MXPA06006741A

MXPA06006741A - Systems and methods of producing a crude product.

Info

Publication number: MXPA06006741A
Application number: MXPA06006741A
Authority: MX
Inventors: Stanley Nemec Milam
Original assignee: Shell Int Research
Priority date: 2003-12-19
Filing date: 2004-12-16
Publication date: 2006-08-18
Also published as: MXPA06006791A; NL1027779C2; RU2379331C2; BRPI0405575A; WO2005061671A2; WO2005066308A3; NL1027780A1; NL1027782C2; NL1027782A1; NL1027778A1; WO2005066309A3; AU2004312366A1; WO2005061671A3; BRPI0405723A; WO2005063928A2; WO2005061664A3; NL1027776C2; CA2549405A1; TW200535232A; WO2005066304A3

Abstract

Contact of a crude feed with one or more catalysts produces a total product that includes a crude product. The crude feed has a residue content of at least 0.2 grams of residue per gram of crude feed. The crude product is a liquid mixture at 25 degree C and 0.101 MPa. One or more properties of the crude product may be changed by at least 10 % relative to the respective properties of the crude feed. In some embodiments, gas is produced during contact with one or more catalysts and the crude feed.

Description

SYSTEMS AND METHODS OF PRODUCTION OF A CRUDE PRODUCT FIELD OF THE INVENTION The present invention describes in a general way the systems and methods of crude feed treatment, and further describes the compositions produced, as an example, when these systems and methods are used. In particular, the embodiments described herein relate to systems and methods of converting a crude cargo with a waste content of at least 0.2 grams of waste per gram of crude feed, to obtain a crude product consisting of (a) a liquid mixture at 25 ° C and 0.101 MPa, and (b) has one or more improved properties than the crude feed properties. BACKGROUND OF THE INVENTION Crude oils that have one or more inadequate properties that do not allow them to be transported or processed for the high cost using conventional infrastructure are commonly called "unfavorable crudes". Disadvantageous crudes usually contain relatively high levels of waste. Such crudes tend to be difficult and expensive to transport and / or process Outlining conventional facilities. Crudes with a high percentage of waste can be treated at high temperatures to convert the crude into coke. Ref. 173570 Alternatively, crude oils with a high percentage of residues are usually treated with water at high temperatures to obtain less viscous crudes or crude mixtures. During processing it can be difficult to remove water from the less viscous crude, or from the less viscous crude mixtures with conventional methods. The "disadvantageous crudes" generally include hydrocarbons with hydrogen deficiency. When hydrogen-deficient hydrocarbons are processed, it is usually necessary to add considerable amounts of hydrogen, particularly if unsaturated compounds resulting from the disintegration processes are produced. Hydrogenation during processing, which usually includes the use of an active hydrogenation catalyst, may be necessary to prevent the unsaturated fragments from forming coke. It is expensive to produce and transport hydrogen to treatment facilities. Coke can be formed, or deposited on the catalyst surfaces very quickly during the processing of "disadvantageous crudes". This can be expensive in the regeneration of the catalytic activity of the catalyst contaminated with coke. The high temperatures that are used during the regeneration can also decrease the activity of the catalyst or cause a deterioration thereof.

The disadvantageous crudes may include acid components that contribute to the total acid number (TAN) of the crude feed. The "disadvantageous crudes" with a relatively high TAN index can contribute to the corrosion of metallic components during transport and / or processing of "unfavorable crudes". The removal of the acid components from the "disadvantageous crudes" may include the chemical neutralization of the acidic components with various bases. Alternatively, corrosion-resistant metals can be used in the transport equipment and / or in the processing equipment. The use of corrosion-resistant metals generally involves a significant expense, and therefore, it is desirable to avoid the use of these metals in existing equipment. Another method for inhibiting corrosion may include the addition of corrosion inhibitors to the "disadvantageous crudes" prior to transport and / or processing thereof. The use of corrosion inhibitors can negatively affect the equipment used for the processing of crude oils, or the quality of the products obtained from crude oil. The "disadvantageous crudes" may contain relatively high concentrations of polluting metals, for example, nickel, vanadium and / or iron. During the processing of said crudes, the metals . contaminants and / or polluting metal compounds can be deposited on the catalyst surface or in the pore volume of the catalyst. This can lower the catalyst activity. The disadvantageous crudes usually contain organically bound heteroatoms (for example, sulfur, oxygen and nitrogen). The organically bound heteroatoms can sometimes produce adverse effects on the catalysts. Alkali metal salts or alkaline earth metal salts have been used in waste desulfurization processes. These processes tend to perform poor desulfurization, insoluble oil sludge production, deficient demetallization, formation of substantially inseparable salt and oil mixtures, use of large quantities of hydrogen gas, and / or relatively high hydrogen pressures. Some of the processes that are applied to improve the quality of the crude include the addition of a diluent to the "disadvantageous crudes" to decrease the percentage by weight of the components that contribute to the disadvantageous properties. However, the addition of diluent usually increases the costs of treating "unfavorable crudes" due to the costs of the diluent or the higher cost associated with the handling of "unfavorable crudes". The addition of diluent to a "disadvantageous crude" can sometimes decrease the stability of the crude.

U.S. Patent Nos. 3,136,714 to Gibson et al .; 3,558,747 to Gleim et al .; 3,847,797 to Pasternak et al .; 3,948,759 to King et al .; 3,957,620 to Fukui et al .; 3,960,706 to McCollum et al .; 3,960,708 to McCollum et al .; 4,119,528 to Baird, Jr. et al .; 4,127,470 to Baird, Jr. et al .; 4,224,140 by Fujimori et al .; 4,437,980 to Heredy et al .; 4,591,426 to Krasuk et al .; 4,665,261 from Mazurek; 5,064,523 to Kretschmar et al .; 5,166,118 to Kretschmar et al .; 5,288,681 of Gatsis; 6,547,957 to Sudhakar et al .; and publications of patent applications Nos. 20030000867 by Reynolds and 20030149317 by Rendina, describe various processes and systems used to treat crude oils. However, the processes, systems and catalysts described in these patents have limited applicability due to many of the technical problems raised above. In summary, "disadvantageous crudes" generally have undesired properties (eg, relatively high residues, a tendency to corrosion of equipment, and / or a tendency to consume relatively high concentrations of hydrogen during treatment). Other undesired properties include relatively high concentrations of unwanted components (eg, relatively high TAN, organically bound heteroatoms, or metallic contaminants). These properties give rise to complications either in conventional transport or in the treatment infrastructure, among which may include increased corrosion, decrease in catalyst half-life, blockages or increased use of hydrogen during treatment. Therefore, it is very necessary, from the economic and technical point of view, to have better systems, methods or catalysts to convert the "disadvantageous crude" into crude product that possesses more desired properties. BRIEF DESCRIPTION OF THE INVENTION The inventions described herein generically describe the systems and methods used for the contact of a crude feed with one or more catalysts to produce a total product, including the crude product, and in some embodiments , also to a non-condensable gas. In addition, the inventions described herein describe compositions with novel combinations of the components they possess. Said compositions can be obtained using the systems and methods described herein. The invention - provides a method for preparing a "crude product", which includes contacting a feed of the crude with a hydrogen feed in the presence of one or more catalysts obtaining the "crude product", where one or more of the catalysts include a catalyst containing K3Fe? 0S14. The invention further provides a method for obtaining a "crude product", which includes: contacting the feed of the crude with a hydrogen feed in the presence of one or more catalysts to give a total product including a "raw product" ", which consists of the liquid mixture at 25 ° C and 0.101 MPa, at least one of the catalysts includes one or more transition metal sulfides, and the crude feed has a residue content of at least 0.2 grams of residue per gram of crude feed, as determined by ASTM D5307 method; and controlling the contact conditions in such a way that the "crude product" has maximum 0.05 grams of coke per gram of crude product, the crude product has at least 0.001 grams of naphtha per gram of crude product, and the naphtha has a number of octanes of at least 70. The invention further provides a method for obtaining a "crude product", which includes: contacting the crude feed with a hydrogen feed in the presence of one or more catalysts to give a total product which includes a "crude product", which consists of the liquid mixture at 25 ° C and 0.101 MPa, at least one of the catalysts includes one more transition metal sulfides, and the feed of the crude has a residual content of minus 0.2 grams of residue per gram of crude, as determined by the ASTM D5307 method; and controlling the contact conditions in such a way that the crude product includes kerosene, in concentrations of at least 0.2 grams of aromatic compounds per gram of kerosene, as determined by the method ASTM D5186, the kerosene has a freezing point at temperature maximum -30 ° C, as determined by the method ASTM D2386, and the crude product has maximum 0.05 grams of coke per gram of crude product. The invention further provides a method for obtaining a crude product, which includes: contacting the feed of the crude with a hydrogen feed in the presence of one or more catalysts to produce a total product including a crude product, which consists of the liquid mixture at 25 ° C and 0.101 MPa, at least one of the catalysts includes one more transition metal sulfides, and the crude feed has a residue content of at least 0.2 grams of residue per gram of feed crude, and control the contact conditions so that the raw product contains maximum 0.05 grams of coke per gram of crude product with a weight ratio of atomic hydrogen and atomic coal (H / C) in the crude product of maximum 1.75 such as determined by the ASTM D6730 method. The invention further provides a method for obtaining a crude product, which includes: contacting a crude feed with a hydrogen feed in the presence of one or more catalysts to obtain a total product including the crude product, which consists of a liquid mixture at 25 ° C and 0.101 MPa, at least one of the catalysts includes one or more transition metal sulfides, and the crude feed has a residue content of at least 0.2 grams of residue per gram of crude feed, as determined by ASTM method D5307, - and the weight ratio of atomic hydrogen and atomic carbon (H / C) in the crude feed is at least 1.5; and control the contact conditions so that the crude product has an H / C atomic ratio of 80-120% of the atomic ratio H / C of the crude feed, the crude product has a maximum residue of 30% of the residue of the crude feed, as determined by the ASTM D5307 method, the crude product has at least 0.001 grams of naphtha per gram of crude product, and the naphtha has an octane number of at least 70. The invention further provides a method for obtain a crude product, which includes: the contact of a crude feed with a hydrogen feed in the presence of one or more catalysts, to produce a total product that includes the crude product, which consists of a liquid mixture at 25 ° C and 0.101 MPa, at least one of the catalysts includes one or more transition metal sulfides, and the crude feed has a residue content of at least 0.2 grams of residue per gram of feed. crude oil, as determined by the ASTM D5307 method; and control the contact conditions in such a way that the crude product contains, per gram of crude product: at least 0.001 grams of naphtha, with an octane number of at least 70; at least 0.001 grams of kerosene, which includes aromatics, and which contains at least 0.2 grams of aromatics per gram of kerosene, as determined by the ASTM D5186 method, and kerosene has a freezing point at a maximum temperature -30 ° C, as determined by the ASTM method D2386; at least 0.001 grams of vacuum gas oil (GOV), which has at least 0.3 grams of aromatics per gram of GOV, as determined by the IP 368/90 method; and maximum 0.05 grams of residue, as determined by the ASTM D5307 method. The invention further provides a method for obtaining a crude product, which includes: contacting the crude feed with a hydrogen feed in the presence of one or more catalysts including transition metal sulfide catalysts to obtain a total product that includes the crude product, which consists of a liquid mixture at 25 ° C and 0.101 MPa, the transition metal sulfide catalyst has a total of at least 0.4 gram of one or more transition metal sulfides per gram of catalyst transition metal sulfide, the crude feed has a residual content of at least 0.2 grams of residue per gram of crude feed, as determined by the ASTM D5307 method; and control the contact conditions in such a way that the raw product has maximum 0.05 grams of coke per gram of raw product, and the raw product has a residual content of maximum 30% of the content of the crude feed, as determined by the ASTM D5307 method. The invention further provides a method for obtaining a crude product, which includes: contacting the crude feed with a hydrogen feed in the presence of one or more catalysts including transition metal sulfide catalysts to obtain a total product that includes the crude product, which consists of a liquid mixture at 25 ° C and 0.101 MPa, the transition metal sulfide catalyst has a total of at least 0.4 grams of one or more transition metal sulfides per gram of catalyst transition metal sulfide, the crude feed has a nitrogen content of at least 0.001 grams of nitrogen per gram of crude feed, and the crude feed has a residue content of at least 0.2 grams of residue per gram of feed of crude; and controlling the contact conditions so that the crude product has a nitrogen content of maximum 90% of the nitrogen content of the crude feed, and the raw product has a residue content of maximum 30% of the waste content of the crude oil. crude feed, determining the nitrogen content by the method ASTM D5762 and determining the residue content by the method ASTM D5307. The invention further provides a method for obtaining a crude product, which includes: contacting the crude feed with a hydrogen feed in the presence of one or more catalysts including transition metal sulfide catalysts to obtain a total product that includes the crude product, which consists of a liquid mixture at 25 ° C and 0.101 MPa, the transition metal sulfide catalyst has a total of at least 0.4 grams of one or more transition metal sulfides per gram of catalyst transition metal sulfide, the crude feed has a total Ni / V / Fe content of at least 0.0001 grams of Ni / V / Fe per gram of crude feed, and the crude feed has a residual content of minus 0.2 grams of residue per gram of crude feed; and control the contact conditions in such a way that the raw product has a content of coke per gram of crude product of maximum 0.05 grams, the crude product has a content of Ni / V / Fe of maximum 90% of the content of Ni / V Fe / Fe of crude oil, and the raw product has a residue content of maximum 30% of the content of crude oil residue, determining the content of Ni / V / Fe by the method ASTM D5863 and determining the content of waste by the ASTM D5307 method. The invention further provides a method for obtaining a crude product, which includes: contacting the crude feed with a hydrogen feed in the presence of one or more catalysts including transition metal sulfide catalysts to obtain a total product that includes the crude product, which consists of a liquid mixture at 25 ° C and 0.101 MPa, the transition metal sulfide catalyst has a total of at least 0.4 grams of one or more transition metal sulfides per gram of catalyst transition metal sulfide, the crude feed has a sulfur content of at least 0.001 grams of sulfur per gram of crude feed, and the crude feed has a residue content of at least 0.2 grams of residue per gram of feed of crude; and control the contact conditions so that the crude product has a sulfur content of maximum 70% of the sulfur content of the crude feed, and the crude product has a residue content of maximum 30% of the content of the feed residue of crude oil, determining the sulfur content by the method ASTM D4294 and determining the content of residue by the method ASTM D5307. The invention also provides a method for obtaining a transition metal sulfide catalyst composition which includes: mixing a transition metal oxide and a metal salt to form a mixture of metal salt and transition metal oxide; the reaction of a mixture of metal salt and transition metal oxide with hydrogen to form an intermediate; and the reaction of the intermediate with sulfur in the presence of one or more hydrocarbons to produce a sulfided transition metal catalyst. The invention further provides a method for obtaining a crude product, which includes: contacting the crude feed with a hydrogen feed in the presence of one or more catalysts including transition metal sulfide catalysts to obtain a total product that It includes the crude product, which is a liquid mixture at 25 ° C and 0.101 MPa, the sulfide catalyst transition metal includes a sulfide of transition metal, and the crude feed has a residue content of at least 0.2 grams of residue per gram of crude feed, as determined by ASTM method D5307; and controlling the contact conditions in such a way that the crude product has a residue content of maximum 30% of the residue content of the crude feed; and the transition metal sulfide catalyst is obtained in the following manner: mixing a transition metal oxide and a metal salt to form a mixture of metal salt and transition metal oxide; the reaction of a mixture of metal salt and transition metal oxide with hydrogen to form an intermediate; and the reaction of the intermediate with sulfur in the presence of one or more hydrocarbons to produce a sulfided transition metal catalyst. The invention further provides a method for obtaining a crude product, which includes: contacting a crude feed with a hydrogen feed in the presence of one or more catalysts to give a total product including the crude product, which it consists of a liquid mixture at 25 ° C and 0.101 MPa, the crude feed has at least 0.2 grams of residue per gram of crude feed, as determined by the method ASTM D5307; and producing at least a fraction of the total product in the form of steam; condense at least a fraction of the vapor at 25 ° C and 0.101 MPa; and form the crude product, which contains per gram of crude product: at least 0.001 grams of naphtha, the naphtha has an octane number of at least 70; At least 0.001 grams of GOV, the GOV has at least 0.3 grams of aromatics per gram of GOV, as determined by the method IP 368/90; and maximum 0.05 grams of residue, as determined by the ASTM D5307 method. The invention further provides a method for obtaining a crude product, which includes: contacting a crude feed with a hydrogen feed in the presence of an inorganic salt catalyst to give a total product including the crude product, the which contains a residue of at least 0.2 grams of residue per gram of crude feed, as by the ASTM D5307 method, the crude product is a liquid mixture at 25 ° C and 0.101 MPa, and the crude product contains is determined by gram of crude product: at least 0.001 grams of naphtha, the naphtha contains at least 0.001 grams of monocyclic ring aromatics per gram of naphtha, as determined by the method ASTM D6730; at least 0.001 grams of distillates; and maximum 0.05 grams of residue, as determined by the ASTM D5307 method. The invention further provides a method for obtaining a crude product, which includes: contacting a crude feed with a hydrogen feed in the presence of an inorganic salt catalyst to give a total product including the crude product, the containing residue of at least 0.2 grams of residue per gram of crude feed, as by the ASTM D5307 method, the crude product is a liquid mixture at 25 ° C and 0.101 MPa, and the crude product is determined contains per gram of raw product: at least 0.001 grams of diesel, and diesel has at least 0.3 grams of aromatics per gram of diesel, as determined by IP 368/90; at least 0.001 grams of GOV, which contains at least 0.3 grams of aromatic compounds per gram of GOV, as determined by the method IP 368/90; and maximum 0.05 grams of residue, as determined by the ASTM D5307 method. The invention further provides a method for obtaining a crude product, which includes: contacting a crude feed with a hydrogen feed in the presence of an inorganic salt catalyst to obtain a total product including the crude product, which consists of in a liquid mixture at 25 ° C and 0.101 MPa, the crude feed has a residual content of at least 0.2 grams of residue per gram of crude feed, as determined by the ASTM D5307 method, and the crude feed has a content of monocyclic aromatic rings of maximum 0.1 grams of aromatic compounds per gram of crude feed; and control the contact conditions in such a way that during the contact maximum 0.2 grams of hydrocarbons are formed which are not condensable at 25 ° C and 0.101 MPa per gram of crude feed, as determined by the mass balance, such that the crude product has a content of monocyclic aromatic rings of at least 5% more than the content of these of the crude feed, the content of monocyclic aromatic rings being determined by the method ASTM D6730. - The invention further provides a method for obtaining a crude product, which includes: contacting a crude feed with a hydrogen feed in the presence of an inorganic salt catalyst to obtain a total product including the crude product, which consists of a liquid mixture at 25 ° C and 0.101 MPa, the crude feed has a residue content of at least 0.2 grams of residue per gram of crude feed, as determined by the ASTM D5307 method, and the feed of crude has an olefin content, expressed in grams of olefins per grams of crude feed; and controlling the contact conditions so that the crude product has an olefin content of at least 5% more than the olefin content of the crude feed, the olefin content being determined by the ASTM D6730 method. The invention further provides a method to obtain a crude product, which includes: contacting a crude feed with a hydrogen feed in the presence of an inorganic salt catalyst to obtain a total product that includes the crude product, which consists of a liquid mixture at 25 ° C. ° C and 0.101 MPa, the crude feed has a residue content of at least 0.2 grams of residue per gram of crude feed, and the inorganic salt catalyst presents an increase of gas emitted from the gas emitted in a temperature range of between 50 ° C and 500 ° C as determined by the Temporary Product Analysis (TAP); and control the contact conditions in such a way that the crude product has a residue content, expressed in grams of residue per gram of crude product, of maximum 30% of the content of crude oil residue, determining the content of waste by the ASTM D5307 method. The invention further provides a method for obtaining a crude product, which includes: contacting a crude feed with a hydrogen feed in the presence of an inorganic salt catalyst to obtain a total product including the crude product, which consists of in a liquid mixture at 25 ° C and 0.101 MPa, the crude feed has a residue content of at least 0.2 grams of residue per gram of crude feed, and the inorganic salt catalyst includes at least two inorganic metal salts, and the inorganic salt catalyst presents an increase in gas emitted from the gas emitted in a temperature range determined by the Temporary Product Analysis (TAP)., for its acronym in English), the rising temperature of gas emitted is between (a) the DSC temperature of at least one of the two inorganic metal salts and (b) a DSC temperature of the inorganic salt catalyst, and controlling the contact conditions in such a way that the raw product has a residue content, expressed in grams of residue per gram of crude product, the residue content being determined by the ASTM D5307 method. The invention also provides a method for obtaining a crude oil. product, which includes: contacting a crude feed with a hydrogen feed in the presence of an inorganic salt catalyst to obtain a total product that includes the crude product, which consists of a liquid mixture at 25 ° C and 0.101 MPa, the crude feed has a residue content of at least 0.2 grams of residue per gram of crude feed, as determined by the ASTM D5307 method, and the catalyst inorganic salt presents an increase of a gas emitted in a temperature range between 50 ° C and 500 ° C as determined by the Temporary Product Analysis (TAP, for its acronym in English); and producing a crude product in such a way that a volume of crude product of at least 5% more than the volume of the crude feed is produced, when the volumes are measured at 25 ° C and 0.101 MPa. The invention further provides a method for obtaining a crude product, which includes: contacting a crude feed with a hydrogen feed in the presence of an inorganic salt catalyst to obtain a total product including the crude product, which consists of in a liquid mixture at 25 ° C and 0.101 MPa, the crude feed has a residual content of at least 0.2 grams of waste per gram of crude feed, and the inorganic salt catalyst presents an increase in gas emitted from the gas emitted in a temperature range between 50 ° C and 500 ° C as determined by the Temporary Product Analysis (TAP); and controlling the contact conditions so that during contact, 0.2 grams of hydrocarbons that are not condensable at 25 ° C and 0.101 MPa are formed, per gram of crude feed, as determined by the mass balance. The invention further provides a method for obtaining a crude product, which includes: contacting a crude feed with a hydrogen feed in the presence of an inorganic salt catalyst to obtain a total product including the crude product, which consists of in a liquid mixture at 25 ° C and 0.101 MPa, the crude feed has a residue content of at least 0.2 grams of residue per gram of crude feed, and the inorganic salt catalyst has a heat of transition in a range of temperature between 200 ° C and 500 ° C as determined by Differential Calorimetric Scanning (DSC) at a rate of 10 ° C per minute; and control the contact conditions in such a way that the crude product has a residue content, expressed in grams of residue per gram of crude product, of maximum 30% of the content of crude oil residue, determining the content of waste by the ASTM D5307 method. The invention further provides a method for obtaining a crude product, which includes: contacting a crude feed with a hydrogen feed in the presence of an inorganic salt catalyst to obtain a total product including the crude product, which consists of in a liquid mixture at 25 ° C and 0.101 MPa, the crude feed has a residue content of at least 0.2 grams of residue per gram of crude feed and the inorganic salt catalyst has an ionic conductivity of at least the value ionic conductivity of at least one of the inorganic salts of the inorganic salt catalyst at temperatures in the range of 300 ° C and 500 ° C; and control the contact conditions in such a way that the raw product has a residue content, expressed in grams of residue per gram of crude product, of maximum 30% of the residue content of the crude feed, determining the content of waste by the ASTM D5307 method. The invention further provides a method for obtaining a crude product, which includes: contacting a crude feed with a hydrogen feed in the presence of an inorganic salt catalyst to obtain a total product including the crude product, which consists of in a liquid mixture at 25 ° C and 0.101 MPa, the crude feed has a residue content of at least 0.2 grams of residue per gram of crude feed, and the inorganic salt catalyst includes alkali metal salts, in which at least one of the alkali metal salts is alkali metal carbonates, and the alkali metals have an atomic number of at least 11, and at least one of the atomic ratios of an alkali metal has an atomic number of at least 11 relative to the alkali metal with an atomic number greater than 11, is in the range of 0.1 to 10; and control the contact conditions in such a way that the crude product has a residue content, expressed in grams of residue per gram of crude product, of maximum 30% of the content of crude oil residue, determining the content of waste by the ASTM D5307 method. The invention further provides a method for obtaining a crude product, which includes: contacting a crude feed with a hydrogen feed in the presence of an inorganic salt catalyst to obtain a total product, the crude feed having a content of residues of at least 0.2 grams of residue per gram of crude feed, and the inorganic salt catalyst includes alkali metal salts, in which at least one of the alkali metal salts are alkali metal hydroxides, and the alkali metals have an atomic number of at least 11, and at least one of the atomic ratios of an alkali metal has an atomic number of at least 11 relative to the alkali metal with an atomic number greater than 11, is in the range of 0.1 to 10; and producing at least a fraction of the total product in the form of steam; condense at least a fraction of steam at 25 ° C and 0.101 MPa, and form the crude product, which has a residual content of maximum 30% of the residue content of the crude feed.

