0.189.
  • the C 4 compounds had, per gram of C 4 compounds, a butadiene content of 0.003 grams.
  • a weight ratio of alpha C 4 olefins to internal C 4 olefins was 0.75.
  • a weight ratio of alpha C 5 olefins to internal C 5 olefins was 1.08.
  • Example 25 The data in Example 25 demonstrates that continuous processing of a relatively high sulfur feed with the same catalyst in the presence of coke did not diminish the activity of the inorganic salt catalyst, and produced a crude product suitable for transportation.
  • Example 23 Contact of a Feed with a Hydro2 ⁇ n Source in the Presence of a The apparatus and reaction procedure was performed using conditions as described in Example 22. The K 2 CO 3 /Rb 2 CO 3 /Cs 2 CO 3 catalyst (56.5 grams) was charged to the reactor. A total of 2550 grams of feed was processed over 6 hours. From a difference in initial catalyst weight and residue/catalyst mixture weight, 0.114 grams of coke per gram of feed remained in the reactor, based on the weight of the feed. A total of 0.89 grams of total product per gram of feed was produced. The total product included, per gram of total product, 0.04 grams of gas and 0.96 grams of crude product, excluding the amount of methane and water used in the reaction.
  • the gas included, per gram of gas, 0.021 grams of hydrogen, 0.018 grams of carbon monoxide, 0.052 grams of carbon dioxide, 0.18 grams of hydrogen sulfide, and 0.65 grams of non-condensable hydrocarbons. From the amount of hydrogen sulfide produced, it may be estimated that the sulfur content of the feed was reduced by 14 wt%, based on the weight of the feed. As shown in this example, hydrogen, carbon monoxide, and carbon dioxide were produced. The molar ratio of carbon monoxide to carbon dioxide was 0.6.
  • the C 2 -C 6 hydrocarbons included, per gram of C 2 -C 6 hydrocarbons, 0.44 grams of C 2 compounds, 0.31 grams of C 3 compounds, 0.19 grams of C 4 compound and 0.068 grams of C 5 compounds.
  • the weight ratio of iso-pentane to n-pentane in the non-condensable hydrocarbons was 0.25.
  • the weight ratio of iso-butane to n-butane in the non-condensable hydrocarbons was 0.15.
  • the C 4 compounds had, per gram of C 4 compounds, a butadiene content of 0.003 grams.
  • Example 24 Contact of a Feed with a Hydro2en Source in the Presence of CaOZZrO 2 Catalyst to Produce a Total Product. The following reactor and conditions were used for Examples 24-27.
  • a 250 mL Hastelloy C Parr Autoclave (Parr Model #4576) rated at 35 MPa working pressure (5000 psi) at 500 0 C, was fitted with a mechanical stirrer and an 800 watt Gaumer band heater on a Eurotherm controller capable of maintaining the autoclave at + 5 0 C from ambient to 625 0 C, a gas inlet port, a steam inlet port, one outlet port, and a thermocouple to register internal temperature. Prior to heating, the top of the autoclave was insulated with glass cloth.
  • the reactor includes a screen with openings having a diameter of less than 16 mesh.
  • Addition Vessel An addition vessel (a 250 mL, 316 stainless steel hoke vessel) was equipped with a controlled heating system, suitable gas control valving, a pressure relief device, thermocouples, a pressure gauge, and a high temperature control valve (Swagelok Valve # SS-4UW) capable of regulating flow of a hot, viscous, and/or pressurized feed at a flow rate from 0-500 g/min. An outlet side of the high temperature control valve was attached to the first inlet port of the reactor after feed was charged to the addition vessel. Prior to use, the addition vessel line was insulated.
  • the gas stream was collected in a gas bag (a Tedlar gas collection bag) for analysis.
  • the gas was analyzed using GC/MS (Hewlett-Packard Model 5890, now Agilent Model 5890; manufactured by Agilent Technologies, Zion Illinois, U.S.A.).