The invention further provides a method for obtaining a crude product, which includes: contacting a crude feed with a hydrogen feed in the presence of an inorganic salt catalyst to obtain a product, total, the feed of crude has a content of residues of at least 0.2 grams of residue per gram of crude feed, and the inorganic salt catalyst includes alkali metal salts, in which at least one of the alkali metal salts are alkali metal hydrides, and the alkali metals has an atomic number of at least 11, and at least one of the atomic ratios of an alkali metal has an atomic number of at least 11 relative to the alkali metal with an atomic number greater than 11, is in the range of 0.1 to 10; and producing at least a fraction of the total product in the form of steam; condense at least a fraction of steam at 25 ° C and 0.101 MPa, and form the crude product, which has a residual content of maximum 30% of the crude feed residue content.

The invention further provides a method for obtaining a crude product, which includes: contacting a crude feed with a hydrogen feed in the presence of an inorganic salt catalyst, to produce a total product including the crude product, which it consists of a liquid mixture at 25 ° C and 0.101 MPa, the crude feed has a residue content of at least 0.2 grams of residue per gram of crude feed, the inorganic salt catalyst includes one or more alkali metal salts, one or more alkaline earth metal salts, or mixtures thereof, one of the alkali metal salts is an alkali metal carbonate, the alkali metals have an atomic number of at least 11; and controlling the contact conditions in such a way that the raw product has a residue content of maximum 30% of the crude feed residue content, the residue content being determined by the ASTM D5307 method. The invention further provides a method for obtaining a crude product, which includes: contacting a crude feed with a hydrogen feed in the presence of an inorganic salt catalyst, to produce a total product including the crude product, which consists of a liquid mixture at 25 ° C and 0.101 MPa, the crude feed has a residue content of at least 0.2 grams of residue per gram of crude feed, the inorganic salt catalyst includes one or more alkali metal hydroxides, one or more alkaline earth metal salts, or mixtures thereof, - one of the alkali metal salts has an atomic number of at least 11; and controlling the contact conditions in such a way that the raw product has a residue content of maximum 30% of the crude feed residue content, the residue content being determined by the ASTM D5307 method. The invention further provides a method for obtaining a crude product, which includes: contacting a crude feed with a hydrogen feed in the presence of an inorganic salt catalyst, to generate a total product including the crude product, which consists of a liquid mixture at 25 ° C and 0.101 MPa, the crude feed has a residual content of at least 0.2 grams of residue per gram of crude feed, the inorganic salt catalyst includes one or more alkali metal hydrides, one or more alkaline earth metal salts, or mixtures thereof, one of the alkali metal salts have an atomic number of at least 11; and controlling the contact conditions in such a way that the raw product has a residue content of maximum 30% of the crude feed residue content, the residue content being determined by the ASTM D5307 method. The invention also discloses a method for producing hydrogen gas, which includes: contacting a crude feed with one or more hydrocarbons in the presence of an inorganic salt catalyst and water, the hydrocarbons have carbon numbers in the range of 1 to 6, the crude feed has a residue content of at least 0.2 grams of residue per gram of crude feed, and the inorganic salt catalyst shows an increase in gas emitted of a gas emitted in a temperature range between 50 ° C and 500 ° C, as determined by the Temporary Product Analysis (TAP) method; and production of hydrogen gas. The invention further provides a method for obtaining a crude product, which includes: contacting a first raw feed with an inorganic salt catalyst in the presence of steam to produce gas stream, the gas stream includes hydrogen, the first feed of crude has a residue content of at least 0.2 grams of residue per gram of crude first feed, as determined by ASTM method D5307, and the inorganic salt catalyst has an increase in gas emitted from the gas emitted in a range of temperature between 50 ° C and 500 ° C, as determined by the Temporary Product Analysis (TAP) method; contacting the second crude feed with a second catalyst in the presence of at least a fraction of the gas stream generated to obtain a total product that includes the crude product, which consists of a liquid mixture at 25 ° C and 0.101 MPa; and controlling the contact conditions in such a way that one or more properties of the crude product change at least 10% in relation to the respective properties or properties of the second crude feed.

The invention also discloses a method for producing a gas stream, which includes: contacting a crude feed with an inorganic salt catalyst in the presence of steam, wherein the waste content in the crude feed has at least 0.2 grams of the residue per gram of crude feed, as determined by the ASTM 5307 method; and generating a gas stream, which includes hydrogen, carbon monoxide, and carbon dioxide, the molar ratio of carbon monoxide and carbon dioxide is at least 0.3. The invention further provides a method for obtaining a crude product, which includes: conditioning an inorganic salt catalyst, contacting a crude feed with a hydrogen feed in the presence of a conditioned inorganic salt catalyst to obtain a total product that includes the crude product, which consists of a liquid mixture at 25 ° C and 0.101 MPa, the crude feed has a residual content of at least 0.2 grams of residue per gram of crude feed; and control the contact conditions in such a way that the raw product has a residue content, expressed in grams of residue per gram of crude product, of maximum 30% of the content of crude oil residue, which is determined by the method ASTM D5307. The invention further provides the crude composition, which includes hydrocarbons with a boiling range of between 30 ° C and 538 ° C (1000 ° F) at 0.101 MPa, the hydrocarbons include isoparaffins and n-paraffins with a weight ratio of isoparaffins and n-paraffins of maximum 1.4, as determined by the ASTM D6730 method. The invention further provides a crude composition having, per gram of crude composition: at least 0.001 grams of hydrocarbons with a boiling range distribution of maximum 204 ° C (400 ° F) to 0.101 MPa, at least 0.001 grams of hydrocarbons with a boiling range between 204 ° C and 300 ° C at 0.101 MPa, at least 0.001 grams of hydrocarbons with a boiling range distribution between 300 ° C and 400 ° C at 0.101 MPa, and at least 0.001 grams of hydrocarbons with a boiling range between 400 ° C and 538 ° C (1,000 ° F) to 0.101 MPa, and in which the hydrocarbons have a boiling range distribution of maximum 204 ° C include isoparaffins and n-paraffins with a ratio of isoparaffins and n-paraffins of maximum 1.4, as determined by the method ASTM D6730. The invention further provides a crude composition having, per gram of crude composition: at least 0.001 grams of naphtha, which has an octane number of at least 70, naphtha has at least 0.15 grams of olefins per gram of naphtha , as determined by the ASTM D6730 method; at least 0.001 grams of kerosene, which has at least 0.2 grams of aromatics per gram of kerosene, as determined by ASTM D5186 method, and kerosene has a freezing point at a temperature of -30 ° C maximum, as determined by the ASTM method D2386; and maximum 0.05 grams of residue, as determined by the ASTM D5307 method. The invention also provides a crude composition, which contains per gram of composition: at most 0.15 grams of hydrocarbon gas that is not condensable at 25 ° C. and 0.101 MPa, with maximum 0.3 grams of hydrocarbons with a carbon number of 1 to 3 (Cl to C3), per gram of non-condensable hydrocarbon gas; at least 0.001 grams of naphtha, naphtha with an octane number of at least 70; at least 0.001 grams of kerosene, kerosene with a freezing point at a temperature of maximum -30 ° C, as determined by the ASTM D2386 method, kerosene has at least 0.2 grams of aromatics per gram of kerosene, such as determined by the method ASTM D5186; and maximum 0.05 grams of residue, as determined by the ASTM D5307 method. The invention also provides a crude composition having, per gram of composition: maximum 0.05 grams of residue, as determined by the ASTM D5307 method; at least 0.001 grams of hydrocarbons with a boiling range distribution of maximum 204 ° C (400 ° F) to 0.101 MPa; at least 0.001 grams of hydrocarbons with a boiling range distribution of maximum 204 ° C and 300 ° C at 0.101 MPa; at least 0.001 grams of hydrocarbons with a boiling range distribution between 300 ° C and 400 ° C at 0.101 MPa; at least 0.001 grams of hydrocarbons with a boiling range between 400 ° C and 538 ° C (1,000 ° F) at 0.101 MPa; with hydrocarbons in a boiling range between 20 ° C and 204 ° C include olefins with terminal double bonds and olefins with internal double bonds with a molar ratio of olefins with terminal double bonds and olefins with internal double bonds of at least 0.4, as determined by the ASTM D6730 method.

The invention also provides a crude composition having, per gram of composition: maximum 0.05 grams of residue, determined by the method ASTM D5307; and at least 0. 001 grams of a mixture of hydrocarbons with a boiling range of between 20 ° C and 538 ° C (1000 ° F), as determined by the ASTM D5307 method, and the hydrocarbon mixture contains the following compounds per gram of mixture of hydrocarbons: at least 0.001 grams of paraffins, determined by the method ASTM D6730; at least 0.001 grams of olefins, determined by the ASTM D6730 method, and the olefins have at least 0.001 grams of terminal olefins per gram of olefins, as determined by the ASTM method D6730; at least 0.001 grams of naphtha; At least 0.001 grams of kerosene, the kerosene has at least 0.2 grams of aromatics per gram of kerosene, as determined by the method ASTM D5186; at least 0.001 grams of diesel, diesel with at least 0.3 grams of aromatics per gram of diesel, as determined by the IP 368/90 method, and at least 0.001 grams of vacuum gas oil (GOV), the GOV with at least 0.3 grams of aromatic compounds - per grams of GOV, as determined by the method IP 368/90 The invention further provides a crude composition having, per gram of crude composition: maximum 0.05 grams of residue, determined by the method ASTM D5307, at least 0.001 grams of hydrocarbons with a boiling range of maximum 204 ° C (400 ° F) to 0.101 MPa, at least 0.001 grams of hydrocarbons with a boiling range of between 204 ° C and 300 ° C at 0.101 MPa, at least 0.001 grams of hydrocarbons with a boiling range between 300 ° C and 400 ° C at 0.101 MPa, and at least 0.001 grams of hydrocarbons with a boiling range between 400 ° C and 538 ° C (1,000 ° F) to 0.101 MPa, as determined by the method or ASTM D2887, and in which the hydrocarbons have a boiling range of maximum 204 ° C, and have per gram of hydrocarbons with a boiling range of maximum 204 ° C: at least 0.001 grams of olefins, determined by the ASTM method D6730; and at least 0.001 grams of paraffins, which include isoparaffins and n-paraffins with a weight ratio of iso-paraffins and n-paraffins of maximum 1.4, as determined by the ASTM D6730 method. The invention further provides a crude composition possessing, per gram of crude composition: maximum 0.05 grams of residue, determined by the method ASTM D5307; and at least 0.001 grams of hydrocarbons with a boiling range of maximum 204 ° C (400 ° F) to 0.101 MPa; at least 0.001 grams of hydrocarbons with a boiling range of between 204 ° C and 300 ° C at 0.101 MPa; at least 0.001 grams of hydrocarbons with a boiling range between 300 ° C and 400 ° C at 0.101 MPa; and at least 0.001 grams of hydrocarbons with a boiling range of between 400 ° C and 538 ° C (1,000 ° F) to 0.101 MPa, as determined by the method ASTM D2887; and wherein the hydrocarbons have a boiling range of between -10 ° C and 204 ° C include compounds with a carbon number of 4 (C4), the C4 compounds have at least 0.001 grams of butadiene per gram of C4 compounds. The invention also provides a crude composition that has, per gram of crude composition: maximum 0.05 grams of residue; at least 0.001 grams of hydrocarbons with a boiling range of maximum 204 ° C (400 ° F) to 0.101 MPa; at least 0.001 grams of hydrocarbons with a boiling range of between 204 ° C and 300 ° C at 0.101 MPa; at least 0.001 grams of hydrocarbons with a boiling range between 300 ° C and 400 ° C at 0.101 MPa; and at least 0.001 grams of hydrocarbons with a boiling range between 400 ° C and 538 ° C (1,000 ° F) at 0.101 MPa; and more than 0 grams, but less than 0.01 grams of one or more catalysts, which have at least one or more alkali metals. In addition, the invention provides in some embodiments, in combination with one or more methods or compositions according to the invention, the feeding of crude with the following characteristics: (a) not having been treated in a refinery, distilled, and / or fractionally distilled; (b) possess the components with a carbon number greater than 4, and the crude feed has at least 0.5 grams of said components per gram of crude feed; (c) comprises hydrocarbons, one of whose portions has: a boiling range distribution below 100 ° C at 0.101 MPa, a boiling range distribution between 100 ° C and 200 ° C at 0.101 MPa, a distribution of the range boiling between 200 ° C and 300 ° C at 0.101 MPa, a boiling range distribution between 300 ° C and 400 ° C at 0.101 MPa, and a boiling range distribution between 400 ° C and 700 ° C to 0.101 MPa; (d) possess, per gram of crude feed: at least: 0.001 grams of hydrocarbons with boiling ranges below 100 ° C to 0.101 MPa, at least 0.001 grams of hydrocarbons have boiling ranges between 100 ° C and 200 ° C at 0.101 MPa, at least 0.001 grams of hydrocarbons have a boiling range distribution between 200 ° C and 300 ° C at 0.101 MPa, at least 0.001 grams of hydrocarbons have a boiling range distribution of between 300 ° C and 400 ° C at 0.101 MPa, and at least 0.001 grams of hydrocarbons have boiling ranges between 400 ° C and 700 ° C at 0.101 MPa; (e) possesses a TAN index (f) possesses from 0.2 to 0.99 grams, 0.3 to 0.8 grams, or 0.4 to 0.7 grams of residue per gram of crude feed; (g) includes nickel, vanadium and iron or their mixtures; (h) has sulfur; or (i) hydrocarbons with nitrogen. In addition, the invention provides in some embodiments, in combination with one or more methods or compositions according to the invention, the hydrogen feed with the following characteristics: (a) it is gaseous; (b) includes molecular hydrogen; (c) includes light hydrocarbons; (d) includes methane, ethane, propane, or mixtures thereof; (e) includes water; or (f) includes their mixtures. In addition, the invention provides in some embodiments, in combination with one or more methods or compositions according to the invention, a method that includes contacting an inorganic salt catalyst with the following characteristics: (a) heating the inorganic salt catalyst at a temperature of at least 300 ° C; or (b) heating the inorganic salt catalyst to a temperature of at least 300 ° C and cooling the inorganic salt catalyst to a temperature of maximum 500 ° C. Furthermore, the invention provides in some embodiments, in combination with one or more methods or compositions according to the invention, a method that includes contacting the crude feed with one or more catalysts with the following characteristics: such that during maximum contact 0.2 grams are formed, maximum 0.15 grams, maximum 0.1 grams, or maximum 0.05 grams of non-condensable hydrocarbons at 25 ° C and 0.101 MPa per gram of crude feed, as determined by mass balance; (b) such that the contact temperature is 250 - 750 ° C or 260-550 ° C; (c) the pressure is 0.1 - 20 MPa; (d) the ratio of hydrogen gas feed to crude feed is 1-16100 or 5-320 standard cubic meters of hydrogen feed per cubic meter of crude feed; (e) inhibiting the formation of coke; (f) inhibit the formation of coke in the total product or in the crude feed during contact; (g) the crude product has maximum 0.05 grams, maximum 0.03 grams, maximum 0.01 grams, or maximum 0.003 grams of coke per gram of crude product; (h) in such a way that at least a fraction of the inorganic salt catalyst is semi-liquid or liquid at these contact conditions; (i) in such a way that the raw product has a TAN index of maximum 90% of the TAN index of the crude feed; (j) in such a way that the crude feed has a total Ni / V / Fe content of maximum 90%, maximum 50%, or maximum 10% of the Ni / V / Fe content of the crude feed; (k) so that the raw product has a sulfur content of maximum 90%, maximum 60%, or maximum 30% of the sulfur content of the crude feed; (1) so that the crude product has a maximum nitrogen content of 90%, maximum 70%, maximum 50%, or maximum 10% of the nitrogen content of the crude feed; (m) in such a way that the raw product has a maximum residue content of 30%, maximum 10%, or maximum 5% of the residue content of the crude feed; (n) in such a way that ammonia is co-produced with the crude product; (o) in such a way that the crude product includes methanol, and the method further includes: recovering the methanol from the crude product; combine the recovered methanol with more crude feed to form another mixture of methanol and crude feed; and heating the methanol mixture and crude feed in such a way that the TAN index of the additional crude feed is reduced to less than 1; (p) so that one or more properties of the crude product change in maximum 90% relative to the respective properties or to the crude feed; (q) such that a catalyst concentration in the contact zone is in the range of 1-60 grams of the total catalyst per 100 grams of crude feed; or (r) in such a way that the hydrogen feed is added to "the feed of crude oil before or during the contacting In addition, the invention provides in some embodiments, in combination with one or more methods or compositions in accordance with the invention, the contact conditions with the following characteristics: (a) mixing the inorganic salt catalyst with the crude feed at a temperature below 500 ° C, where the inorganic salt catalyst is substantially insoluble in the crude feed (b) stir the inorganic catalyst in the crude feed, or (c) contact the raw feed with an inorganic salt catalyst in the presence of water or steam to give a total product that includes the raw product In addition, the invention provides in some embodiments, in combination with one or more methods or compositions according to the invention, a method that includes contacting the crude feed with one or more inorganic salt catalysts and further including: (a) providing steam in the contact zone before or during contact; (b) forming an emulsion with the feed of crude oil and water before contacting the crude feed with an inorganic salt catalyst and the hydrogen feed; (c) vaporizing the crude feed in the contact zone; or (d) contacting the steam with the inorganic salt catalyst to at least partially remove the coke from the surface of the inorganic salt catalyst. In some embodiments, the invention also provides, in combination with one or more methods or compositions of the invention, a method that includes contacting a crude feed with an inorganic salt catalyst to produce a total product in which at least one The fraction of the total product is produced in the form of vapor, and the method also includes the condensation of at least a fraction of the steam at 25 ° C and 0.101 MPa to form the crude product, controlling the contact conditions in such a way that: ) the crude product also includes the components with a distribution of the selected boiling points; or (b) the crude product includes components with selected API gravity. In addition, the invention provides in some embodiments, in combination with one or more methods or compositions according to the invention, a method that includes contacting the crude feed with one or more catalysts and wherein the catalyst or catalysts are not acids. Furthermore, in some embodiments, the invention also provides, in combination with one or more of the methods or compositions according to the invention, a K3Fe10S? 4 catalyst or a transition metal sulfide catalyst: (a) has a total of at least 0.4 grams , at least 0.6 grams, or at least 0.8 grams of at least one transition metal sulfide per gram of K3FeaoS? 4 catalyst or transition metal sulfide catalyst; (b) has an atomic ratio of transition metal to sulfur in the K3Fe? 0S? 4 catalyst or in the transition metal sulfide catalyst of between 0.2 to 20; (c) further includes one or more alkali metals, one or more compounds of one or more alkali metals, or mixtures thereof; (d) further includes one or more alkaline earth metals, one or more compounds of one or more alkaline earth metals, or mixtures thereof; (e) includes - in addition to one or more alkali metals, one or more compounds of one or more alkali metals, or their mixtures, in which the atomic ratio of the transition metals and the sulfur in the K3Fe10S? 4 catalyst or in the Transition metal sulfur catalyst is 0.5 - 2.5 and the atomic ratio of alkali metals and transition metal is more than 0 to 1; (f) further includes one or more alkaline earth metals, one or more alkaline earth metal compounds, or mixtures thereof, an atomic ratio of transition metal and sulfur in the catalyst K3Fe? 0S? or in the transition metal sulfide catalyst between 0.5-2.5; and the atomic ratio of the alkaline earth metal and the transition metal is more than 0 to 1; (g) further includes zinc; (h) further includes KFe2S3; (i) further includes KFeS2; or (j) it is not acidic. Furthermore, in some embodiments, the invention also provides, in combination with one or more of the methods or compositions according to the invention, a K3Fe? 0S? formed in if you: In addition in some embodiments the invention also provides in combination with one or more of the methods or compositions according to the invention, one or more transition metal sulfides in which: (a) includes one or more metals of transition of columns 6-10 of the periodic table, one or more compounds of one or more transition metals of columns 6 to 10, or mixtures thereof; (b) includes one or more iron sulfides; (c) includes FeS; (d) includes FeS2; (e) includes a mixture of iron sulphides, in which the iron sulphides are represented by the Peji-b) S formula, b being in the range of 0 to 0.17; (f) further includes K3Fe? 0S? 4 after contact with the crude feed; (g) at least one of the transition metals of one or more transition metal sulfides is iron; or (h) are deposited on a support, and the transition metal sulfide catalyst has maximum 0.25 grams of total support per 100 grams of catalyst. In some embodiments, the invention also provides, in combination with one or more methods or compositions of the invention, a method for forming a transition metal sulfide catalyst composition, the method is to mix a transition metal oxide and a metal salt to form a mixture of metal salt and transition metal oxide; reacting the mixture of metal salt and transition metal oxide with hydrogen to form an intermediate; and the reaction of the intermediate with sulfur in the presence of one or more hydrocarbons to produce a transition metal sulfide catalyst: (a) the metal salt includes alkali metal carbonate; (b) further includes dispersing the intermediate in one or more liquid hydrocarbons while reacting with sulfur; (c) where one or more of the hydrocarbons have boiling points of at least 100 ° C; (d) where one or more hydrocarbons are GOV, xylene, or mixtures thereof; (e) wherein the mixture of the transition metal oxide and the metal salt includes: mixing the transition metal oxide and the metal salt in the presence of deionized water to form a wet paste; drying the wet paste at a temperature in the range of 150-250 ° C; and calcining the dried pasta at a temperature in the range of 300-600 ° C; (f) wherein the reaction of the intermediate with sulfur includes heating the intermediate in the presence of at least one of the hydrocarbons at a temperature in the range of 240-350 ° C; or (g) which further includes contacting the catalyst composition with a crude feed including sulfur and a hydrogen feed. Furthermore, in some embodiments, the invention also provides, in combination with one or more of the methods or compositions according to the invention, an inorganic salt catalyst with the following characteristics: (a) one or more alkali metal carbonates, one or more carbonates of alkaline earth metals, or their mixtures; (b) one or more alkali metal hydroxides, one or more alkaline earth metal hydroxides, or mixtures thereof; (c) one or more alkali metal hydrides, one or more alkaline earth metals, or mixtures thereof; (d) one or more sulfides of one or more alkali metals, one or more sulfides of one or more alkaline earth metals, or mixtures thereof; (e) one or more amides of one or more alkali metals, one or more amides of one or more alkaline earth metals, or mixtures thereof; (f) one or more metals of columns 6 to 10 of the periodic table, one or more compounds of one or more metals of columns 6 to of the periodic table, or their mixtures; (g) one or more inorganic metal salts, in which at least one of the salts - Inorganic metal generates a hydride during the use of the catalyst; (h) sodium, potassium, rubidium, cesium, or mixtures thereof; (i) calcium or magnesium; (j) a mixture of a sodium salt and potassium salt and the potassium salt includes potassium carbonate, potassium hydroxide, potassium hydride, or mixtures thereof, and the sodium salt includes sodium carbonate, sodium hydroxide, sodium hydride, or its mixtures; or (k) the mixtures thereof.

In addition, in some embodiments, the invention also provides, in combination with one or more of the methods or compositions according to the invention, an inorganic salt catalyst which includes alkali metals in which: (a) the atomic ratio of alkali metal with an atomic number of at least 11 and an alkali metal with an atomic number greater than 11 is in the range of 0.1 to 4, (b) at least two of the alkali metals are sodium and potassium and the atomic ratio of sodium and potassium is from 0.1 to 4; (c) at least three of the alkali metals are sodium, potassium, rubidium, and each of the atomic ratios of sodium and potassium, sodium and rubidium, and potassium and rubidium are 0.1 to 5; (d) at least three of the alkali metals are sodium, potassium, and cesium, and each of the atomic ratios of sodium and potassium, sodium and cesium, potassium, and cesium are from 0.1 to 5; (e) at least three of the alkali metals are potassium, cesium, rubidium, and each of the atomic ratios of potassium and cesium, potassium and rubidium, and cesium and rubidium are from 0.1 to 5. In addition, in some embodiments, the invention is also provides in combination with one or more of the methods or compositions according to the invention, an inorganic salt catalyst including a support; and: (a) the support includes zirconia oxide, calcium oxide, magnesium oxide, titanium oxide, hydrotalcite, alumina, germanium, iron oxide, nickel oxide, zinc oxide, cadmium oxide, antimony oxide, ~~ or their mixtures; or (b) are incorporated into the support: one or more metals of columns 6 to 10 of the periodic table, one or more compounds of one or more metals from columns 6 to 10 of the periodic table; one or more alkali metal carbonates, one or more alkali metal hydroxides, one or more alkali metal hydrides, one or more alkaline earth metal carbonates, one or more alkaline earth metal hydroxides, one or more alkaline earth metal hydrides or mixtures of the same. In addition, the invention provides in some embodiments, in combination with one or more methods or compositions according to the invention, a method that includes contacting the crude feed with inorganic salt catalyst which includes: (a) the catalytic activity of the Inorganic salt catalyst remains substantially unchanged in the presence of sulfur; or (b) the inorganic salt catalyst is added continuously to the crude feed. Furthermore, in some embodiments, the invention also provides, in combination with one or more of the methods or compositions according to the invention, an inorganic salt catalyst with the following characteristics: (a) an increase in gas emitted in the TAP temperature range, and the gas emitted includes water vapor and / or carbon dioxide; (b) a heat transition in a temperature range between 200-500 ° C, 250-450 ° C, or 300-400 ° C, as determined by differential calorimetry scanning, and at a heating rate of 10 ° C per minute; (c) a DSC temperature in the range between 200-500 ° C, or 250-450 ° C; (d) at a temperature of at least 100 ° C, an X-ray diffraction pattern that is broader than the X-ray diffraction pattern of inorganic salt catalysts below 100 ° C; or (e) after conditioning, the ionic conductivity, at 300 ° C, is lower than the ionic conductivity of the inorganic salt catalyst before conditioning. In some modalities, the invention also provides, in combination with one or more methods or compositions of the invention, an inorganic salt catalyst having an increase in emission in a temperature range, determined by TAP, and the contact conditions are also controlled in a controlled manner. such that the contact temperature: (a) is above Tx, with Tx being 30 ° C, 20 ° C, or 10 ° C below the TAP temperature of the inorganic salt catalyst; (b) at or above the TAP temperature; or (c) at least the TAP temperature of the inorganic salt catalyst. In addition, in some embodiments, the invention also provides, in combination with one or more of the methods or compositions according to the invention, an inorganic salt catalyst having the following characteristics: (a) in a liquid or semi-liquid state at least at the TAP temperature of the inorganic salt catalyst, and the inorganic salt catalyst is substantially insoluble in the crude feed at least at the TAP temperature, the TAP temperature is the minimum temperature at which the inorganic salt catalyst has an increase in gas emitted; b) is a mixture of a liquid phase and a solid phase at a temperature of 50 ° C to 500 ° C; or (c) at least one of the two inorganic salts have a DSC temperature above 500 ° C. In some embodiments, the invention also provides, in combination with one or more methods or compositions of the invention, an inorganic salt catalyst which, when analyzed in the form of a particle that can pass through a 1000 micron filter, deforms under the action of gravity or at a pressure of at least 0.007 MPa when heated to a temperature of at least 300 ° C, such that the inorganic salt catalyst is transformed from a first form to a second form, and the The second form is unable to return to the first form when the inorganic salt catalyst is cooled to 20 ° C. Furthermore, in some embodiments, the invention also provides in combination with one or more of the methods or compositions according to the invention, an inorganic salt catalyst having the following compounds per gram of inorganic salt catalyst: (a) maximum 0.01 grams of lithium, or lithium compounds, calculated as lithium weight; (b) maximum 0.001 grams of halide, calculated as weight of halogen; or (c) maximum 0.001 grams of crystalline oxide compounds. In some embodiments, the invention also provides, in combination with one or more of the methods or compositions of the invention, the total product having at least 0.8 grams of crude product per gram of total product. In addition, in some embodiments, the invention also provides, in combination with one or more of the methods or compositions according to the invention, a composition of crude product: (a) with maximum 0.003 grams, maximum 0.02 grams, maximum 0.01 grams, maximum 0.05 grams , maximum 0.001 grams, from 0.000001 - 0.1 grams, 0.00001 - 0.05 grams, or 0. 0001 - 0.03 grams of waste per gram of crude product; (b) has from 0 grams to 0.05 grams, 0.00001 - 0.03 grams, or 0. 0001 - 0.01 grams of coke per gram of crude product; (c) has an olefin content of at least 10% more than the olefin content of the crude feed; (d) has more than 0 grams, but less than 0.01 grams of inorganic salt catalyst per gram of crude product, as determined by mass balance; (e) has at least 0.1 grams, of 0.00001-0.99 grams, of 0.04 - 0.9 grams of 0.6 - 0.8 grams of GOV per gram of raw product; (f) includes GOV and the GOV has at least 0.3 grams of aromatics per gram of GOV; (g) has 0.001 grams or 0.1 - 0.5 grams of distillate; (h) has an atomic ratio of H / C of maximum 1.4; (i) has an atomic ratio of H / C of 90-110% of the H / C ratio of the crude feed; (j) it has a content of monocyclic aromatics of at least 10% more than the content of monoalkylaromatic compounds of the crude feed; (k) has a content of monocyclic aromatic compounds including xylenes, ethylbenzene or ethylbenzene compounds; (1) contains, per gram of crude product, maximum 0.1 grams of benzene, 0.05 - 0.15 grams of toluene, 0.3-0.9 grams of meta-xylene, 0.5 - 0.15 grams of ortho-xylene, and 0.2 - 0.6 grams of para-xylene; (m) has at least 0.0001 grams or 0.01 - 0.5 grams of diesel; (n) includes diesel, and diesel contains at least 0.3 grams of aromatics per gram of diesel; (o) has at least 0.001 grams, more than 0 to 0.7 grams, or 0.001 - 0.5 grams of kerosene; (p) includes kerosene, and kerosene has at least 0.2 grams or at least 0.5 grams of aromatics per gram of kerosene and / or a freezing point at a temperature of -30 ° C maximum, -40 ° C maximum, or maximum -50 ° C; (q) has at least 0.001 grams or at least 0.5 grams of naphtha; (r) includes naphtha, and naphtha has maximum 0.01 grams, maximum 0.05 grams, or maximum 0.002 grams of benzene per gram of naphtha, an octane number of at least 70, at least 80, or at least 90, or isoparaffins and normal paraffins with a weight ratio of isoparaffins and normal paraffins in naphtha of maximum 1.4; or (s) has a volume that is at least 10% greater than the volume of the crude feed. In addition, the invention provides in some embodiments, in combination with one or more methods or compositions according to the invention, the method that includes contacting the crude feed with one or more catalysts to obtain a total product including a crude product, the method also includes: (a) combining the crude product with the crude oil that is the same or different from the crude feed to form a suitable mixture for transportation; (b) combine the crude product with the crude oil that is the same or different from the crude feed to form a suitable mixture for the treatment facilities; (c) fractionating the crude product; (d) fractionating the crude product into one or more distilled fractions, and producing the transport fuel from at least one of the distilled fractions; or (e) when the catalyst is a transition metal sulfide catalyst, treating it to recover the metals of the transition metal sulfide catalyst. Furthermore, in some embodiments, the invention also provides, in combination with one or more of the methods or compositions according to the invention, a crude product containing per gram of crude product: (a) at least 0.001 grams of GOV, and the GOV has at least 0.3 grams of aromatics per grams of GOV; (b) at least 0.001 grams of diesel, and diesel has at least 0.3 grams of aromatics per gram of diesel; (c) at least 0.001 grams of naphtha, and naphtha: contains maximum 0.5 grams of benzene per gram of naphtha, an octane number of at least 70, or iso-paraffins and n-paraffins with a weight distribution of isoparaffins and n- paraffins of maximum 1.4; (d) a total of at least 0.001 grams of a mixture of components that have a boiling range distribution of maximum 204 ° C (400 ° F) and the mixture has a maximum 0.15 grams of olefins per gram of mixture; (e) a weight ratio of atomic hydrogen and atomic carbon in the composition of maximum 1.75, or maximum 1.8; (f) at least 0.001 grams of kerosene, and kerosene contains: at least 0.5 grams of aromatic compounds per gram of kerosene or with a freezing point at a maximum temperature of -30 ° C; (g) from 0.09 to 0.13 grams of atomic hydrogen per gram of composition; (h) non-condensable hydrocarbon gases and naphtha, which when combined, has a maximum of 0.15 grams of olefins per gram of combined non-condensable hydrocarbon gases and naphtha; (i) non-condensable hydrocarbon gases and naphtha, which when combined, include isoparaffins and n-paraffins with a weight ratio of isoparaffins and n-paraffins in combined non-condensable hydrocarbon and naphtha gases of maximum 1.4; (j) hydrocarbons with a carbon number of up to 3 including: olefins and paraffins with carbon numbers of 2 (C2) and 3 (C3), and weight ratios of the combined C2 and C3 olefins and the C2 paraffins and C3 combined is maximum 0.3; olefins and paraffins with a carbon number of 2 (C2), the weight ratio of C2 olefins and C2 paraffins being maximum 0.2; or the olefins and paraffins with a carbon number of 3 (C3), the weight ratio of the C3 olefins and the C3 paraffins is maximum 0.3; (k) a butadiene content of at least 0.005 grams; (1) an API gravity in a range of 15 to 30 to 15.5 ° C; (m) has maximum 0.00001 grams of Ni / V / total Fe per gram of composition; (n) a content of hydrocarbon paraffins with a boiling range of maximum 204 ° C between 0.7 - 0.98 grams; (o) hydrocarbons with a boiling range distribution of maximum 204 ° C containing, per gram of olefins, hydrocarbons with a boiling range of maximum 204 ° C, from 0.001 - 0.5 grams of olefins (p) hydrocarbons with a range of boiling at maximum 204 ° C including olefins, and the olefins have at least 0.001 grams of terminal olefins per gram of olefins; (q) hydrocarbons with a boiling range of maximum 204 ° C including olefins, and olefins have a mole ratio of olefin endings and internal olefins of at least 0.4; or (r) of 0.001 - 0.5 grams of olefins per gram of hydrocarbons in a boiling range distribution of 20 ° C and 204 ° C. Furthermore, in some embodiments, the invention also provides, in combination with one or more of the methods or compositions according to the invention, a crude product composition that includes one of the catalysts that includes one or more alkali metals in which: (a) at least one of the alkali metals is potassium, rubidium; or cesium, or its mixtures; or (b) at least one of the catalysts further includes a transition metal, a transition metal sulfide or bartonite. In other embodiments, the characteristics of some of the specific embodiments of the invention may be combined with the embodiments of other aspects of the invention. For example, the characteristics of a modality can be combined with the characteristics of other modalities. In other embodiments, the raw products can be obtained by any of the methods and systems described herein. In other embodiments, other features may be added to the specific embodiments described herein. BRIEF DESCRIPTION OF THE FIGURES The advantages of the present invention will be apparent to the experts in the field with the reading of the following detailed description and with reference to the attached figures in which: Figure 1 is a schematic diagram of a modality of a Contact system for the contact of the crude feed with a hydrogen feed in the presence of one or more catalysts to obtain the total product. Figure 2 is a schematic diagram of one embodiment of a contact system for contacting the crude feed with a hydrogen feed in the presence of one or more catalysts to obtain the total product. Figure 3 is a diagram of one embodiment of a separation zone in combination with a contact system. Figure 4 is a diagram of one embodiment of a mixing zone in combination with a contact system. Figure 5 is a diagram of one embodiment of a combination of a separation zone, a contact system and a mixing zone.

Figure 6 is a diagram of one modality of the multiple contact system. Figure 7 is a diagram of one embodiment of the ionic conductivity measuring system. Figure - 8 is a table of the properties of the crude feed and of the properties of the crude products obtained from the contact modalities of the crude feed with a transition metal sulfide catalyst. Figure 9 is a table of the crude feed compositions and the non-condensable hydrocarbon compositions obtained from the contact modes of the crude feed with a transition metal sulfide catalyst. Figure 10 is a table of the properties of the crude feed and of the compositions of the crude products obtained from the contact modalities of the crude feed with a transition metal sulfide catalyst. Figure 11 is a graphical representation of the log 10 curves of ion streams of gases emitted from inorganic salt catalysts as a function of temperature, determined by TAP. Figure 12 is a graphical representation of the log curves of the strength of inorganic salt catalysts and of an inorganic salt relative to potassium carbonate resistance versus temperature. Figure 13 is a graphical representation of the log curves of the catalyst resistance Na2C03 / K2C03 / Rb2C03 relative to potassium carbonate resistance versus temperature. Figure 14 is a graphical representation of the percentage by weight of the coke, liquid hydrocarbons, and gas versus various charges of hydrogen produced from the contact modes of the crude feed with the inorganic salt catalyst. Figure 15 is a graphical representation of the percentage by weight versus the number of carbons of the crude products produced from the contact modes of the crude feed with the inorganic salt catalyst. Figure 16 is the tabulation of the components produced in the embodiments that describe the contact of the crude feed with an inorganic salt catalyst, a metal salt, or silicon carbide. Various modifications to the invention can be made and various alternative forms thereof are accepted, specific aspects thereof are shown by way of example in the figures and will be described in detail herein. The figures may not be to scale. It should be understood that the figures and the detailed description of the invention do not limit the scope of the invention to the form presented, but on the contrary, it is intended to cover all the modifications, equivalences and alternative forms thereof that are within the spirit and of the scope of the present invention. DETAILED DESCRIPTION OF THE INVENTION In the present description certain embodiments of the inventions are described in more detail. The terms used herein are defined as follows. "Alkali metals" describe 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 their mixtures. "Alkaline earth metals" describe one or more metals of column 2 of the periodic table, one or more compounds of one or more metals of column 2 of the periodic table, or their mixtures. "AMU" is the unit of atomic mass. "ASTM" is the American Standard Testing and Materials. The "C5 asphaltenes" are insoluble asphaltenes in pentane. The content of asphaltenes C5 is that determined with the ASTM D2007 method. The percentage of atomic hydrogen and the percentage of atomic carbon of the crude feed, crude product, naphtha, kerosene, diesel and GOV are those determined by the ASTM D5291 method. "Gravity API" is API gravity at 15.5 ° C. It is determined by the method ASTM D6822. "Bitumen" is a type of crude produced or obtained from a hydrocarbon formation. The boiling range distributions of the crude feed or of the total product are those determined by the ASTM D5307 method unless otherwise indicated. The content of the hydrocarbon components, for example, of paraffins, isoparaffins, olefins, nafteños and aromatics are those that are determined by the method ASTM D6730. The content of aromatic compounds in diesel and GOV is determined by the method IP 368/90. The content of aromatic compounds in kerosene is that determined by the method ASTM D5186. "Bronsted-Lowry acidity" is a molecular form that is capable of donating one proton to another molecular form. "The basis of Bronsted-Lowry" is the molecular form that is capable of accepting protons of another molecular form. Examples of Bronsted-Lowry bases include hydroxide (OH), water (H20), carboxylate (RC02-), halide (Br-, Cl ~, F ~,? ~), Bisulfate (HS04 ~~), and sulfate ( S042_). "Carbon number" is the total number of carbon atoms in a molecule. "Coke" are the solids that contain carbonaceous solids that do not vaporize under the conditions of the process. The coke content is the one determined by the mass balance. The coke weight is the total weight of solids minus the total weight of input catalysts. "Content" means the weight of a component in a substrate (e.g., a load of crude, a total product, or a crude product) expressed as a weight fraction or weight percent based on the total weight of the substrate.

"Wtppm" are parts per million by weight. "Diesel" are hydrocarbons with a boiling range distribution between 260 ° C (500 - 650 ° F) to 0.101 MPa. Diesel content is that determined by the ASTM D2887 method. "Distillate" are hydrocarbons with a boiling range distribution between 343 ° C (400 - 650 ° F) to 0.101 MPa. The content of the distillate is that determined by the ASTM D2887 method. The distillate may include kerosene and diesel. "DSC" describes the differential scanning calorimetry. "Freezing point" is the temperature at which the formation of crystalline particles in a liquid takes place.