  • the liquid condensate stream was removed from the cold traps and weighed. Crude product and water were separated from the liquid condensate stream. The crude product was weighed and analyzed.
  • the feed was heated to 150 0 C.
  • a mixture of CaO (15.03 grams, 0.26 moles) and ZrO 2 (20.05 grams, 0.16 moles) were added to the feed to produce an inorganic salt catalyst/catalyst support/feed mixture.
  • the resulting mixture catalyst was metered to the reactor vessel over 20 minutes (a calculated WHSV of 0.8 h "1 ) to maintain the feed liquid level of 50% of the reactor volume under a nitrogen atmosphere.
  • methane and water 26.06 grams charged as steam
  • the reaction was run until little or no gas and/or liquid product was produced.
  • the reactor was weighed at the end of the run to obtain a final reactor weight.
  • the total product included 1.06 grams of a crude product, and 8.152 grams of gas.
  • the gas included 0.445 grams of non-condensable hydrocarbons, 4.39 grams (0.10 moles) of CO 2 , 3.758 grams (0.13 moles) of CO, 0.627 grams of H 2 gas, 0.03 grams Of H 2 S and 0.296 grams of coke.
  • the selectivity for products containing carbon was calculated based on the weight of carbon containing products divided by weight of asphalt charged to the reactor. For five experiments run as described in Example 24 the mean selectivity for products containing carbon was determined to be: 67 wt% for combined carbon monoxide and carbon dioxide, 7.47 wt% for non-condensable hydrocarbons and 19.88 wt% for crude product and 4.94 wt% for coke.
  • This example demonstrates a method for contacting the feed with an inorganic salt catalyst/support mixture in the presence of a hydrogen source hydrogen source and steam to produce a crude product and gas and less than 0.1 grams of coke per gram of feed. In the presence of CaO, more the production of gas was increased relative to the production of than crude product.
  • Example 25 Contact of a Feed with a Hydro2en Source in the Presence of MgOZZrO 2 Catalyst to Produce a Crude Product.
  • the feed and apparatus was the same as described in Example 24.
  • ZrO 2 (8.59 grams) was placed on the screen in the reactor.
  • the feed was heated to 150 0 C.
  • MgO catalyst (19.82 grams, 0.49 moles) and ZrO 2 (29.76 grams, 0.24 moles) were charged to the feed (9.92 grams) to produce an inorganic salt catalyst/catalyst support/feed mixture.
  • the resulting mixture catalyst was metered to the reactor vessel over 0.5 hour (a calculated WHSV of 0.75 h "1 ) to maintain the feed liquid level of 50% of the reactor volume under a nitrogen atmosphere.
  • methane and water (48.1 grams charged as steam) were charged to the reaction vessel over 0.5 hour.
  • the reaction was run until little or no gas and/or liquid product was produced.
  • the reactor was weighed at the end of the run to obtain a final reactor weight.
  • the total product included 1.92 grams of a crude product, and 18.45 grams of gas.
  • the gas included 1.183 grams of non-condensable hydrocarbons, 8.66 grams (0.19 moles) of CO 2 , 7.406 grams (0.26 moles) of CO, 1.473 grams of H 2 gas, 0.125 grams of H 2 S, and 0.0636 grams of coke.
  • the molar ratio of CO to CO 2 was calculated to be 1.4.
  • the selectivity for products containing carbon was calculated based on the weight of carbon containing products divided by weight of asphalt charged to the reactor. For three experiments run as described in Example 25 the mean selectivity for products containing carbon was determined to be: 65.88 wt% for combined carbon monoxide and carbon dioxide, 11.74 wt% for non-condensable hydrocarbons and 12.35 wt% for crude product and 8.78 wt% for coke.
  • This example demonstrates a method for contacting the feed with an inorganic salt catalyst/support mixture in the presence of a hydrogen source and steam to produce a crude product and gas and less than 0.1 grams of coke per gram of feed. More gas than crude product was produced in the presence of MgO as compared to Example 24.