The freezing point is determined by the ASTM method D2386. "GC / MS" is gas chromatography combined with mass spectrometry. "Rigid base" are the anions described by Pearson in Journal of American Chemical Society, 1963, 85, p. 3533. "H / C" describes the weight ratio of atomic hydrogen to atomic carbon. H / C is the one that is determined from the measured values for the percentage of weight of hydrogen and percentage by weight of carbon by the method ASTM D5291. "Heteroatoms" 'are oxygen, nitrogen or sulfur in the molecular structure of a hydrocarbon. The heteroatom content is determined by the ASTM methods E385 for oxygen, D5762 for nitrogen and D4294 for sulfur. "Hydrogen feed" is hydrogen, or a compound, or compounds that react in the presence of a crude charge and the catalyst to provide hydrogen to one or more crude feed compounds. A hydrogen feed may include, but is not limited to, hydrocarbons (for example Cl to C6 hydrocarbons such as methane, ethane, propane, butane, pentane and naphtha), water, or mixtures thereof. A mass balance can be made to evaluate the net concentration of hydrogen added to the crude feed compounds. "Inorganic salt" is a compound that includes cation and metal anion. "IP" is the Petroleum Institute, now known as the Energy Institute of London, United Kingdom. "Isoparaffins" are saturated branched chain hydrocarbons. "Kerosene" are hydrocarbons with a boiling range distribution between 204 ° C and 260 ° C (400 - 500 ° F) at 0.101 MPa. Kerosene content is what is determined by the ASTM D2887 method. "Lewis acidity" is a compound or material with the ability to accept one or more electrons from another compound. "Base Lewis" is a compound or material with the ability to donate one or more electrons to another compound. "Light hydrocarbons" are hydrocarbons with a carbon number in the range of 1 to 6. "Liquid mixture" is a composition that includes one or more compounds that are liquid at standard temperatures and pressures (25 ° C, 0.101 MPa, indices referred to herein as "STP"), or a composition that includes the combination of one or more compounds that are liquid to STP with one or more compounds that are solid to STP. The content of micro carbon residues ("MCR") means the amount of carbon residues that remain after the evaporation and pyrolysis of the substrate. The MCR content is the one determined by the ASTM D4530 method. "Naphtha" are hydrocarbons with a boiling range distribution between 38 ° C and 204 ° C (100 - 400 ° F) at 0.101 MPa. Diesel content is that determined by the ASTM D2887 method. "Ni / V / FE" is nickel, vanadium, iron or combinations thereof. "Ni / V / Fe content" is the Ni / V / Fe content of a substrate. The Ni / V / Fe content is determined by the ASTM D5863 method. "Nm3 / m3" are the normal cubic meters per cubic meter of gas in the crude cargo. "Non-acid" are the properties of the Lewis base or Bronsted-Lowry. "Non-condensable gas" are the components and mixtures of components that are gases at temperatures and standard pressure (25 ° C, 0.101 MPa, referred to hereinafter as "STP"). "n-paraffins" are straight chain saturated hydrocarbons. "Octane Number" describes a numerical representation calculated in the anti-knock properties of a combustion engine as compared to the standard reference fuel. The calculated octane number of naphtha is that determined by the ASTM D6730 method. "Olefins" are compounds with non-aromatic carbon carbon double bonds. The types of olefins include, in a non-limited way, cis, trans, terminal, internal, branched and linear olefins. The "periodic table" refers to the periodic table specified by the International Union of Pure and Applied Chemistry (IUPAC), November 2003. "Polyaromatic compounds" are 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" means components whose boiling range is above 538 ° C (1000 °). F) at 0.101 MPa as determined by ASTM D5307 method "Semiliquid" is the phase of a substance having both properties of a liquid phase and solid phase substance Examples of semiliquid inorganic salt catalysts include a suspension or a phase that has the consistency for example of molasses, dough or toothpaste. "SCFB" is the standard cubic foot of gas per barrel of crude feed. "Superbase" is the material that can deprotonate hydrocarbons such such as paraffins and olefins under reaction conditions. "TAN" is the total acid number expressed as milligrams ("mg") of KOH per gram ("g") of sample. all ASTM D664. "TAP" is the Temporary Product Analysis. "TMS" is the transition metal sulfide. "GOV" are the components with distribution of the boiling range between 343 ° C and 538 ° C (650 - 1000 ° F) at 0.101 MPa. Content of the GOV is that determined by the method ASTM D2887. In the context of this application, it should be understood that if the value obtained for a property of the composition tested is outside the limits of the test method, it can be recalibrated to study said property. It should be understood that other standardized test methods that are equivalent to the referenced test methods can be used. The crudes can be produced or distilled from the hydrocarbon formations and then stabilized. Generally, the crudes are in solid, semi-solid or liquid state. Crudes may include oil. The stabilization may include, but is not limited to, the removal of non-condensable gases, water, salts or combinations thereof, from the crude to form a stabilized crude. This stabilization can usually take place at or near the production or distillation site.

Stabilized crudes generally have not been distilled, in whole or in fractions, in the treatment facilities, to produce multiple components with specific boiling point distributions (eg, naphtha, distillates, GOV, or lubricating oils). ). Distillation includes, but is not limited to, atmospheric distillation methods or vacuum distillation methods. Unblemished or unfractionated stabilized crudes include components that have a carbon number greater than 4 in amounts of at least 0.5 grams of the components per gram of crude. Examples of stabilized crudes include total crudes, fractionated crudes, desalted crudes, desalted crudes and fractions, or combinations thereof. "Fractionated crude" is a crude that has been treated in such a way that at least some of the components with boiling points below 35 ° C at 0.101 MPa have been removed. In general, fractionated crudes have a maximum content of 0.1 g, maximum 0.05 grams, or maximum 0.02 grams of these components per gram of fractionated crude. Some stabilized crudes have properties such that stabilized crudes are transported to conventional treatment facilities by transport vehicles (eg pipes, trucks or ships). Other crudes have one or more unsuitable properties that make them disadvantageous. The disadvantageous crudes may not be suitable for the transport vehicle or for the treatment facilities, which makes the disadvantageous crude have low economic value. The economic value can be such that the production, transport or treatment of the reserve that includes the crude disadvantage is considered very expensive. The properties of the disadvantageous crudes include, but are not limited to: a) a TAN index of at least 0.5; b) viscosity of at least 0.2 Pa.s; c) API gravity of maximum 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 heteroatom 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 oil; g) an asphaltene content of at least 0.04 grams of asphaltenes per gram of crude; h) an MCR content of at least 0.02 grams of MCR per gram of crude; or i) combinations thereof. In some embodiments, disadvantageous crude oil may include, per gram of disadvantageous 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 modalities, the unfavorable crude has 0.2 - 0.99 grams, 0.3-0.9 grams, or 0.4 - 0.7 grams of residue per gram of unfavorable crude. In some embodiments, the disadvantageous crude may include, per gram of disadvantageous crude, at least 0.001 grams of sulfur, at least 0.005 grams of sulfur, at least 0.01 grams of sulfur, or at least 0.02 grams of sulfur. The disadvantageous crudes may include. a mixture of hydrocarbons with a range of boiling points. Unfavorable crudes may include, per gram of disadvantageous 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 200 ° C and 300 ° 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 300 ° C and 400 ° 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 400 ° C and 700 ° C to 0.101 MPa, or combinations thereof. Some disadvantageous crudes may include, per gram, disadvantageous crude, at least 0.001 grams, at least 0.005 grams, or at least 0.01 grams of hydrocarbons with boiling points in the range of maximum 200 ° C to 0.101 MPa., in addition to other components with higher boiling ranges. In general, unfavorable crude oil has, per gram of unfavorable crude, a content of said hydrocarbons of maximum 0.2 grams or maximum 0.1 grams. • In certain modalities, disadvantageous crude oil may include, per gram thereof, up to 0.9 grams, or up to 0.99 grams of hydrocarbons with boiling ranges of at least 300 ° C. In certain embodiments, disadvantageous crudes may also include, per gram of disadvantageous crude, at least 0.001 grams of hydrocarbons with a boiling range distribution of at least 650 ° C. In certain modalities, the disadvantageous crude oil may include, per gram thereof, up to 0.9 grams, or up to 0.99 grams of hydrocarbons with a boiling range between 300 ° C and 1000 ° C.

Among the disadvantageous crudes that can be treated with the processes described herein, include, without limitation, the crude obtained from the following countries and the regions of the countries: Canadian Alberta, Orinoco in Venezuela, Southern California In U.S.A. and North Slope Alaska, Campeche Bay in Mexico, San Jorge Basin in Argentina, Santos and Campos Basin in Brazil, Bohai Gulf in China, Karamay in China, Zagros in Iraq, Caspian Sea in Kazakhstan, High Seas in Nigeria , North Sea of the United Kingdom, northwest of Madagascar, Ornan, and Schoonebek in the Netherlands. The treatment of disadvantageous crudes can improve the properties of disadvantageous crudes so that they become acceptable for transport or for treatment. The crude or a disadvantageous crude that is treated herein is described as "crude feed". The crude feed may be fractionated, as described herein. The crude product that is obtained from the crude feed treatment, as described herein, is generally suitable for being transported or for refining. The properties of the crude product produced as described herein are more similar to the corresponding properties of the Intermediate West Texas crude than of the crude feed, or more similar to the corresponding properties of the Brent crude, than of the crude feed, which improves the economic value in comparison with the economic value of the crude feed. This crude product can be refined with less pretreatment or without it, which improves the efficiency of the refineries. The pretreatment may include desulfurization, demetallization or atmospheric distillation to remove impurities from the crude product. The methods for contacting a crude feed according to the inventions are described herein. In addition, the modalities to generate products with different concentrations of naphtha, kerosene, diesel or GOV are described that are not generally produced in conventional processes. The crude feed may be contacted with a hydrogen feed in the presence of one or more catalysts in a contact zone or in combinations of two or more contact zones. In certain embodiments, the hydrogen feed in situ is generated. The generation of the hydrogen feed in situ can include the reaction of at least one fraction of the crude feed with inorganic salt catalyst at temperatures in the range of 200-500 ° C or 300-400 ° C to form hydrogen or light hydrocarbons . The generation of hydrogen in situ can include the reaction of at least one fraction of the inorganic salt catalyst including, for example, alkali metal format. The total product generally includes gas, vapor, liquids, or their mixtures produced during contact. The total product includes the product consisting of a liquid mixture to STP, and in certain embodiments, to hydrocarbons that are not condensable to STP. In certain modalities, the total product or the crude product may include solids (such as solids or inorganic coke). In certain embodiments, solids can be transported in the liquid or in the vapor produced during contact. The contact zone generally includes a reactor, a reactor fraction, or multiple portions of a reactor, or multiple reactors. Reactors can be used for the contact of a crude feed with a hydrogen feed in the presence of a catalyst that includes a packed bed reactor, a fixed bed reactor, a continuous stirred tank reactor (CSTR, for its acronym in English ), a vaporization reactor, a plug flow reactor, and a liquid / liquid contactor. Examples of CSTR include a fluidized bed reactor and an ebullient bed reactor. Contact conditions usually include temperature, pressure, crude feed flow, total product flow, residence time, hydrogen feed flow, or combinations thereof. The contact conditions can be controlled to produce a crude product with specific properties. The contact temperatures can be 200 - 800 ° C, 300 - 700 ° C, or 400 - 600 ° C. In embodiments in which the hydrogen feed is added in the form of a gas (for example, hydrogen gas, methane or ethane), the ratio of the gas and the crude feed is usually 1-16, 100 Nm3 / m3, 2 - 8000 Nm3 / m3, 3 - 4000 Nm3 / m3, or 5 - 300 Nm3 / m3. The pressure in the contact zone can be 0.1-20 MPa, 1-16 MPa, 2-10 MPa, or 4-8 MPa. In some embodiments in which steam is added, the ratio of steam and crude feed is in the range of 0.01 to 3 kg, 0.03 to 2.5 kg, or 0.1 to 1 kg of steam, per kilogram of crude feed. The circulation speed of the crude feed may be sufficient to maintain the volume of the crude feed in the contact zone of at least 10%, at least 50%, or at least 90% of the total volume of the contact zone . In general, the volume of crude feed in the contact zone is 40%, 60%, or 80% of the total volume of the contact area. In certain embodiments, contact can be made in the presence of another gas, for example, argon, nitrogen, methane, ethane, propanes, butanes, propenes, butenes, or combinations thereof. Figure 1 is a schematic diagram of one embodiment of a contact system 100 used to produce the total product as steam. The crude feed leaves the crude feed supply 101 and enters the contact zone 102 through the conduit 104. The amount of catalyst used in the contact zone can be from 1 to 100 grams, 2 to 80 grams, or 4. to 60 grams, per 100 grams of crude feed in the contact area. In certain embodiments, a diluent may be added to the crude feed to decrease the viscosity of the crude feed. In certain embodiments, the crude feed enters the bottom of the contact zone fraction 102 through conduit 104. In certain embodiments, the crude feed may be heated to a temperature of at least 100 ° C or at least 300 ° C. before introducing the crude feed the contact zone 102, or during said introduction. In general, the crude feed can be heated to a temperature in the range of 100 - 500 ° C or 200 - 400 ° C. In certain embodiments, the catalyst is combined with the crude feed and transferred to the contact zone 102. The crude feed mixture and catalyst can be heated to a temperature of at least 100 ° C or at least 300 ° C before introduce it into the contact zone 102. In general, the crude feed can be heated to a temperature between 200 - 500 ° C or 300 - 400 ° C. In certain embodiments, the crude feed mixture and catalyst is a suspension. In certain modalities, the TAN index of the crude feed can be reduced before introducing the crude feed to the contact zone. For example, when the catalyst mixture and the crude feed are heated to a temperature of between 100-400 ° C or 200-300 ° C, the alkali salts of acidic components can be formed in the crude feed. The formation of these alkaline salts can remove some acid components from the crude feed to lower the TAN index of the crude feed. In some embodiments, the crude feed is added continuously to the contact zone 102. Mixing the contact zone 102 may be sufficient to inhibit the separation of the catalyst from the catalyst mixture and the crude feed. In certain embodiments, at least a fraction of the catalyst can be removed from the contact zone 102, and in some embodiments, said catalysts are regenerated and reused. In certain modalities, fresh catalysts can be added to the contact zone 102 during the reaction process. In certain embodiments, the crude feed mixture with the inorganic salt catalyst or the crude feed is introduced into the contact zone in the form of an emulsion. The emulsion can be prepared by combining a mixture of water and inorganic salt catalysts with a mixture of surfactant and the crude feed. In certain embodiments, the stabilizer is added to the emulsion. The emulsion remains stable for at least 2 days, at least 4 days, or at least 7 days. In general, the emulsion can remain stable for 30, 10, 5 or 3 days. Surfactants include, but are not limited to, organic polycarboxylic acids (Tenax 2010; MeadWestvaco Specialty Product Group; Charleston, South Carolina, USA), C2i dicarboxylic fatty acids (DIACID 1550; MeadWestvaco Specialty Product Group), petroleum sulfonates (Hostapur SAS 30; Clarient Corporation, Charlotte, South Carolina, USA), Agent Tergital Surfactant NP-40 (Union Carbide; Danbury, Connecticut, USA), or mixtures thereof. In a non-limited way, the stabilizers include diethylamine (Aldrich Chemical Co., Milwaukee, Wisconsin, USA) or monoethanolamine (J.T. Baker, Phillipsburg, New Jersey, USA). The reflux conduit 106 may be coupled with the conduit 108 and the conduit 104. In certain embodiments, the reflux conduit 106 may enter directly or exit the contact zone 102. The reflux conduit 106 may include the flow control 110. The flow control valve 110 may allow recycling at least a fraction of the material of the conduit 108 to the conduit 104 or to the contact zone 102. In certain embodiments, the condensing unit may be located in the conduit 108. to allow at least a fraction of the material to condense and recycle to the contact zone 102. In certain embodiments, the recycling conduit 106 may be a gas recycling line. The flow control valves 110 and 110 'can be used to control the flow from and to the contact zone 102, such that a constant volume of liquid is maintained in the contact zone. In certain embodiments, a range of substantially selected liquid volume can be maintained in the contact zone 102. The feed volume in the contact zone 102 can be monitored using standard instrumentation. The gas inlet port 112 can be used to allow the addition of the supply of hydrogen or additional gases to the crude feed as it enters the contact zone 102. In certain embodiments, the inlet port of steam 114 can be used to allow direct addition of steam to the contact zone 102. In certain embodiments, an aqueous stream is introduced to the contact zone 102 by the inlet port of. steam 114. In certain embodiments, at least a fraction of the total product is obtained in the form of vapor from the contact zone 102. In certain embodiments the total product is produced in the form of vapor or as a vapor with small concentrations of liquids and solids. from the upper part of the contact zone 102. The steam is transported to the separation zone 116 by the conduit 108. The ratio of hydrogen feed and oil feed in the contact zone 102 or the pressure in the zone of contact may change the control of the liquid phase or vapor phase produced from the top of the contact zone 102. In certain embodiments, the steam produced from the top of the contact zone 102 includes at least 0.5 grams, 0.8 grams , 0.9 grams, or at least 0.97 grams of crude product per gram of crude feed. In certain embodiments, the steam produced from the upper part of the contact zone 102 includes from 0.8 to 0.99, or 0.9 to 0.98 grams of crude product per gram of crude feed. The catalysts or solids used can remain in the contact zone 102 as by-products of the contact process. Solid catalysts or catalysts used may include a feed of residual crude or coke. In the separation unit 116, the steam is cooled and separated from the raw product and gases using standard separation techniques. The crude product leaves the separation unit 116 and enters the raw product receiver 119 through conduit 118. The resulting crude product may be suitable for transport or treatment. The raw product receiver 119 may include one or more pipe lines, one or more storage units, one or more transport containers, or their combinations. In some embodiments, a separate gas (eg, hydrogen, carbon monoxide, carbon dioxide, hydrogen sulfide, or methane) can be transported to other processing units (eg, for use in a fuel cell or a power plant). sulfur recovery) or recycled to the contact zone 102 via line 120. In certain embodiments, solids or liquids transported in the raw product can be removed by standard physical separation methods (eg, filtration, centrifugation, or separation of membranes). Figure 2 describes a contact system 122 for treating a crude feed with one or more catalysts to obtain a total product which may be a liquid, or a liquid combined with gas or solids. The crude feed may enter the contact zone 102 through conduit 104. In some embodiments, the crude feed comes from the crude feed supply. The conduit 104 may include a gas inlet port 112. In some embodiments, the gas inlet port 112 may enter directly into the contact zone 102. In certain embodiments, the steam inlet port 114 may be used to allow the addition of the vapor to the contact zone 102. The crude feed may be contacted with the catalyst in the contact zone 102 to obtain the total product. In some embodiments, the conduit 106 allows at least a fraction of the total product to be recycled to the contact zone 102. The mixture that includes the feed of unreacted crude or the solids and total products leaves the contact zone 102 and enters to the separation zone 124 by the conduit 108. In certain embodiments, the condensation unit (eg, in the conduit 106) may be placed to allow at least a fraction of the mixture in the conduit to condense and recycle to the zone. of contact 102 for further processing. In certain embodiments, the recycling conduit 106 may be a gas recycling line. In certain embodiments, the conduit 108 may include a filter to remove particles from the total product. In the separation zone 124, at least a fraction of the crude product can be separated from the total product or the catalyst. In embodiments in which the total product includes solids, these can be separated from the total product with standard solids separation techniques (e.g., centrifugation, filtration, decanting, membrane separation). The solids include, for example, the combination of catalyst, used catalyst or coke. In some embodiments, a fraction of gases is separated from the total product. In some embodiments, at least a fraction of the total product and the solids can be recycled to the conduit 104 or in some embodiments, to the contact zone 102 through the conduit 126. For example, the recycled fraction can be combined with the crude feed and enter contact zone 102 for further processing. The crude product can leave the separation zone 124 through conduit 128. In certain embodiments, the crude product can be transported to the product raw receiver. In some embodiments, the total product or the crude product may include at least a fraction of the catalyst. The gases transported in the total product or in the raw product can be separated using standard liquid or gas separation techniques, for example, spraying, membrane separation and pressure reduction. In some embodiments, the separated gas is transported to other processing units (eg, for use in a fuel cell, a sulfur recovery plant, other processing units, or combinations thereof) or recycled to the contact zone . In certain embodiments, the separation of at least a fraction of the crude feed is carried out before the crude feed enters the contact zone. Figure 3 is a schematic diagram of an embodiment of the separation zone in combination with a contact system. The contact system 130 can be the contact system 100 or the contact system 122 (shown in FIGS 1 and 2). The crude feed enters the separation zone 132 through line 104. In the separation zone 132, at least a fraction of the crude feed is separated with standard separation techniques to give a separate oil feed and hydrocarbons. The feeding of separated crude can in some embodiments include a mixture of components with a distribution of the boiling point values of at least 100 ° C, or in certain embodiments, a boiling distribution of at least 120 ° C, in some modes a distribution of the boiling range of at least 200 ° C. In general, the feed of separated crude includes a mixture of components with a boiling point distribution of between 100 and 1000 ° C, 120 and 900 ° C, or 200 to 800 ° C. The separated hydrocarbons from the crude feed exit the separation zone 132 through the conduit 134 to be transported to other processing units, treatment facilities, storage facilities, or combinations thereof. At least a fraction of the separated crude feed leaves the separation zone 132 and enters the contact system 130 through the conduit 136 to be further processed to form a crude product, which leaves the contact system 130 through the conduit 138. In certain embodiments, the crude product obtained from the crude feed by any of the methods described herein is mixed with a crude that is the same as or different from the crude feed. For example, the crude product can be combined with the crude having different viscosity which results in a product mixed with a viscosity that is between the viscosity of the crude product and the viscosity of the crude oil. The resulting mixed product may be suitable for transport and / or treatment.