  • Example 26 Contact of a Feed with a Hydrogen Source in the Presence of ZrCMo Produce a Crude Product. The feed and apparatus was the same as described in Example 24. ZrO 2 (8.56 grams) was placed on the screen in the reactor.
  • the feed was heated to 150 0 C.
  • ZrO 2 24.26 grams was charged to the feed (5.85 grams) to produce a ZrO 2 /feed mixture.
  • the resulting mixture catalyst was metered to the reactor vessel over 20 minutes (a calculated WHSV of 0.6 h "1 ) to maintain the feed liquid level of 50% of the reactor volume under a nitrogen atmosphere.
  • methane and water (24.1 grams charged as steam) were charged to the reaction vessel over 20 minutes.
  • the reaction was run until little or no gas and/or liquid product was produced.
  • the reactor was weighed at the end of the run to obtain a final reactor weight.
  • the total product included 0.4 grams of a crude product, and 5.25 grams of gas.
  • the gas included 0.881 grams of non-condensable hydrocarbons, 2.989 grams of CO 2 , 1.832 grams of CO, 0.469 grams of H 2 gas, and 0.34 grams of H 2 S. From the difference in the initial and final weight of the reactor 1.67 grams of coke was formed. The molar ratio of CO to CO 2 was calculated to be 1.
  • the selectivity for products containing carbon was calculated based on the weight of carbon containing products divided by weight of asphalt charged to the reactor. For two experiments run as described in Example 26 the mean selectivity for products containing carbon was determined to be: 31.73 wt% for combined carbon monoxide and carbon dioxide, 18.93 wt% for non-condensable hydrocarbons and 10.34 wt% for crude product and 39 wt% for coke.
  • This example demonstrates that contacting a feed with a catalyst support in the presence of a hydrogen source and steam produces a minimal amount of crude product, gases, and coke.
  • Comparative Example 27 Contact of a Feed with a Hydrogen Source under Non- Catalytic Conditions to Produce a Crude Product.
  • the feed and apparatus was the same as described in Example 24.
  • Silicon carbide, an inert material, (silicon carbide, 13.1 grams) was placed on the screen in the reactor. The feed was heated to 150 0 C. Silicon carbide (24.26 grams) was charged to the feed (4.96 grams) to produce a silicon carbide /feed mixture.
  • the resulting mixture catalyst was metered to the reactor vessel over 0.5 hour (a calculated WHSV of 0.4 h "1 ) to maintain the feed liquid level of 50% of the reactor volume under a nitrogen atmosphere.
  • the selectivity for products containing carbon was calculated based on the weight of carbon containing products divided by weight of asphalt charged to the reactor. For two experiments run as described in Example 27 the mean selectivity for products containing carbon was determined to be: 11.75 wt% for combined carbon monoxide and carbon dioxide, 7.99 wt% for non-condensable hydrocarbons and 9.32 wt% for crude product and 65.96 wt% for coke.
  • Data points 270 represents the total amount of carbon monoxide and carbon dioxide gases produced.
  • Data points 272 represents amount of non-condensable hydrocarbons produced.
  • Data points 274 represents amount of crude product.
  • Data points 276 represents amount of coke produced and/or unreacted asphaltenes.
  • the total amount of carbon monoxide and carbon dioxide gases is enhanced when a feed is contacted with an inorganic salt catalyst as compared to contact with a catalyst support or under thermal conditions.
  • calcium oxide is used as the inorganic salt catalyst more crude product is produced compared to magnesium oxide, zirconium oxide, or the thermal experiment.
  • Example 28 Contact of a Feed with a Hydro2 ⁇ n Source In the Presence of a Supported Inor2anic Catalyst.
  • An inorganic salt catalyst was supported on zeolite.