Figure 4 is a schematic diagram of one embodiment of a combination of the mixing zone 140 and the contact system 130. In certain embodiments, at least a fraction of the crude product leaves the contact system 130 through the conduit 138 and enters into the mixing zone 140. In the mixing zone 140, at least a fraction of the crude product is combined with one or more streams of processing (eg, a stream of hydrocarbons produced by the separation of one or more feeds of crude, or naphtha), a crude, a crude feed, or their mixtures, to obtain the mixed product. The process streams, the crude oil feed, or their mixtures are introduced directly into the mixing zone 140 or upstream of said zone through the conduit 142. The mixing system can be located in the mixing zone 140 or nearby to that area. The mixed product may be in accordance with the description of the product. Product descriptions include, but are not limited to, a range or limit of API gravity, TAN index, viscosity, or combinations thereof. The mixed product leaves the mixing zone 140 through the conduit 144 to be transported or processed. In certain embodiments, methanol is generated during the contact process using the catalyst. For example, hydrogen and carbon monoxide can react to form methanol. The recovered methanol may contain dissolved salts, for example, potassium hydroxide. The recovered methanol can be combined with additional crude feed to give the methanol mixture and crude feed. The combination of methanol with crude feed tends to decrease the viscosity of the crude feed. Heating the raw feed mixture and methanol to a maximum of 500 ° C may decrease the TAN index of the crude feed to less than 1. Figure 5 is a diagram of one embodiment of a combination of a separation zone. , a contact system and a mixing zone. The crude feed enters the separation zone 132 through line 104. The crude feed is separated as described above to form a separate crude feed. The separated raw feed enters the contact zone 130 through the conduit 136. The crude product leaves the contact zone 130 and enters the mixing zone 140 through the conduit 138. In the mixing zone 140, they are combined other process and crude streams introduced by conduit 142 with the crude product to form the mixed product. The crude product leaves the mixing zone 140 through line 144.

Figure 6 is a schematic diagram of a multiple contact system 146. The contact system 100 (shown in Figure 1) can be located before the contact system 148. In an alternative embodiment, the positions of the contact systems can be reversed. . The contact system 100 • includes an inorganic salt catalyst. The contact system 148 may include one or more catalysts. The catalyst in the contact system 148 may be an additional inorganic salt catalyst, the transition metal sulfide catalyst, the additional catalysts, or mixtures thereof. The crude feed enters the contact system 100 through line 104, and is brought into contact with the hydrogen feed in the presence of an inorganic salt catalyst to give the total product. The total product includes hydrogen, and in some embodiments, a crude product. The total product can leave the contact system 100 through the conduit 108. The hydrogen generated from the contact of the inorganic salt catalyst with the crude feed can be used as a hydrogen feed for the contact system 148. At least a fraction of the hydrogen generated is transferred to contact system 148 from contact system 100 via line 150. In an alternative mode, the hydrogen generated in this way can be separated or treated, and then transferred to the contact system 148 via line 150. In certain embodiments, the contact system 148 can be part of the contact system 100 such that the hydrogen generated flows directly from the contact system 100 to the contact system 148. In some embodiments, the steam current produced by the contact system 100 may be directly mixed with the crude feed entering the contact system 148. The second feed of crude oil it enters the contact system 148 through the conduit 152. In the contact system 148, the contact of the crude feed with at least a fraction of the hydrogen and the generated catalyst gives rise to the product. In some modalities, the product is the total product. The product leaves the contact system 148 through the conduit 154. In certain embodiments, the system including the contact systems, the contact zones, the separation zones, or the mixing zones, such as those shown in the figures 1-6 can be located at or near the production site that produces unfavorable crude feed. After processing through the catalytic system, the crude feed can be considered as suitable for transport or for use in a refinery process. In certain modalities, the crude product or the mixed product is transported to the refinery or to the treatment facility. The raw product or the mixed product can be processed to obtain commercial products such as transport fuel, heating fuel, lubricants, or chemical compounds. Processing may include distillation or fractional distillation of the crude product or the mixed product to obtain one or more distillation fractions. In some embodiments, the crude product, the mixed product or one or more distilled fractions can be hydrotreated. In some modalities, the total product may include maximum 0.05 grams, maximum 0.03 grams, or maximum 0.01 grams of coke per gram of total product. In certain embodiments, the total product is substantially free of coke (i.e. coke is not detected). In some modalities, the crude product may include maximum 0.05 grams, maximum 0.03 grams, maximum 0.01 grams, maximum 0.005 grams or maximum 0.003 grams of coke per gram of crude product. In certain modalities, the crude product has a coke content in a range of more than 0.05, 0.00001 to 0.03 grams, 0.0001 to 0.01 grams, or 0.001 to 0.005 grams per gram of crude product, or it is not detectable. In some modalities, the crude product has an MCR content of maximum 90%, maximum 80%, maximum 50%, maximum 30%, or maximum 10% of the MCR content of the crude feed. In certain modalities, the crude product has a negligible MCR content. In some modalities, the crude product may include maximum 0.05 grams, maximum 0.03 grams, maximum 0.01 grams, or maximum 0.001 grams of MCR per gram of crude product. In general, the crude product has 0 to 0.04 grams, 0.000001 to 0.03 grams, or 0.00001 to 0.01 grams of MCR per gram of crude product. In some embodiments, the total product includes non-condensable gas. The non-condensable gas generally includes, but is not limited to, carbon dioxide, ammonia, hydrogen sulfide, hydrogen, carbon monoxide, methane, other hydrocarbons that are not condensable to STP, or a mixture thereof. In certain embodiments, hydrogen gas, carbon dioxide, carbon monoxide or combinations thereof may be formed in situ by contact. of steam and light hydrocarbons with the inorganic salt catalyst. In general, under thermodynamic conditions, the molar ratio of carbon monoxide and carbon dioxide is 0.07. In some embodiments, the molar ratio of the carbon monoxide generated and the carbon dioxide generated is at least 0.3., at least 0.5 or at least 0.7. In some embodiments, the molar ratio of the carbon monoxide generated and the carbon dioxide generated is between 0.3 to 1.0, 0.4 to 0.9, or 0.5 to 0.8. The ability to preferably generate carbon monoxide relative to carbon dioxide in situ can be beneficial for other processes located in an area close to the process or upstream thereof. For example, the carbon monoxide generated can be used as a reducing agent in the treatment of hydrocarbon formations or it can be used in other processes, for example, in gas synthesis processes. In some embodiments, the total product produced herein may include a mixture of compounds with a boiling range of between -10 ° C and 538 ° C. The mixture may include hydrocarbons with carbon numbers in the range of 1 to 4. The mixture may include 0.001 to 0.8 grams, 0.003 to 0.1 grams, or 0.004 to 0.01 grams of C4 hydrocarbons per gram of said mixture. C4 hydrocarbons can include 0.001 to 0.8 grams, 0.003 to 0.1 grams or 0.005 to 0.01 grams of butadiene per gram of C4 hydrocarbons. In some modalities, isoparaffins are produced in relation to the n-paraffins at a weight ratio of maximum 1.5, maximum 1.4 and maximum 1.0, maximum 0.8, maximum 0.3 or maximum 0.1. In certain embodiments isoparaffins are produced in relation to the n-paraffins at a weight ratio in the range of 0.0001 to 1.5, 0.0001 to 1.0 or 0.001 to 0.1. Paraffins include iso-paraffins or n-paraffins. In some embodiments, the total product or crude product may include olefins or paraffins at ratios or concentrations that are not generally found in crude oils produced or obtained from the formation. Olefins include a mixture of olefins with terminal double bond (alpha olefins) and olefins with internal double bonds. In certain embodiments, the olefin content in the crude product is greater than the olefin content of the • 5 crude feed by a factor of 2, 10, 50, 100 or at least 200. In some embodiments, the olefin content in the crude product is greater than the olefin content of the crude feed by a maximum factor 1,000, maximum 500, maximum 300, or maximum 250. 0 In certain embodiments, hydrocarbons with a boiling point distribution between 20 - 400 ° C have an olefin content in the range of 0.00001 to 0.1 grams, 0.0001 to 0.05 grams , or 0.001 to 0.04 grams per gram of hydrocarbons with a distribution of 5 boiling points of between 20 to 400 ° C. In some embodiments, 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. In certain modalities, the crude product has 0.0001 to 0.5 grams, 0.001 to 0.2 grams, or 0.01 to 0.1 grams of alpha olefins per gram of raw product. In certain embodiments, hydrocarbons with a boiling point distribution between 20 - 400 ° C have an alpha olefin content in the range of 0.0001 to 0.1 grams, 0.001 to 0.05 grams, or 0.01 to 0.04 grams per gram of hydrocarbons with a distribution of boiling points between 20 to 400 ° C. In some embodiments, hydrocarbons with a boiling range between 20 and 204 ° C have a weight ratio of alpha olefins and olefins with internal double bonds of at least 0.7, at least 0.8, at least 0.9, at least 0.1, at least 1.4, or at least 1.5. In some embodiments, hydrocarbons with a boiling range between 20 and 204 ° C have a weight ratio of alpha olefins and olefins with internal double bonds in the range of 0.7 to 10, 0.8 to 5, 0.9 to 3 or 1 to 2. The weight ratio of alpha olefins and olefins with internal double bonds of crude oils and commercial products is generally 0.5 maximum. The ability to produce a higher concentration of alpha olefins with respect to olefins with internal double bonds can facilitate the conversion of the crude product to commercial products. In some embodiments, the contact of a crude feed with the hydrogen feed in the presence of an inorganic salt catalyst can produce hydrocarbons with a range of boiling range between 20 and 204 ° C including linear olefins. Linear olefins have cis and trans double bonds. The weight ratio of linear olefins with double trans bonds and linear olefins with cis double bonds is of maximum 0.4, maximum 1.0 or maximum 1.4. In certain embodiments, the weight ratio of linear olefins with trans double bonds and linear olefins with cis double bonds is between 0.001 to 1.4, 0.01 to 1.0 or 0.1 to 0.4. In certain embodiments, hydrocarbons with a boiling range distribution between 20 and 204 ° C have n-paraffin content of at least 0.1 grams, at least 0.15 grams, at least 0.20 grams, or at least 0.3 grams per gram of hydrocarbons with a boiling range between 20 and 400 ° C. The content of n paraffins of these hydrocarbons, per gram of hydrocarbons, can be between 0.001 to 0.9 grams, from 0.1 to 0.8 grams, or 0.2 to 0.5 grams. In some embodiments, these hydrocarbons have a weight ratio of isoparaffins and n-paraffins of maximum 1.5, maximum 1.4, maximum 1.0, maximum 0.8 or maximum 0.3. From the content of n-paraffins in these hydrocarbons, it can be estimated that the content of n-paraffins in the crude product may be in the range of 0.001 to 0.9 grams, 0.01 to 0.8 grams, or 0.1 to 0.5 grams per gram of crude oil. product. In some embodiments, the crude product has a Ni / V / Fe content of maximum 90%, maximum 50%, maximum 10% or maximum 5% or maximum 3% of the Ni / V / Fe content of the crude feed. In certain modalities, the crude product includes, maximum 0.0001 grams, maximum IxlO "5 grams, or maximum lxlO" 6 grams of Ni / V / Fe per gram of crude product. In certain modalities, the crude product has, per gram of crude product, a content Ni / V / Fe total in the range of 1 x 10"7 grams to 5" x 10"5 grams, 3 x 10" 7 grams to 2 x 10 ~ 5 grams, or 1 x 10"6 grams to 1 x 10" 5 grams. In some modalities, the raw product has a TAN index of maximum 90%, maximum 50%, or maximum 10% of the TAN index of the crude feed. In certain modalities, the crude product may have a TAN index of maximum 1, maximum 0.5, maximum 0.1 or maximum 0.05. In certain modalities, the TAN index of the crude product can be in the range of 0.001 to 0.5, 0.01 to 0.2 or 0.05 to 0.1. In certain modalities, the API gravity of the crude product is at least 10% higher, at least 50% higher, or at least 90% greater than the API gravity of the crude feed. In certain modalities, the API gravity of the crude product is from 13 to 50, 15 to 30 or 16 to 20. In some embodiments, the raw product has a total content of heteroatoms of maximum 70%, maximum 50%, maximum 30% of the total heteroatom content of the crude feed. In some embodiments, the crude product has a total heteroatom content of at least 10%, at least 40%, at least 60% of the total heteroatom content of the crude feed. The crude product may have a sulfur content of maximum 90%, maximum 70%, or maximum 60% of the sulfur content of the crude feed. The sulfur content of the raw product, per gram of raw product, can be maximum 0.02 grams, maximum 0.008 grams, maximum 0.005 grams, maximum 0.004 grams, maximum 0.003 grams or maximum 0.001 grams. In certain modalities, the crude product has, per gram of raw product, sulfur in concentrations of 0.0001 to 0.02 grams or 0.005 to 0.01 grams. In certain embodiments, the crude product may have a maximum nitrogen content of 90% or maximum 80% of the nitrogen content of the crude feed. The nitrogen content of the crude product, per gram of crude product, can be maximum 0.004 grams, and maximum 0.003 grams, or maximum 0.001 grams. In certain modalities, the crude product has, per gram of raw product, nitrogen in concentrations of 0.0001 to 0.005 grams or 0.001 to 0.003 grams. In certain modalities, the crude product has, per gram of crude product, from 0.05 to 0.2 grams, or from 0.09 to 0.15 grams of hydrogen. The H / C of the crude product can be of maximum 1.8, maximum 1.7, maximum 1.6 and maximum 1.5 or maximum 1.4. In certain embodiments, the H / C content of the crude product is 80-120%, 90-110%, of the H / C content of the crude feed. In certain embodiments, the H / C content of the crude product is 100-120%, of the H / C content of the crude feed. If the raw product has H / C within 20% of the H / C of the crude feed, then the uptake or consumption of hydrogen in the process is minimal. The raw product includes components with a range of boiling points. In some embodiments, the crude product includes: at least 0.001 grams, or from 0.001 to 0.5 grams of hydrocarbons with boiling ranges of maximum 200 ° C or maximum 204 ° C to 0.101 MPa; at least 0.001 grams, or from 0.001 to 0.5 grams of hydrocarbons with boiling ranges between 200 ° C and 300 ° C at 0.101 MPa; at least 0.001 grams, or from 0.001 to 0.5 grams of hydrocarbons with boiling ranges between 300 ° C and 400 ° C at 0.101 MPa; and at least 0.001 grams, or from 0.001 to 0.5 grams of hydrocarbons with a boiling range of between 400 ° C and 538 ° C at 0.101 MPa. In certain modalities the raw product has, per gram of crude product, naphtha in concentrations of 0.00001 to 0.2 grams or 0.0001 to 0.1 grams or 0.001 to 0.05 grams. In certain modalities, the crude product has 0.001 to 0.2 grams or 0.01 to 0.05 grams of naphtha. In some modalities, naphtha has maximum 0.15 grams, maximum 0.1 grams or maximum 0.05 grams of olefins per gram of naphtha. In some modalities, the crude product has from 0.00001 to 0.15 grams, 0.0001 to 0.1 grams, or 0.001 to 0.05 grams of olefins per gram of raw product. In some modalities, naphtha has maximum 0.01 grams, maximum 0.005 grams or maximum 0.002 grams of benzene per gram of naphtha. In certain embodiments, naphtha has an naphthene content that is undetectable, or in the range of 1 x 10"'7 grams to 1 x 10-2 grams, 1 x 10 ~ s grams to 1 x 10" 5 grams, 5 x 10"6 grams to 1 x 10" 4 grams. Benzene-containing compositions can be considered hazardous to be handled, therefore crude product with a relatively low benzene content may not require special handling. In certain embodiments, naphtha can include aromatic compounds. Aromatic compounds may include monocyclic ring compounds or polycyclic ring compounds. 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; l-ethyl-2-methyl benzene; 1, 2, 3-trimethyl benzene; 1, 3, 5-trimethyl benzene; l-methyl-3-propyl benzene; 1-methyl-2-propyl benzene; 2-ethyl-l, 4-dimethyl benzene; 2-ethyl-2,4-dimethylbenzene; 1, 2, 3, 4-tetra-methyl benzene; ethyl, penylmethyl benzene; 1,3 diethyl-2,4,5,6-tetramethylbenzene; tri-isopropyl-ortho-xylene; substituted benzene, toluene, ortho-xylene, meta-xylene, para-xylene, or mixtures thereof. Monocyclic aromatic compounds are used in a variety of commercial products or sold as individual components. The crude product produced as described typically has a high content of monocyclic aromatic compounds. In certain modalities, the crude product has, per gram of crude product, toluene in concentrations of 0.001 to 0.2 grams or 0.05 to 0.15 grams or 0.01 to 0.1 grams. In certain modalities, the crude product has, per gram of crude product, a meta xylene content of 0.001 to 0.1 grams or 0.005 to 0.09 grams or 0.05 to 0.08 grams. The raw product has, per gram of crude product, ortho xylene content of 0.001 to 0.2 grams or 0.005 to 0.1 grams or 0.01 to 0.05 grams. The crude product has, per gram of raw product, xylene content of 0.001 to 0.09 grams or 0.005 to 0.08 grams or 0.001 to 0.06 grams. Increasing the aromatic content of naphtha tends to increase the octane number of naphtha. Crude oils can be valued based on an estimate of the crude oil potential. The gasoline potential may include, but is not limited to, an octane number calculated for the naphtha fraction of the crude oils. Crudes usually have an octane number of 35 to 60. The octane number of gasoline tends to reduce the requirement for additives that increase the octane number of gasoline. In certain embodiments, the crude product includes naphtha that has an octane number of at least 60, at least 70, at least 80, or at least 90. In general, the octane number of naphtha is between 60 and 99 , 70 and 98 6 80 and 95. In some embodiments, the crude product has a higher total aromatic content in hydrocarbons boiling between 204 ° C and 500 ° C ("naphtha and total kerosene") in relation to the total content of aromatics in naphtha and total kerosene of the crude feed at least 5%, at least 10%, or at least 99%. In general, the total content of aromatics in naphtha and kerosene in the crude feed is 8%, 20%, 75%, or 100% greater than the total content of aromatics in the naphtha and the total kerosene of the crude feed. In some embodiments, kerosene and naphtha can have a total of polyaromatic compounds in the range of 0.00001 to 0.5, 0.0001 to 0.2 grams, or 0.001 to 0.1 grams per gram of kerosene and total naphtha. The crude product has, per gram of crude product, a content of distillates of 0.0001 to 0.9 grams, of 0.001 to 0.5 grams, of 0.005 to 0.3 grams or of 0.01 to 0.2 grams. In some embodiments, the weight ratio of kerosene and diesel in the distillate is in the range of 1: 4 to 4: 1, 1: 3 to 3: 1 or 2: 5 to 5: 2. In some embodiments, the raw product has at least 0.001 grams of more than 0 to 0.7 grams, 0.001 to 0.5 grams, or 0.01 to 0.1 grams of kerosene per gram of crude product. In certain modalities, the crude product has 0.001 to 0.5 grams or 0.01 to 0.3 grams of kerosene. In some embodiments, the kerosene has per gram thereof, 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 thereof, an aromatic content of 0.1 to 0.5 grams, or 0.2 to 0.4 grams. In certain embodiments, the kerosene freezing point may be lower than -30 ° C, lower than -40 ° C, or lower than -50 ° C. Increasing the aromatic content of the kerosene fraction of the crude product tends to increase the density and reduce the freezing point of the kerosene fraction of the crude product. A crude product with a kerosene fraction with a high density and a low freezing point can be refined to produce aviation turbine fuel with desirable properties of high density and low freezing point. In certain modalities, the crude product has, per gram of crude product, diesel in concentrations of 0.001 to 0.8 grams or 0.01 to 0.4 grams. In some embodiments, the diesel has per gram thereof, an aromatics content of at least 0.1 grams, at least 0.3 grams or at least 0.5 grams. In certain embodiments, diesel has, per gram thereof, an aromatic content of 0.1 to 1 grams, 0.3 to 0.8 grams or 0.2 to 0.4 grams. In certain modalities, the crude product has, per gram of crude product, a GOV content of 0.0001 to 0.99 grams or 0.001 to 0.8 grams, or 0.1 to 0.3 grams. In certain modalities, the GOV content in the raw product is 0.4 to 0.9 grams, or 0.6 to 0.8 grams per gram of raw product. In certain modalities, the GOV has, per gram thereof, an aromatic content of 0.1 to 0.99 grams, from 0.3 to 0.8 grams or from 0.5 to 0.6 grams. In some modalities, the crude product has a maximum residue content of 70%, maximum 50% or maximum 30%, maximum 10%, or maximum 1% of the residue content of the crude feed. In certain modalities, the crude product has, per gram of crude product, a maximum residue content of 0.1 grams, maximum 0.05 grams, maximum 0.03 grams, maximum 0.02 grams, and maximum 0.01 grams, maximum 0.005 grams, or maximum 0.001 grams. In certain modalities, the crude product has, per gram of raw product, a residue content in the range of 0.000001 to 0.1 grams, 0.00001 - 0.05 grams, 0.001 - 0.03 grams, or 0.005 - 0.04 grams. In some embodiments, the crude product may include at least a fraction of the catalyst. In certain modalities, the crude product from more than 0 grams, but less than 0.01 grams, 0.000001 - 0.001 grams, or 0.00001 -0.0001 grams of total catalyst per gram of crude product. The catalyst can be used to stabilize the crude product during transport or processing thereof in processing facilities. The catalyst can inhibit corrosion, inhibit friction or increase the water separation capacity of the crude product. A crude product that includes less a fraction of the catalyst can also be processed to give lubricants or other commercial products. The catalyst used for the treatment of a crude feed in the presence of a hydrogen feed to obtain the total product can be a single catalyst or a plurality of catalysts. The catalysts of the application may first be catalyst precursors which become a catalyst in the contact zone when the hydrogen is contacted or the crude feed with sulfur is contacted with the catalyst precursor. The catalysts used in the contact of the crude feed with a hydrogen feed to produce a total product can help in the reduction of the molecular weight of the crude feed. To not overdo the theory, the catalyst combined with the hydrogen feed can reduce the molecular weight of the components in the crude feed by the action of basic components (Lewis base or Bronsted-Lowry bases) and / or superbasic components in the catalyst. Examples of catalysts that may have a Lewis or Bronsted-Lowry base include the catalysts described herein. In some modalities, it is a TMS catalyst. The TMS catalyst includes a compound containing a transition metal sulfide. For the purposes of this application, the weight of the transition metal sulfide in the TMS catalyst is determined by the addition of the total weight of the transition metals and the total weight of the sulfur in the catalyst. In general, the atomic ratio of the transition metal and sulfur is usually 0.2 -20, 0.5-10, or 1-5. Examples of transition metal sulfides can be found in "Inorganic Sulfur Chemistry"; edited by G. Nickless; Elsevier Publishing Company; Amsterdam - London - New York; Copyright 1968; Chapter 19. In certain embodiments, the TMS catalyst may include a total of at least 0.4 grams, at least 0.5 grams, at least 0.8 grams, or at least 0.99 grams of one or more transition metal sulfides per gram of catalyst. In certain embodiments, the TMS catalyst has a total content of one or more transition metal sulfides per gram of catalyst, 0.4-0.999 grams, 0.5 to 0.9 grams, or 0.6 to 0.8 grams. The TMS catalyst includes one or more transition metal sulfides. Examples of transition metal sulfides include pentlandite (Fe4.5Ni .5S8), smitite (Fe6.5Ni2.25S ??), bravoite (Fe0.7Ni0.2Co0.?S2), mackinawita (Fe0.75Ni0.25S0) .9), argentopentlandita (AgFe6Ni2S8), isocubanita (CuFe2S3), isocalcopirita (Cu8Fe9S? 6), sfalerita (Zno.95Feo.05S), mooihoekita (Cu9Fe9S16), chatkalita (Cu6FeSn2S8), sternbergita (AgFe2S3), chalcopirita (CuFeS2), troilite (FeS), pyrite (FeS2), pyrrhotite (Fe (? -x) S (x = 0 to • 0.17)), heazlewoodite (Ni3S2) or vaesite (NiS). In certain embodiments, the TMS catalyst includes one or more transition metal sulfides combined with alkali metals, ferrous alkali metals, zinc, zinc compounds, or mixtures thereof. The TMS catalyst is represented in some embodiments by the general chemical formula Ac [MaS.b] d, wherein A is alkali metal, alkaline earth metal or zinc; M is a transition metal of columns 6 to 10 of the periodic table, and S is sulfur. The atomic ratio of a to Jb is 0.5 to 2.5, or 1 to 2. The atomic ratio of c to a is 0.0001 to 1, 0.1 to 0.8, or 0.3 to 0.5. In some embodiments, the transition metal is iron. In some embodiments, the TMS catalyst may include alkali metal sulphides or alkaline earth metals or transition metals for example, bartonite (K3Fe? 0S? 4), rasvumite (KFe2S3), djerfisherite (KsNaFe? 9Cu4NiS26Cl), chlorobarterite (Kg.? Fe24Cuo.2S26.?Clo.7), b well coyoteite (NaFe3S5- (H20) 2). In some embodiments, the TMS catalyst includes bartonite prepared in situ. Bartonite prepared in situ can be termed synthetic bartonite. Synthetic or natural bartonite can be used as a TMS catalyst in the methods described herein. In certain embodiments, the TMS catalyst may include maximum 25 grams, maximum 15 grams, or maximum 1 gram of support per 100 grams of TMS catalyst. Typically, the TMS catalyst has from 0 to 25 grams, 0.00001 to 20 grams, 0.0001 grams to 10 grams of base material per 100 grams of TMS catalyst. Examples of base materials that can be used with the TMS catalyst include refractory oxides, porous carbon materials, zeolites or mixtures thereof. In some embodiments, the TMS catalyst does not contain virtually, or is completely free of support. The TMS catalyst which includes alkali metals, alkaline earth metals, zinc, zinc compounds, or their mixtures may contain one or more transition metal sulfides, bimetal sulphides of transition metals and alkali metals, sulfides of high transition metals. valence, transition metal oxides, or mixtures thereof, as determined by X-ray diffraction. In some embodiments, a fraction of the alkali metal compound, the alkaline earth metal compound, zinc compound or a fraction of the sulfide compound of the present invention may be present. transition metal of the TMS catalyst, in the form of amorphous composition not detectable by X-ray diffraction techniques. In some embodiments, the crystalline particles of the TMS catalyst or the crystalline particle mixtures of the TMS catalyst have a particle size of maximum 108 A , maximum 103 Á, maximum 100 Á, or maximum 40 Á. In normal practice, the average crystalline particle size of the TMS catalyst is generally 10. The TMS catalyst that includes alkali metals, alkaline earth metals, zinc, zinc compounds, or mixtures thereof can be prepared by mixing sufficient concentrations of deionized water, a desired concentration of transition metal oxide, and a desired concentration of metal carbonates of columns 1 to 2, metal oxalates from columns 1 to 2, metal acetates of columns 1 to 2, zinc carbonate, zinc acetate, zinc oxalate, or mixtures thereof to form a wet paste. The wet paste can be dried at temperatures of 100-300 ° C or 150-250 ° C to form a mixture of salt and transition metal oxides. The mixture of salt and transition metal oxides can be calcined at temperatures of 300-1000 ° C, 500-800 ° C, or 600-700 ° C to form a mixture of metal salt and transition metal oxide. The mixture of metal salt and transition metal oxide can react with hydrogen to form a reduced intermediate solid. The addition of hydrogen can be carried out at a flow rate such that the excess concentration of hydrogen and mixture of metal salt and transition metal oxide is provided. Hydrogen can be added to the mixture of metal salt and transition metal oxide for 10 to 50 hours or 20 to 40 hours to give a reduced intermediate solid which includes the elemental transition metal. The addition of hydrogen can be carried out at a temperature of 35-500 ° C, 50-400 ° C, or 100-300 ° C, at a total pressure of 10 to 15 MPa, 11 to 14 MPa or 12 to 13 MPa . It is to be understood that the reduction time, the reaction temperature, the selection of the reduction gas, the reduction gas pressure and the flow rate of the reduction gas used to prepare the solid intermediate is generally changed in relation to the absolute mass of the selected transition metal oxide. The intermediate-reduced solid can sometimes pass through a 40 mesh screen with minimal force. The reduced intermediate solid can be added incrementally as elemental sulfur and hot diluent (eg, at 100 ° C) or can be added to one or more sulfur compounds, mixed at such a rate that heat production and gas production are controlled . The diluent can include any suitable diluent that provides a means to dissipate the heat of sulfhydration. The diluent may include solvents with boiling point distributions of at least 100 ° C, at least 150 ° C, at least 200 ° C, or at least 300 ° C. In general, the diluent has a boiling range between 100 and 500 ° C, 150 and 400 ° C or 200 and 300 ° C. In some embodiments, the diluent is GOV or its xylenes. Sulfur compounds include, but are not limited to, hydrogen sulfide or thiols. The concentration of sulfur or the sulfur compounds can be from 1 to 100 mol%, 2 to 80 mol%, 5 to 50 mol%, 10 to 30 mol%, based on the moles of the metals of columns 1 to 2 or zinc in the metal salts of columns 1 to 2 or the zinc salt. After the addition of a reduced solid intermediate to the mixture of elemental sulfur and diluent, the resulting mixture can be heated upwards, until reaching a final temperature of 200 to 500 ° C, 250 to 450 ° C, or 300 to 400 ° C, and maintained at a final temperature for at least 1 hour, at least 2 hours, or at least 10 hours. In general, the final temperature is maintained for 15 hours, 10 hours, 5 hours or 1.5 hours. After heating to the high sulfidation reaction temperature, the catalyst / diluent mixture can be cooled to a temperature of 0 to 100 ° C, 30 to 90 ° C, or 50 to 80 ° C to facilitate recovery of the catalyst from the mixture. The sulfurized catalyst can be isolated in an oxygen-free atmosphere from the diluent using standard techniques and washed with at least a fraction of the low boiling solvent (e.g., pentane, heptane or hexane) to produce a TMS catalyst. The TMS catalyst can be converted to powder with standard techniques. In some modalities, it 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 amides, alkaline earth metal sulphides, alkaline earth metal acetates, alkaline earth metal oxalates, alkaline earth metal forms, alkaline earth metal pyruvates , or their mixtures. Inorganic salt catalysts include, but are not limited to, mixtures of: NaOH / RbOH / CsOH; KOH / RbOH / CsOH; NaOH / KOH / RbOH; - NaOH / KOH / CsOH; K2C03 / Rb2C03 / Cs2C03; Na20 / K20 / K2C03; NaHC03 / KHC03 / Rb2C03; LiHC03 / KHC03 / Rb2C03; KOH / RbOH / CsOH mixed with mixture of K2C03 / Rb2C03 / Cs2C03; K2C03 / CaC03; K2C03 / MgC03; Cs2C03 / CaC03; Cs2C03 / CaO; Na 2 CO 3 / Ca (OH) 2; KH / CsC03; KOCHO / CaO; Cs0CH0 / CaC03; CsOCHO / Ca (EIGHT) 2; NaNH2 / K2C03 / Rb20; K2C03 / CaC03 / Rb2C03; K2C03 / CaC03 / Cs2C03; K2C03 / MgC03 / Rb2C03; K2C03 / MgC03 / Cs2C03; or Ca (OH) 2 mixed with mixture of K2C03 / RbC03 / Cs2C03. In certain embodiments, the catalysts of inorganic salts contain maximum 0.00001 grams, maximum 0.001 grams, or maximum 0.01 grams of lithium, calculated in lithium weight, per gram of inorganic salt catalyst. In some embodiments, the inorganic salt catalyst contains 0 grams, but less than 0.01 grams, 0.0000001 to 0.001 grams, or 0.00001 to 0.0001 grams of lithium, calculated in lithium weight, per gram of inorganic salt catalyst. In certain embodiments, the inorganic salt catalyst includes one or more alkali metal salts that include an alkali metal with an atomic number of at least 11. The atomic ratio of an alkali metal with an atomic number of at least 11 to an alkali metal with an atomic number greater than 11, in some embodiments, it is from 0.1 to 10, 0.2 to 6, or 0.3 to 4 when the inorganic salt catalyst has two or more alkali metals. For example, the inorganic salt catalyst may include sodium, potassium and rubidium salts with a sodium potassium ratio of 0.1 to 6, the ratio of sodium and rubidium is 0.1 to 6, and the ratio of potassium and rubidium is 0.1 to 6. In another example, the inorganic salt catalyst includes sodium salt and potassium salt with the atomic ratio of sodium and potassium from 0.1 to 4. In certain embodiments, the inorganic salt catalyst includes metals from columns 8 to 10 of the periodic table, composed of metals from columns 8 to 10 of the periodic table, metals from column 6 of the periodic table, metal compounds from column 6 of the periodic table, or their mixtures. The metals of columns 8 to 10 include, but are not limited to, iron, ruthenium, cobalt or nickel. The metals of column 6 include, but are not limited to, chromium, molybdenum or tungsten. In certain embodiments, the inorganic salt catalyst includes 0.1 to 0.5 grams, or 0.2 to 0.4 grams of Raney nickel per gram of inorganic salt catalyst. In certain embodiments, the inorganic salt catalyst also includes metal oxides of columns 1 to 2 or column 13 of the periodic table. The metals of column 13 include, but are not limited to, boron or aluminum. Non-limiting examples of metal oxides include lithium oxide (Li20), potassium oxide (K20), calcium oxide (CaO), or aluminum oxide (A1203). The inorganic salt catalyst in certain embodiments is free of Lewis acids, or substantially free of Lewis acids (eg, BC13, AlCl3 and S03), Bronsted-Lowry acids (eg, H30 +, H2S04, HCl, and HN03) ), glass forming compositions (eg, borates and silicates), and halides. The inorganic salt may contain, per gram of inorganic salt catalyst: from 0 grams to 0.1 grams, 0.000001 - 0.01 grams, or 0.00001 - 0.005 grams of: a) halides; b) compositions that form glass at temperatures of at least 350 ° C, or maximum 1000 ° C; c) Lewis acids; d) Bronsted-Lowry acids; or e) mixtures thereof. The inorganic salt catalyst can be prepared with standard techniques. For example, the desired concentration for each component of the catalyst can be combined using standard mixing techniques (e.g., ground or spray). In other embodiments, the inorganic compositions are dissolved in a solvent (e.g., water or a suitable organic solvent) to form a mixture of solvent and inorganic composition. The solvent can be removed with standard separation techniques to produce the inorganic salt catalyst. In certain modalities, the inorganic salts of the inorganic salt catalyst can be incorporated into the support to form the supported inorganic salt catalyst. Examples of supports include, but are not limited to, zirconium oxide, calcium oxide, magnesium oxide, titanium oxide, hydrotalcite, alumina, germanium, iron oxide, nickel oxide, zinc oxide, cadmium oxide, oxide of antimony, and their mixtures. In certain embodiments, an inorganic salt, a metal of columns 6 to 10 or metal compounds of columns 6 to 10 may be impregnated in supports. Alternatively, the inorganic salts may be melted or softened with heat and forced into a metal support or a metal oxide support, or on the same, to form a supported inorganic salt catalyst. The structure of the inorganic salt catalyst is generally non-homogeneous, permeable or mobile at a certain temperature or in a temperature range when the order in the catalyst structure is lost. The inorganic salt catalyst can be disordered without a substantial change in the composition (eg, without decomposition of the salt). Without being bound by theory, it is believed that the inorganic salt catalyst becomes disordered (it is mobile) as the distance between the ions in the latices of the inorganic salt catalyst increases. As the ion distance increases, the crude feed or hydrogen feed may be permeable through the inorganic salt catalyst instead of through the surface of the inorganic salt catalyst. The permeability of the crude feed or of the hydrogen feed through the inorganic salt usually produces an increase in the contact zone between the inorganic salt catalyst and the crude feed or the hydrogen feed. The increase of the contact zone or the reactivity area of the inorganic salt catalyst can increase the yield of the crude product, limit the production of waste or coke, or facilitate the change in the properties of the crude product in relation to the same properties of the crude feed. The inorganic salt catalyst disorder (eg, inhomogeneity, permeability or mobility) can be determined with DSC methods, ion conductivity measurements, TAP methods, visual inspection, X-ray diffraction methods, or combinations thereof. The use of TAP to determine the characteristics of the catalysts is described in the following U.S. Patents: 4,626,412 to Ebner et al.; 5,039,489 to Gleaves et al .; and 5,264,183 to Ebner et al. The TAP system can be obtained from Mithra Technologies (Foley, Missouri, USA). The TAP analysis can be carried out in a temperature range of 25 - 850 ° C, 50 - 500 ° C, or 60 - 400 ° C, at a heating rate of 10-50 ° C, or 20 - 40 ° C , and vacuum in the range of 1 x 10 ~ 13 to 1 x 10"8 torr.The temperature can remain constant or increase as a function of time.As the inorganic salt catalyst increases, the gas emission is measured. of the Inorganic Salt Catalyst 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 increase (acute increase) is detected. the evolution of the gas from the inorganic salt catalyst is considered to be the temperature at which the inorganic salt catalyst becomes disordered In certain embodiments, an increase in the gas emitted from the inorganic salt catalyst can be detected at a given temperature range with TAP, the temperature or range of temperature is described "temperature TAP". The initial temperature of the temperature range determined with TAP is called the "minimum TAP temperature". The increase in gas emitted by the catalysts of inorganic salts suitable for contact with a crude feed is at a TAP temperature of 100-600 ° C, 200-500 ° C, or 300-400 ° C. In general, the TAP temperature is in the range of 300 - 500 ° C. In certain embodiments, different compositions of inorganic salt catalysts also exhibit gas increases, but at different TAP temperatures. The magnitude of the ionization increase associated with the gas emitted may be indicative of the order of the particles in a crystal structure. In a highly ordered crystalline structure, ion particles are generally very associated, and the release of the structure of ions, molecules, gases or their combinations requires more energy (ie, more heat). In a disordered crystal structure, the ions do not associate with each other as strongly as the ions of a highly ordered crystal structure. Because ions associate weaker, such high energy values are usually not required to release the ions, molecules or gases from the disordered crystal structure and therefore the amount of ions or gas released from a structure of disordered glass is usually greater than the amount of ions or gas released from a highly ordered crystal structure at a selected temperature. In certain embodiments, the heat of dissociation of the inorganic salt catalysts can be observed in a range of 50 ° C to 500 ° C at a heating or cooling rate of 10 ° C, as determined by the differential heat-exchange scan. In a DSC method, the sample can be heated to a first temperature, cooled to room temperature, and then heated again. The transitions observed during the first heating are usually representative of the water or solvent transported and may not be representative of the heat of the dissociations. For example, a drying heat of a wet or hydrated sample is usually easily observed below 250 ° C, usually between 100 and 150 ° C. The transitions observed during the cooling cycle and the second heating correspond to the dissociation heat of the sample. "The heat transition" describes the process that occurs when the molecules or atoms ordered in the structure become disordered when the temperature increases during the DSC analysis. "The cold transition" describes the process that occurs when the molecules or atoms ordered in the structure are homogenized when the temperature decreases during the DSC analysis. In certain modalities, the cold / heat transition of an inorganic salt catalyst takes place over a range of temperatures that are detected with DSC. The temperature or range of temperatures at which the heat transition of the inorganic salt catalyst occurs during the second heating cycle is described as "DSC temperature". The lowest DSC temperature of the temperature range in the second heating cycle is defined as "minimum DSC temperature". The inorganic salt catalyst can have a heat transition between 200 and 500 ° C, 250 and 450 ° C, or 300 and 400 ° C. In an inorganic salt containing inorganic salt particles which is a relatively homogeneous mixture, the shape of the peak associated with the heat absorbed during the second heating cycle may be relatively narrow. In an inorganic salt catalyst containing inorganic salt particles which is a relatively non-homogeneous mixture, the shape of the peak associated with the heat absorbed during the second heating cycle can be relatively broad. The absence of peaks in a DSC spectrum indicates that the salt does not absorb or release heat during the scanned temperature range. The lack of transitional heat usually indicates that the structure of the sample does not change with heating. As the homogeneity of the particles of an inorganic salt mixture increases, the ability of the mixture to remain solid or semi-liquid during heating decreases. The homogeneity of the inorganic mixture can be related to the ionic radius of the cations in the mixtures. For cations with smaller ionic radius, the ability of a cation to share the electron density with the corresponding anion increases and increases the acidity of the corresponding anion. For a series of similar charge ions, the smaller ion radius results in greater inter-ionic attractive forces between the cation and the anion if the anion is a strong base. The higher interionic attractive forces tend to result in higher transition heat temperatures for the salt and more homogenous salt particle mixtures (higher peaks and greater area under the DSC curve). Mixtures that include cations with small ionic radii tend to be more acidic than cations of higher ionic radii, and therefore the acidity of the inorganic salt mixture increases when the cationic radius decreases. For example, the contact of a crude feed with a hydrogen feed in the presence of an inorganic mixture that includes lithium cations tends to produce larger amounts of gas or coke relative to the contact of the crude feed with a hydrogen feed in the presence of an inorganic salt catalyst that includes cations with ionic radions greater than lithium. The ability to inhibit the generation of gas or coke increases the yield of total liquid product in the process. In certain embodiments, the inorganic salt catalyst may include two or more inorganic salts. The minimum DSC temperature for each of the inorganic salts can be determined. The minimum DSC temperature of the inorganic salt catalyst may be less than the minimum DSC temperature of at least one of the inorganic metal salts in the inorganic salt catalyst. For example, the inorganic salt catalyst may include potassium carbonate and cesium carbonate. Potassium carbonate and cesium carbonate have DSC temperatures above 500 ° C. A catalyst of K2C03 / Rb2C03 / Cs2C03 has a DSC temperature of 290-300 ° C. "In certain embodiments, 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, For example, the TAP temperature of the inorganic salt catalyst may be 350. 500 ° C. The DSC temperature of the same inorganic salt catalyst can be 200 to 300 ° C, and the DSC temperature of the individual salts can be at least 500 ° C or maximum 1000 ° C. embodiments an inorganic salt catalyst with a TAP index or a DSC temperature between 150 and 500 ° C, 200 and 450 ° C, or 300 and 400 ° C, which does not undergo decomposition at these temperatures, for catalyst conversion of compositions with high viscosity or high molecular weight (eg, crude feed) in liquid products In certain embodiments, inorganic salt catalysts may have higher conductivity relative to inorganic salts during the heating of the inorganic salt catalyst in a temperature range of 200 to 600 ° C, 300 to 500 ° C, or 350 to 450 ° C. The higher conductivity of the inorganic salt catalyst is generally associated with the acquisition of mobility of the particles in the inorganic salt catalyst. The ionic conductivity of some inorganic salt catalysts changes at lower temperatures than the temperature at which the ionic conductivity of a single inorganic salt catalyst component changes. The ionic conductivity of the inorganic salts can be determined by applying Ohm's law. V = IR, where V is the voltage, I is the current, and R is the resistance. To measure the ionic conductivity, the inorganic salt catalyst can be placed in a quartz vessel with two cables (for example, copper or platinum cables), separated from each other, but immersed in the inorganic salt catalyst. Figure 7 is a graphical representation of the system that can be used to measure the ionic conductivity. A quartz vessel 156 with a sample 158 can be placed in the heating device, and heated up to the desired temperature. Supply voltage 160 is applied to cable 162 during heating. The resulting current that passes through the wires 162 and 164 is measured in a meter 166. This may be, but not limited to, a Wheatstone bridge or a multiple meter. As the sample 158 becomes less homogeneous (more mobile) without decomposition occurring, the resistivity of the sample should decrease and the current observed in the meter 166 should increase. In some embodiments, at the desired temperature, the catalyst Inorganic salt can have different ionic conductivities after heating, cooling, and subsequent heating. The difference in ionic conductivities may indicate that the crystal structure of the inorganic salt catalyst is altered from its original form (initial form) to another form (second form) during heating. The ionic conductivities, after heating, are expected to be similar or equal if the shape of the inorganic salt catalyst does not change during heating. In certain embodiments, the inorganic salt catalyst has a particle size in the range of 10 to 1000 microns, 20 to 500 microns, or 50 to 100 microns, as determined by passing the inorganic salt catalyst through the mesh or sieve. The inorganic salt catalyst can be softened when heated to temperatures above 50 ° C and below 500 ° C. As the inorganic salt catalyst softens, the liquid and catalyst particles may exist at the same time in the matrix of the inorganic salt catalyst. The catalyst particles in some embodiments can self-deform with gravity, or under a pressure of at least 0.007 MPa, or maximum 0.101 MPa, when heated to a temperature of at least 300 ° C, or maximum 800 ° C, in such a way that the inorganic salt catalyst is converted in the first form to the second form. Upon cooling the inorganic salt catalyst to 20 ° C, the second form of the inorganic salt catalyst is unable to return to the first form of the inorganic salt catalyst. The temperature at which the inorganic salt is transformed from the first to the second form is called the "deformation" temperature. The deformation temperature can be a temperature range or a single temperature. In certain embodiments, the inorganic salt catalyst particles self-degrade with gravity or with pressure upon heating to a deformation temperature less than the deformation temperature of any of the individual inorganic metal salts. In certain embodiments, the inorganic salt catalyst includes two or more inorganic salts with different deformation temperatures. In some embodiments, the deformation temperature in the inorganic salt catalyst differs from the deformation temperatures of the individual inorganic metal salts.