  • the supported inorganic salt catalyst contained, per gram of supported inorganic salt catalyst, 0.049 grams of potassium, 0.069 grams of rubidium, and 0.109 grams of cesium.
  • a feed (Kuwait long residue, WHSV of Ih "1 ) was fluidly contacted with a supported inorganic salt catalyst (modified Equilibrium c) in a micro-activity test ("MAT") at 450 0 C, 1 bar absolute (0.1 MPA) in the presence of steam (water flow rate of 0.36 gram/min to produce the steam) using methane as the fluidization gas at a rate of 45 NmL/min to produce a total product.
  • MAT micro-activity test
  • contacting a feed with a supported inorganic salt catalyst produced in the presence of a hydrogen source and steam produced a total product and at most 0.2 grams of coke.
  • a catalyst to feed ratio 4 a total product that included 0.08 grams of gas, 0.73 grams of crude product and 0.16 grams of coke, per gram of feed, was produced.
  • a catalyst to feed ratio of 8 a total product that included 0.09 grams of gas, 0.7 grams of crude product and 0.14 grams of coke, per gram of feed, was produced.
  • adjusting the catalyst to feed ratio from 4 to 8 lowered the amount of coke formed during contacting.
  • Example 29 Contact of a Feed with a Hydro2 ⁇ n Source In the Presence of an E-Cat at Various Catalyst/Feed Ratios.
  • the equipment, contacting conditions, feed, and catalyst to feed ratios were the same as for Example 28.
  • the catalyst was a commercial Equilibrium fluidized catalytic cracking catalyst ("E-Cat", Akzo Nobel Cobra 553) that included 1541 ppmw of nickel, 807 ppmw of vanadium, 029 wt% sodium and 0.4 wt% iron.
  • the amount of gas, crude product, and coke formed for each run is tabulated in Table 3, FIG. 17 and graphically depicted in FIG. 18.
  • Plot 286 represents the amount of gas produced.
  • Plot 288 represents the amount of crude product produced, and
  • Plot 290 represents the amount of coke produced for each run.
  • the amount of gas and crude product formed from the feed using the new E-Cat remained constant for at various catalyst to feed ratios.
  • 0.23 grams of gas, 0.60 grams of crude product, and 0.16 grams of coke of product, per gram of feed was produced.

Abstract

L'invention concerne des procédés de production d'un produit brut. Un procédé consiste à acheminer une charge d'alimentation et un catalyseur à sels inorganiques supporté vers une zone de contact. La charge d'alimentation présente une teneur totale, par gramme de charge d'alimentation, d'au moins 0,9 gramme d'hydrocarbures dont l'intervalle de distillation est compris entre 343°C et 538°C. Le contact du catalyseur à sels inorganiques supporté avec la charge d'alimentation en présence d'une source d'hydrogène et de vapeur est réalisé de façon que le catalyseur à sels inorganiques supporté devienne fluidisé, un produit total renfermant un produit brut étant produit. Le produit brut présente une teneur totale, par gramme de produit brut, d'au moins 0,2 gramme d'hydrocarbures dont l'intervalle de distillation est compris entre 204°C et 343°C.
PCT/US2007/071671 2006-06-22 2007-06-20 Procédés de production d'un produit brut à partir d'une charge d'alimentation sélectionnée WO2007149921A1 (fr)

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EP07812215A EP2029698A1 (fr) 2006-06-22 2007-06-20 Procédés de production d'un produit brut à partir d'une charge d'alimentation sélectionnée
JP2009516704A JP2009541537A (ja) 2006-06-22 2007-06-20 選択された原料からの原油生成物の製造方法
CA002655581A CA2655581A1 (fr) 2006-06-22 2007-06-20 Procedes de production d'un produit brut a partir d'une charge d'alimentation selectionnee
MX2008016078A MX2008016078A (es) 2006-06-22 2007-06-20 Metodo para obtener un producto crudo a partir de una fuente seleccionada.

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CA2655581A1 (fr) 2007-12-27
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