In certain embodiments, the inorganic salt catalyst is liquid or semi-liquid, above the temperature of DSC or the TAP index. In some embodiments, the inorganic salt catalyst is liquid or semi-liquid at the minimum DSC or TAP temperature. At the DSC temperature or at or above the minimum TAP index, the semi-liquid or liquid inorganic salt catalyst, mixed with the crude feed may form a separate phase from the crude feed in some of the embodiments. In some embodiments, the liquid or semi-liquid inorganic salt catalyst has low solubility in crude feed (eg, from 0 grams to 0.5 grams, 0.0000001 - 0.2 grams, or 0.0001 - 0.1 grams of inorganic salt catalyst per gram of feed of crude) or is insoluble in the crude feed (for example from 0 grams to 0.05 grams, 0.000001 - 0.01 grams, or 0.00001 - 0.001 grams of inorganic salt catalyst per gram of crude feed) at the minimum TAP temperature. In some embodiments, X-ray powder diffraction methods are used to determine the separation of the atoms in the inorganic salt catalyst. The shape of the Dooi peak in the X-ray spectrum can be monitored and the relative order of the inorganic salt particles can be estimated. The X-ray diffraction peaks represent different inorganic salt catalyst compounds. In powder X-ray diffraction, the Dooi peak can be monitored and the separation between the atoms can be estimated. In the inorganic salt catalyst containing highly ordered inorganic salt atoms, the D0o? It has a relatively narrow shape. In an inorganic salt catalyst (for example a catalyst K2C03 / Rb2C03 / Cs2C03) containing inorganic salt atoms in a random manner, the shape of the D0o? Can it be relatively wide or can there be no D0o peak? • To determine if the disorder of the inorganic salt atoms changes during heating, the X-ray diffraction spectrum of the inorganic salt catalyst can be taken before heating compared to the X-ray diffraction spectrum after heating. The peak D0o? (which corresponds to the atoms of inorganic salts) in the spectrum of x-ray diffraction taken at temperatures above 50 ° C may not exist, or be wider than the peaks D0o? in the X-ray diffraction spectrum at temperatures below 50 ° C. In addition, the X-ray diffraction pattern of the individual inorganic salts shows peaks D0o? relatively narrow at the same temperatures. The contact conditions can be controlled such that the total product composition (and therefore, the crude product) can vary for a given crude feed in addition to limiting or inhibiting the formation of side products. The total product composition includes, but is not limited to, paraffins, olefins, aromatics or mixtures thereof. These compounds are part of the crude product compositions and the non-condensable hydrocarbon gases.

If the contact conditions are controlled in combination with the catalyst described herein, a total product with less coke content than predicted can be obtained. If the MCR content of different crude oils is compared, they can be ranked based on their tendency to form coke. For example, crude with an MCR content of 0.1 grams of MCR per gram of crude is expected to form more coke than a crude with an MCR content of 0.001 grams of MCR per gram of crude oil. In general, disadvantageous crudes have an MCR content of at least 0.05 grams of MCR per gram of unfavorable crude. In certain embodiments, the residue content or the content of coke deposited in the catalyst during the reaction period can be maximum 0.1 grams, maximum 0.05 grams or maximum 0.03 grams of residue and / or coke per gram of catalyst. In certain modalities, the weight of residue or coke deposited in the catalyst is 0.0001 to 0.1 grams, 0.001 to 0.05 grams or 0.01 to 0.03 grams. In some embodiments, the catalyst used is substantially free of residue or coke. In certain modalities, the contact conditions are controlled in such a way that maximum 0.015 grams, maximum 0.01 grams, maximum 0.005 grams, or maximum 0.003 grams of coke are formed per gram of crude product. The contact of a crude feed with the catalyst under controlled contact conditions produces a lower amount of coke or residue relative to the amount of coke or residue produced by heating the crude feed in the presence of a refining catalyst, or in the absence of the catalyst, in. the same contact conditions. The contact conditions can be controlled, in some modalities, such that per gram of crude feed, they become at least 0.5 grams, at least 0.7 grams, at least 0.8 grams, or at least 0.9 grams of crude oil feed. product. In general, between 0.5 and 0.99 grams, 0.6 and 0.9 grams, or 0.7 and 0.8 grams of raw product per gram of crude feed during contact are produced. The conversion of crude feed into raw product with a minimum production of waste and coke, if any, in the raw product allows it to become commercial products with a minimum pretreatment in the refinery. In certain modalities, it becomes maximum 0.2 grams, maximum 0.1 grams, maximum 0.05 grams, maximum 0.03 grams or maximum 0.01 grams of crude oil feed in non-condensable hydrocarbons per gram of crude feed. In certain modalities, it is produced from 0 to 0.2 grams, 0.0001 to 0.1 grams, 0.001 to 0.05 grams, or 0.01 to 0.03 grams of non-condensable hydrocarbons per gram of crude feed.

The temperature of the contact zone, the circulation rate of the crude feed, the total product rate, the rate or the catalyst feed concentration, or combinations thereof, can be controlled to maintain the desired reaction temperatures. In some embodiments, the temperature in the contact zone can be controlled by changing the circulation of the gaseous hydrogen feed or the inert gas through the contact zone to dilute the hydrogen concentration or to remove excess heat from the zone. contact. In some embodiments, the temperature in the contact zone can be controlled such that the temperature in the contact zone is equal to, greater than or less than the desired temperature "Ti". In certain embodiments, the contact temperature is controlled such that the temperature in the contact zone is less than the minimum TAP temperature and or that the minimum DSC temperature. In certain embodiments, Ti may be 30 ° C lower, 20 ° C lower, 0 10 ° C lower than the minimum TAP temperature or the minimum DSC temperature. For example, in one embodiment, the contact temperature can be controlled such that it is 370 ° C, 380 ° C or 390 ° C during the reaction period when the minimum TAP temperature or the minimum DSC temperature is 400 ° C. In certain embodiments, the contact temperature is controlled such that the temperature in the contact zone is less, greater than or equal to the TAP temperature of the catalyst and / or the DSC temperature of the catalyst. For example, the contact temperature can be controlled such that it is 450 ° C, 500 ° C, or 550 ° C during the reaction period when the TAP temperature or the minimum DSC temperature is 450 ° C. The control of the contact temperatures based on the TAP temperatures of the catalyst or the DSC temperatures of the catalyst can give rise to better properties in the crude product. This control can, among other things, reduce the formation of coke, the formation of non-condensable gas or its combinations. In certain embodiments, the inorganic salt catalysts can be conditioned before being added to the crude feed. In some embodiments, the conditioning may take place in the presence of the crude feed. The conditioning of inorganic salt catalysts may include heating the inorganic salt catalyst to a first temperature of at least 100 ° C, at least 300 ° C, at least 300 ° C, at least 400 ° C, or at least 500 ° C C, and then cooling the inorganic salt catalyst to a second temperature of maximum 250 ° C, maximum 200 ° C, or maximum 100 ° C. In certain embodiments, the inorganic salt catalyst is heated to a temperature of between 150-700 ° C, 200-600 ° C, or 300-500 ° C and then cooled to a second temperature in the range of 25-240. ° C, 30 to 200 ° C, or 50 to 90 ° C. The conditioning temperatures can be determined with the measurements of ionic conductivity at different temperatures. In some embodiments, the conditioning temperatures are determined from the DSC temperatures obtained from the cold / heat transitions obtained by heating and cooling the inorganic salt catalyst at multiple times in DSC. The conditioning of inorganic salt catalysts can allow contact of a crude feed at reaction temperatures lower than the temperatures used with conventional hydrotreating catalysts. In some modalities, the content of naphtha, distillate, GOV, or their mixtures can be varied in the total product, changing the rate of total product removal from the contact zone. For example, decreasing the total product removal rate tends to increase the contact time of the crude feed with the catalyst. Alternatively, increasing the pressure relative to the initial pressure can increase the contact time, can increase the yield of crude product, it may increase the incorporation of hydrogen from gases in the crude product for a given mass flow rate of the crude feed or hydrogen feed, or may alter the combinations of these effects. Increased contact times of the crude feed with the catalyst can lead to a higher concentration of diesel, kerosene, or naphtha and a lower concentration of GOV in relation to the concentration of diesel, kerosene, naphtha, and GOV produced at shorter times contact. If you increase the contact time of the total product in the contact zone, you can also change the average carbon number of the raw product. If the contact time is increased, a higher percentage by weight of the lower carbon numbers can be obtained (and therefore, a higher API gravity).

In some modalities, contact conditions may change over time. For example, contact pressure or contact temperature may increase to increase the concentration of hydrogen that is captured by the crude feed to produce the raw product. The ability to change the concentration of hydrogen uptake of the crude feed, while improving other properties of the crude feed, increases the type of crude product that can be produced from a single crude feed. The ability to produce multiple raw products from a single crude feed can allow compliance with other descriptions associated with transportation or treatment. The uptake of hydrogen can be evaluated by comparing H / C of the crude feed with the H / C of the crude product. The increase of the H / C of the crude product in relation to the H / C of the crude feed indicates that hydrogen is incorporated into the crude product from the hydrogen feed. A relatively low increase of the H / C of the crude product (20%, in relation to the crude feed) indicates that there is a relatively low consumption of hydrogen gas during the process. It is desirable to achieve a significant improvement of the properties of the crude product, in relation to the same properties of the crude feed with a minimum consumption of hydrogen. The ratio of hydrogen feed and crude feed can be modified to change the properties of the crude product. For example, it can increase the ratio of hydrogen feed and crude feed resulting in a crude product with higher GOV content per gram of crude product. In certain embodiments, the contact of the crude feed with the catalysts of inorganic salts in the presence of light hydrocarbons and / or steam allows to obtain more liquid hydrocarbons and less coke in the raw product than the contact of the crude feed with a catalyst of inorganic salt in the presence of hydrogen and steam. In embodiments that include contacting the crude feed with methane in the presence of the inorganic salt catalyst, at least a fraction of the components of the crude product may include carbon and atomic hydrogen (from methane) that is incorporated into the molecular structures of the components. In certain embodiments, the volume of crude product produced from crude feed in contact with the hydrogen feed in the presence of inorganic salt catalyst is at least 5% higher, at least 10% higher, or at least 15%, or at least 100% greater than the volume of crude product obtained from the thermal process at STP. The total volume of crude product obtained by contacting the crude feed with the inorganic salt catalyst can be at least 110% vol, from the volume of crude feed to STP. The increase in volume is believed to be due to a lower density. The lower density can generally be at least partially caused by hydrogenation of the crude feed. In certain embodiments, the crude feed has 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 per gram of crude feed in contact with a hydrogen feed in the presence of an inorganic salt catalyst without decreasing catalyst activity.

In certain embodiments, the inorganic salt catalyst can be at least partially regenerated by removing one or more components that contaminate it. The contaminants include, but are not limited to, metals, sulfides, nitrogen, coke or their mixtures. Sulfide contaminants can be removed from the inorganic salt catalysts by the contact of steam and carbon dioxide with the catalyst used to produce hydrogen sulfide. Nitrogen contaminants can be removed by contacting the inorganic salt catalyst with steam to give ammonia. Coke contaminants can be removed from the catalysts of inorganic salts used by the contact thereof with steam or methane to give rise to hydrogen and carbon oxides. In some modalities, one or more gases are generated from the mixture of catalysts of inorganic salts used with residual crude feed. In certain embodiments, a mixture of inorganic salt used can be heated (for example, K2C03 / Rb2C03 / Cs2C03; K0H / A1203; Cs2C03 / CaC03; or NaOH / KOH / LiOH / Zr02), feed unreacted crude or waste and / or coke at a temperature in the range of 700 - 1000 ° C or from 800 - 900 ° C until the production of gas and / or liquids be minimal in the presence of steam, hydrogen, carbon dioxide, or light hydrocarbons to give rise to a liquid phase or a gas. The gas may include a greater amount of hydrogen or carbon dioxide relative to the reactive gas. For example, the gas may include from 0.1 to 99 moles or from 0.2 to 8 moles of hydrogen or carbon dioxide per mole of reactive gas. The gas may contain a relatively low concentration of light hydrocarbons or carbon monoxide. For example, less than 0.05 grams of light hydrocarbons per gram of gas and less than 0.01 grams of carbon monoxide per gram of gas. The liquid phase can contain water, for example, more than 0.5 to 0.99 grams, or more than 0.9 to 0.9 grams of water per gram of liquid. In some embodiments, the catalyst used or solids in the contact zone can be treated to recover metals (eg, vanadium or nickel) from the catalyst used and / or solids. The catalyst used and / or solids can be treated using generally known metal separation techniques, for example, heating, chemical treatment or gasification. EXAMPLES Following are examples of the preparation of the catalysts, the testing of the catalysts and the systems controlling the contact conditions. Example 1. Preparation of sulfur catalyst K-Fe A K-Fe sulfide catalyst is prepared by combining 1000 grams of iron oxide (Fe203) and 580 g of potassium carbonate with 412 grams of deionized water to form a wet paste. The wet paste is dried at 200 ° C to form a mixture of iron oxide and potassium carbonate. The mixture of iron oxide and potassium carbonate is calcined at 500 ° C to form a mixture of iron oxide and potassium carbonate. The mixture of iron oxide and potassium carbonate is reacted with hydrogen to form a reduced intermediate solid that included iron metal. The addition of hydrogen was performed for 48 hours at 450 ° C and 11.5 to 12.2 MPa (1665 to 1765 psi). The solid intermediate was passed through a 40 mesh screen with minimal force. The solid intermediate was added in an increasing manner at such a rate that the evolution of the heat and the gas produced was controlled to a mixture of elemental sulfur and m-xylene and GOV at 100 ° C. After adding the intermediate solid, the resulting mixture was heated up to 300 ° C and maintained at 300 ° C for 1 hour. The solvent and catalyst were mixed at less than 100 ° C and the sulfurized catalyst was separated from the mixture. The sulfurized catalyst was isolated by filtration in a dry chamber under an argon atmosphere, and washed with m-xylene to give 544.7 grams of sulfide catalyst K-Fe. The sulphide catalyst K-Fe was sprayed by passing it through a 40 mesh screen.

The resulting sulfur catalyst K-Fe was analyzed with x-ray diffraction techniques. From the x-ray diffraction spectrum analysis, it was determined that the catalyst included troilite (FeS), sulfide K-FE (KFeS2), pyrrhotite, and iron oxides (such as magnetite, Fe30). The peak associated with iron disulfide (eg, pyrite, FeS2) is not observed in the x-ray diffraction spectrum. Example 2. Contact of a crude feed with a hydrogen feed in the presence of a K-Fe sulfide catalyst. A 600 mL continuous stirring tank reactor (composed of 316 stainless steel) was adapted with a feed inlet port in the bottom, a single effluent steam port, three thermocouples located in the internal reactor, and a Rushton turbine of six sheets of 1.25 inches in diameter driven by axle. The sulfide catalyst K-Fe (110.3 grams) prepared as described in Example 1 is charged to the reactor. Hydrogen gas is measured at 8,000 Nm3 / m3 (50,000 SCFB) in the reactor and mixed with bitumen (Lloydminster region in Canada). The bitumen enters the reactor through the bottom of the feed inlet port to form a mixture of crude feed and hydrogen. During the reaction run time of 185 hours, the hydrogen gas and the crude feed are continuously poured into the reactor and the product is continuously removed through the effluent steam port of the reactor. The crude feed is poured at a rate of 67.0 g / hr to maintain the liquid level of the crude feed at 60% of the reactor volume. A source of gamma rays 137Cs of 50 millicurie and a scintillation detector of sodium iodide was used to measure the level of liquid in the reactor. The feed of crude and hydrogen gas was contacted with the catalyst at an average internal reactor temperature of 430 ° C. The contact of the crude and hydrogen feed with the catalyst results in a total product in the form of the effluent vapor from the reactor. The effluent vapor from the reactor leaves the vessel through a single top outlet port. The reactor head is heated electrically at 430 ° C to avoid internal condensation of the reactor effluent vapor at the head of the reactor. After leaving the reactor, the effluent vapor from the reactor was cooled and separated in a liquid and gas separator at high pressures and in a low pressure gas and liquid separator to give rise to a liquid stream and a gas stream. The gas stream is sent to a caustic countercurrent flow cleaner to remove acid gases, and then quantified using standard chromatographic techniques. The total product includes, per gram of total product, 0.918 grams of crude product and 0.089 grams of non-condensable hydrocarbon gases. In the reactor, 0.027 grams of solids remain per gram of crude feed. The properties and compositions of the crude product and the non-condensable hydrocarbon gases produced by this method are summarized in Table 1 in Figure 8, Table 2 of Figure 9, and Table 3 of Figure 10. This example demonstrates that there is a method for the contact of the crude feed with hydrogen in the presence of a transition metal sulfide catalyst to produce a total product with minimal coke generation. The total product included a crude product that was a liquid mixture to STP and that has maximum 0.1 grams of non-condensable hydrocarbon gases per gram of total product. If we compare the results of the MCR content of the crude feed (13.7%) in Table 1 with the solids formed during the process (2.7% p), it is possible to see that the combination of the controlled conditions and the catalyst produced in coke quantities less than those indicated by the ASTM D4530 method. The non-condensable hydrocarbons include C2, C3 and C4 hydrocarbons. From the sum of the percentages by weight of the C2 hydrocarbons listed in Table 2 (20.5 grams), the ethylene content per gram of total C2 hydrocarbon can be calculated. The C2 hydrocarbons of the hydrocarbon gases included 0.073 grams of ethylene per gram of total C2 hydrocarbons. From the sum of the percentages by weight of the C3 hydrocarbons listed in Table 2 (23.9 grams), the propene content per gram of total C3 hydrocarbons can be calculated. The C3 hydrocarbons of the non-condensable hydrocarbon gases included 0.21 grams of propene per gram of total C3 hydrocarbons. The. hydrocarbons C of the non-condensable hydrocarbon gases had a weight ratio of isobutane and n-butane of 0.2. This example demonstrates that the method used to produce a crude product that includes at least 0.001 grams of hydrocarbons with a boiling range distribution of maximum 204 ° C (400 ° F) to 0.101 MPa, at least 0.001 grams of hydrocarbons with a distribution from the boiling range between 204 ° C and 300 ° C to 0.101 MPa, at least 0.001 grams of hydrocarbons with a boiling point distribution between 300 ° C and 400 ° C at 0.101 MPa, and at least 0.001 grams of hydrocarbons with a boiling point distribution between 400 ° C and 538 ° C (1000 ° F) at 0.101 MPa. The hydrocarbons that had a boiling point distribution lower than 204 ° C included isoparaffins and n-paraffins, and the ratio of said isoparaffins to n-paraffins was maximum 1.4. The crude product included boiling points that are associated with naphtha, kerosene, diesel and GOV. The crude product had at least 0.001 grams of naphtha and the naphtha fraction of the crude produced a number of octanes of at least 70. The naphtha fraction of the crude product has a benzene content of maximum 0.01 grams of benzene per gram of naphtha. The naphtha fraction of the crude product had maximum 0.15 grams of olefins per gram of naphtha. The naphtha fraction of the crude product had maximum 0.1 grams of monocyclic aromatic compounds per gram of naphtha. The crude product has at least 0.001 grams of kerosene. The kerosene fraction of the crude product had a freezing point below -30 ° C. The kerosene fraction of the crude product included aromatics, and the kerosene fraction of the crude product had an aromatics content of at least 0.3 grams of aromatics per gram of kerosene. The kerosene fraction of the crude product had at least 0.2 grams of monocyclic aromatic compounds per gram of kerosene. The crude product has at least 0.001 grams of diesel. The diesel fraction of the crude product includes aromatics, and the diesel fraction of the crude product had an aromatic content of at least 0.4 grams of aromatics per gram of diesel compound. The raw product has at least 0.001 grams of GOV. The GOV fraction of the crude product included aromatic compounds, and the GOV had an aromatic content of at least 0.5 grams of aromatics per gram of GOV. Example 3. Preparation of a K-Fe sulfide catalyst without hydrocarbon diluent. A K-Fe sulfide catalyst is prepared by combining 1000 grams of iron oxide (Fe203) and 173 g of potassium carbonate with 423 grams of deionized water to form a wet paste. The wet paste is processed as described in Example 1 thus forming a solid intermediate. The solid intermediate was passed through a 40 mesh screen with minimal force. Unlike example 2, the solid intermediate is mixed with elemental sulfur without hydrocarbon diluent. In a dry chamber using an argon atmosphere, the solid intermediate is mixed with elemental sulfur in a powder form, placed in a sealed carbon steel cylinder, heated to 400 ° C, and maintained at 400 ° C for 1 hour. . The sulfhydrated catalyst is recovered from the carbon steel reactor as a solid. The potassium-iron sulfide catalyst is fractionated in a powder with a mortar so that the resulting catalyst powder is passed through the 40-mesh molecular sieve. The resulting iron-potassium sulfide catalyst was analyzed by diffraction-diffraction techniques. X-rays. From the X-ray diffraction analysis, it was determined that the catalyst included pyrite (FeS2), iron sulphide (FeS), and pyrrhotite (Fe? -xS). The combined species of iron oxide and iron and potassium sulfide are not detected by X-ray diffraction techniques. Example 4. Contact of a crude feed with a hydrogen feed in the presence of a K-Fe sulfide catalyst at a rate gaseous hydrogen greater towards the crude feed. The apparatus, the crude feed and the reaction procedure were those described in Example 2, with the difference that the ratio of hydrogen gas and crude feed was 16,000 Nm3 / m3 (100,000 SCFB). The sulfide catalyst K-Fe (75.0 grams) prepared as described in Example 3 is charged to the reactor. Table 1 of Figure 8 and Table 3 of Figure 10 summarize the properties of the crude product produced by this method. The weight percentage of the GOV produced in Example 4 is greater than the weight percentage of the GOV produced in Example 2. The weight percentage of the distillate produced in Example 4 is less than the weight percentage of the distillate produced in Example 2 The API gravity of the crude product produced in Example 4 is lower than the API gravity of the crude product produced in Example 2. A higher API gravity indicates that hydrocarbons with higher carbon numbers are produced.

After contact with the crude feed, the TMS catalyst of the reactor is analyzed. From this analysis it is deduced that the transition metal catalyst included K3Fe? 0S? after being in the presence of crude oil and hydrogen. Example 5. TAP test of catalyst K2C03 / Rb2C? 3 / Cs2C? 3 and of the individual inorganic salts. In all TAP tests, 300 mg of sample is heated in a TAP system reactor from room temperature (27 ° C) to 500 ° C at a rate of 50 ° C per minute. The water vapor emitted and the carbon dioxide emitted are monitored with a mass spectrometer from the TAP system. The alumina-supported catalyst K2C03 / Rb2CO3 / Cs2C03 proved to have an increase in current of more than 0.2 volts per carbon dioxide emitted and an increase in the 0.01 volt current of water emitted from the inorganic salt catalyst at 360 ° C. The minimum TAP temperature was 360 ° C, as determined by plotting log 10 of the iron current versus temperature. Figure 11 is a graphical representation of the log 10 curves of the ionic current of gases emitted from the catalyst K2C03 / Rb2C03 / Cs2C03 ("log (I)") versus temperature ("T"). Curves 168 and 170 are logarithmic values of iron currents for emitted water and C02 emitted from inorganic salt catalysts. The acute increases for water and C02 emitted from inorganic salt catalysts take place at 360 ° C. Unlike what happens with the catalyst K2C03 / Rb2C03 / Cs2C03, the potassium carbonate and the cesium carbonate had no detectable current increases at 360 ° C both for the water and for the carbon dioxide emitted.

The substantial increase in gas emitted for the catalyst 2C03 / Rb2C03 / Cs2C03 demonstrates that catalysts of inorganic salts composed of two or more different inorganic salts can be more disordered than the individual pure carbonate salts. Example 6. DSC test of inorganic salt catalyst and individual inorganic salts. Throughout the DSC test, 10 mg of sample is heated at 520 ° C at a rate of 10 ° C per minute, cooled from 520 ° C to 0.0 ° C at a rate of 10 ° C per minute, and then heated from 0 ° C at 600 ° C at a speed of 10.0 ° C using Differential Calorimetric Scan (DSC) model DSC-7, manufactured by Perkin-Elmer (Norwalk, Connecticut, USA). The DSC analysis of a K2C03 / Rb2C03 / Cs2C03 catalyst during the second heating of the sample shows that the salt mixture had a higher heat transition between 219 ° C and 260 ° C. The midpoint of the temperature range was 250 ° C. The area under the heat transition curve is calculated to be -1.75 Joules per gram. The beginning of the crystal disorder was determined at the beginning at the minimum DSC temperature of 219 ° C. Unlike these results, no defined heat transitions were observed for cesium carbonate. The DSC analysis of the mixture of K2C03, Li2C03 and Na2C03 during the second heating of the sample shows that the mixture of K2C03, LiC03 and Na2C03 had a higher heat transition between 390 ° C and 400 ° C. The midpoint of the temperature range was 385 ° C. The area under the heat transition curve is calculated to be -182 Joules per gram. The start of mobility is determined at the beginning of the minimum DSC temperature of 390 ° C. The acute heat transition indicates that the salt mixture is substantially homogeneous. Example 7. Ionic Conductivity Test of an inorganic salt catalyst or an individual inorganic salt in relation to K2CQ3. The entire test was carried out by placing 3.81 cm (1.5 inches) of the inorganic salt catalysts or the individual inorganic salts in a quartz vessel with separate platinum or copper wires, but immersed in a sample in an oven. porcelain. The cables are connected to a dry cell of 9.55 volts and a limited current resistor of 220, 000 ohms. The porcelain oven was heated to 600 ° C and the current was measured using a microammeter. Figure 12 is a graphical representation of the logarithmic curves of the strength of the sample in relation to the potassium carbonate resistance ("log (r K2C03)") versus temperature ("T"). The curves 172, 174, 176, 178, and 180 are logarithmic curves of the K2C03 resistance, CaO resistance, K2C03 / Rb2C03 / Cs2C03 catalyst resistance, Li2C03 / KC03 / Rb2C03 / Cs2C03 catalyst resistance, and Na2C03 / K2C03 catalyst resistance / Rb2C03 / Cs2C03, respectively. The CaO curve (curve 174) has relatively high stable resistance in relation to K2C03 (curve 172) at temperatures in the range of 380-500 ° C. A stable resistance indicates an ordered structure or ions that tend not to move with each other during heating. The catalyst of K2C03 / Rb2C03 / Cs2C03, the catalyst of Li2C03 / K2C03 / Rb2C03 / Cs2C03 and the catalyst of Na2C03 / K2C03 / Rb2C03 / Cs2C03 (see curves 176, 178, and 180) show a slight decrease in resistivity in relation to with K2C03 at temperatures of 350 - 500 ° C. The decrease in resistivity usually indicates that current flow is detected during voltage application to the cables immersed in the inorganic salt catalyst. The data in Figure 12 demonstrate that inorganic salt catalysts are generally more mobile than pure inorganic salts at temperatures between 350-600 ° C.

Figure 13 is a graphical representation of the logarithmic curves of catalyst Na2C03 / K2C03 / Rb2C03 / Cs2C03 in relation to the resistance of K2C03 ("log (r K2C03)") versus temperature ("T"). Curve 182 is a graph of the catalyst ratio Na2C03 / K2C03 / Rb2C03 / Cs2C03 relative to the resistance of K2C03 (curve 172) versus temperature during heating of the catalyst Na2C03 / K2CO3 / Rb2C03 / Cs2CO3. After heating, the catalyst Na2C03 / K2C03 / Rb2C03 / Cs2C03 is cooled to room temperature and then heated in the conductivity apparatus. Curve 184 is a log of resistance resistance of the catalyst Na2C03 / K2C03 / Rb2C03 / Cs2C03 in relation to the resistance of K2C03 versus temperature during heating of the inorganic salt catalyst after cooling from 600 ° C to 25 ° C. The ionic conductivity for the reheated Na2C03 / K2C03 / Rb2C03 / Cs2C03 catalyst increased in relation to the ionic conductivity of the original Na2C03 / K2C03 / Rb2C03 / Cs2C03 catalyst. From the difference of ionic conductivities of the inorganic salt catalyst during the first and second heating, it can be concluded that the inorganic salt catalyst forms a different form (second form) upon cooling which is not the same as the form (first form) before let there be heating Example 8. Testing of circulation property of an inorganic salt catalyst. A powdered K2C03 / Rb2C03 / Cs2C03 catalyst with a layer 1-2 cm thick is placed on a quartz plate. The disc is placed in the oven and heated at 500 ° C for 1 hour. To determine the circulation properties of the catalyst, the dish is manually tilted in the oven after heating. The catalyst K2C03 / Rb2C03 / Cs2C03 does not circulate. When pressed with a spatula the catalyst has a pasty consistency. On the other hand, the individual carbonate salts are in the form of free-flowing powders under the same conditions. The catalyst Na2C03 / K2C03 / Rb2C03 / Cs2C03 became liquid and flows rapidly (for example as water) in the dish under the same conditions. Examples 9-10; Contact of a Crude Feed with a Hydrogen Source in the Presence of a K2C Catalyst? 3 / Rb2C03 / Cs2C03 and Steam. The following equipment and general procedure were employed in Examples 9-27 except where variations are described. Reactor: A Hastelloy C Parr autoclave (Parr Model # 4576) of 250 mL calibrated at 35 MPa (5000 psi) working pressure and 500 ° C, was adapted with a mechanical stirrer and an 800 watt Gaummer heating band in a Eurotherm controller capable of maintaining the autoclave at ± 5 ° C from ambient temperature up to 625 ° C, a gas inlet port, a steam inlet port, an outlet port, and a thermocouple to record the internal temperature. Before heating, the upper part of the autoclave was insulated with fiberglass. Addition vessel. An addition vessel (250 mL stainless steel Hoke vessel) was equipped with a controlled heating system, an appropriate gas control valve, pressure relay devices, thermocouples, a pressure gauge and a high temperature control valve ( Swagelok valve # SS-4UW) capable of regulating the flow of a hot, viscous and / or pressurized crude feed at a flow rate of 0-500 g / min. The outlet side of the high temperature control valve was connected to the first inlet port of the reactor after the crude feed was charged to the addition vessel. Prior to use, the line of the addition vessel was isolated. Product Collection. The steam from the reactor exited through the outlet port and was introduced into a series of cold temperature-reducing traps (submerged tubes connected to a series of Hole stainless steel 316 containers of 150 mL). Liquid vapor was condensed in the cold traps to form a gas stream and a stream of condensed liquid. Regulated the steam flow rate from the reactor and through the cold traps, as required, using a counter pressure regulator. The flow velocity and the total volume of gas for the gas stream leaving the cold traps were measured using a wet type meter (Ritter wet type meter model # TG 05). After leaving the meter, the gas stream was collected in a gas bag (collection bag for Tediar gas) 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 condensed liquid stream was removed from the cold traps and weighed. The crude product and water were separated from the condensate stream. The crude product was weighed and analyzed. Process. Crudo Cerro Negro (137.5 grams) was charged to the addition vessel. The crude feed had an API gravity of 6.7. The crude feed had, per gram of crude 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 crude feed was heated to 150 ° C. The K2C03 / Rb2C03 / Cs2C03 catalyst (31.39 grams) was charged to the reactor. The K2C03 / Rb2C03 / Cs2C03 catalyst was prepared by combining 16.44 grams of K2C03, 19.44 grams of Rb2C03 and 24.49 grams of Cs2C03. The K2C03 / Rb2C03 / Cs2C03 catalyst had a minimum TAP temperature of 360 ° C. The K2C03 / Rb2C03 / Cs2C03 catalyst had a DSC temperature of 250 ° C. The individual salts (K2C03, Rb2C03 and Cs2C03) did not show DSC temperatures in a range of 50-500 ° 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 ° C under a flow at atmospheric pressure of methane of 250 cm 3 / min. After reaching the desired reaction temperature, steam was supplied to the reactor at a rate of 0.4 mL / min and methane at a rate of 250 cm3 / min. Steam and methane were measured continuously during the addition of the crude feed to the reactor for 2.6 hours. The crude feed was pressurized into the reactor using 1.5 MPa (229 psi) of CH4 for 16 minutes. The residual crude feed (0.56 grams) remaining in the addition vessel was completed after the addition of the crude feed. A decrease in temperature was observed at 370 ° C during the addition of the crude feed. The catalyst / crude feed mixture was heated to the reaction temperature of 450 ° C and maintained at that temperature for 2 hours. After two hours, the reactor was cooled and the resulting residue / catalyst mixture was weighed to determine a percentage of coke produced and / or not consumed in the reaction. For the difference between the initial catalyst weight and the weight of the coke / catalyst mixture, 0.046 grams of coke remained in the reactor per gram of crude feed. The total product included 0.87 grams of crude product with an average API gravity of 13 and gas. The gas included unreacted CH4, hydrogen, C2 and C4-C6 and C02 hydrocarbons (0.08 grams of C02 per gram of gas). The crude product had, per gram of crude product, 0.01 grams of sulfur and 0.000005 grams of Ni and total V. The crude product was not analyzed further. For Example 10, the reaction procedures, conditions, crude feed and catalyst were the same as in Example 9. The crude product of Example 10 was analyzed to determine the boiling range distributions of the crude product. The crude product had, per gram of crude product, 0.14 grams of naphtha, 0.19 grams of distillates and 0.45 grams of vacuum gas oil (VGO), and residual content of 0.001 grams, and undetectable amounts of coke. Examples 9 and 10 demonstrate that the contact of the crude feed with a source of hydrogen in the presence of at least 3 grams of catalyst per 100 grams of crude feed generates a total product including a crude product which is a liquid mixture of standard conditions of temperature and pressure (STP). The crude product had a residual content of up to 30% of the residue content of the crude feed. The crude product had a sulfur content and a total Ni / V content of up to 90% of the sulfur content and Ni / V in the charge. The crude product included 'at least 0.001 grams of hydrocarbons with a boiling range distribution of at least 200 ° C to 0.101 MPa, at least 0.001 grams of hydrocarbons with a boiling range distribution between 200 - 300 ° C to 0.101 MPa, at least 0.001 grams of hydrocarbons with a boiling range distribution between 400 - 538 ° C (1000 ° F) at 0.101 MPa. Example 11-12: Contact of a Crude Feed with a Hydrogen Source in the Presence of a Catalyst of K2C03 / Rb2C03 / Cs2C03 and Steam. The reaction procedures, conditions and the K2C03 / Rb2C03 / Cs2C03 catalyst in Examples 11 and 12 were the same as in Example 9, except that 130 grams of crude feed (Cerro Negro Crude) and 60 grams of catalyst were used. of K2C03 / Rb2C03 / Cs2C03. In Example 11, methane was used as a source of hydrogen. In Example 12, hydrogen gas was used as the source of hydrogen. A graphical representation of the quantities of non-condensable gas, crude product and coke is shown in Figure 14. Bars 186 and 188 represent the% by weight of produced coke, bars 190 and 192 represent the% by weight of liquid hydrocarbons produced and bars 194 and 196 represent% by weight of gas produced based on the weight of the crude feed. In Example 11, 93% by weight of crude product (bar 192), 3% by weight of gas (bar 196) and 4% by weight of coke (bar 188) were produced, based on the weight of Crudo Cerro Negro . In Example 12, 84% by weight of product crude (bar 190), 7% by weight of gas (bar 194) and 9% by weight of coke (bar 186) were produced, based on the weight of Crudo Cerro Negro. Examples 11 and 12 provide a comparison of the use of methane as a source of hydrogen and the use of hydrogen gas as a source of hydrogen. Methane is generally less expensive to produce and / or transport than hydrogen, so a process using methane is desirable. As demonstrated, methane is at least as effective as hydrogen gas as a source of hydrogen when a crude feed is contacted in the presence of an inorganic salt catalyst to produce a total product. Examples 13 - 14: Production of a Crude Product with a Selected API Gravity. The apparatus, reaction procedure and the inorganic salt catalyst were the same as in Example 9, except that the reactor pressure varied. In Example 13, the reactor pressure was 0.1 MPa (14.7 psi) during the contact period. A crude product with API gravity of 25 to 15.5 ° C was produced. The total product had hydrocarbons with a distribution of carbon numbers in a range of 5 to 32 (see curve 198 in figure 15). In Example 14, the reactor pressure was 3.4 MPa (514.7 psi) during the contact period. A crude product with an API gravity of 51.6 to 15.5 ° C was produced. The total product had hydrocarbons with a distribution of carbon numbers in a range of 5 - 15 (see curve 200 in figure 15). These examples demonstrate methods for contacting the crude feed with hydrogen in the presence of an inorganic salt catalyst at different pressures to generate a crude product with a selected API gravity.

By varying the pressure, a crude product with greater or lesser API severity was produced. Examples 15-16: Contact of a Crude Feed in the Presence of a K.2C03 / Rb2C03 / Cs2C03 Catalyst or Silicon Carbide in the Absence of an External Hydrogen Source. In Examples 15 and 16, the apparatuses, crude feed and reaction procedure were the same as in Example 9, except that the crude feed and the catalyst (or silicon carbide) were charged directly into the reactor at the same time. weather. Carbon dioxide (C0) was used as the entrainment gas. In Example 15, 138 grams of Cerro Negro Crude was combined with 60.4 grams of the K2C03 / Rb2C03 / Cs2C03 catalyst (same catalyst as in Example 9). In Example 16, 132 grams of Cerro Negro Crude were combined with 83.13 grams of silicon carbide (Mesh 40, Stanford Materials, Aliso Viejo, C.A.). It is estimated that such silicon carbide possesses low,. or null, catalytic property under the process conditions described herein. In each example, the mixture was heated to the reaction temperature of 500 ° C for a period of 2 hours. The C02 was supplied to the reactor at a rate of 100 cm3 / min. The steam generated from the reactor was collected in the cold traps and in a gas bag using a counter pressure of 3.2 MPa (479.7 psi). The crude product of the traps met and analyzed. In Example 15, 36.82 grams (26.68% by weight based on the weight of the crude feed) of a colorless liquid hydrocarbon with an API gravity of at least 50 was produced by the contact of the crude feed with a salt catalyst inorganic in an atmosphere of carbon dioxide. In Example 16, 15.78 grams (11.95% by weight based on the weight of the crude feed) of a yellow liquid hydrocarbon with an API gravity of 12 was produced by the contact of the crude feed with silicon carbide in an atmosphere of carbon dioxide. Although the performance in Example 15 is low, the in situ generation of a hydrogen source in the presence of an inorganic salt catalyst is greater than the in-generation of hydrogen under non-catalytic conditions. The yield of crude product in Example 16 is half the yield of crude product in Example 15. Example 15 also demonstrates that hydrogen is generated during contact of the crude feed in the presence of the inorganic salt and in the absence of a hydrogen gas source. Examples 17 -20: Contact of a Crude Feed with a Hydrogen Source in the Catalyst Presence of K2C03 / bC? 3 / Cs2C03 / Calcium Oxide and Silicon Carbide to Atmospheric Conditions. The apparatus, the reaction procedure, the crude feed and the inorganic salt catalyst were the same as in Example 9, except that the Cerro Negro Oil was added directly to the reactor instead of adding it through the addition vessel and He used hydrogen gas as a source of hydrogen. The reactor pressure was 0.101 MPa (14.7 psi) during the contact period. The flow rate of hydrogen gas was 250 cm3 / min. Reaction temperatures, vapor flow rates and percentages of crude product, gas and coke produced are tabulated in Table 4, Figure 16. In Joints 17 and 18 the K2C03 / Rb2C03 / Cs2C03 catalyst was used. In Example 17, the contact temperature was 375 ° C. In Example 18, the contact temperature was in a temperature range of 500-600 ° C. As shown in Table 4 (Figure 16), for Examples 17 and 18, when the temperature was increased from 375 ° C to 500 ° C, gas production increased from 0.02 grams to 0.05 grams of gas per gram. of total product. The production of coke, however, decreased from 0.17 grams to 0.09 grams of coke per gram of crude feed at the highest temperature. The sulfur content in the crude product also decreased from 0.01 grams to 0.008 grams of sulfur per gram of crude product at the highest temperature. Both raw product had an H / C of 1.8. In Example 19, a crude feed was contacted with CaCO3 under conditions similar to the conditions described for Example 18. The percentages of crude product, gas and coke production are tabulated in Table 4, Figure 16. The production gas was increased in Example 19 in relation to the gas production in Example 18. The desulfurization of the crude feed was not as effective as in Example 18. The crude product generated in Example 19 had, per gram of crude product, 0.01 grams of sulfur compared to the sulfur content of 0.008 grams per gram of crude product for the crude product obtained in Example 18. Example 20 is a comparative example for Example 18. In Example 20, charged 83.3 grams of silicon carbide to the reactor instead of the inorganic salt catalyst. The gas and coke production was significantly increased in Example 20 in relation to the gas and coke production of Example 18. Under these non-catalytic conditions, 0.22 grams of coke were produced per gram of crude product, 0.25 grams of non-condensable gas and 0.5 grams of raw product. The crude product produced in Example 20 had 0.036 grams of sulfur per gram of crude product, compared to 0.01 'grams of sulfur per gram of crude product produced in Example 18. These examples demonstrate that the catalyst used in Examples 17 and 18 provides improved results on non-catalytic conditions and conventional metal salts. At 500 ° C, and at a hydrogen flow rate of 250 cm 3 / min, the amounts of coke and non-condensable gas were significantly lower than the amounts of coke and non-condensable gas produced under non-catalytic conditions. In the examples using inorganic salt catalysts (see examples 17-18 in Table 4, Figure 16), a decrease in the weight percentage of gas produced relative to the produced gas formed during the control experiment was observed ( for example, Example 20 in Table 4, Figure 16). Of the amount of hydrocarbons in the produced gas, the thermal disintegration of the crude feed is estimated to be maximum 20% by weight, maximum 15% by weight, maximum 10% by weight, maximum 5% by weight, or nothing, based on the total amount of the crude feed put in contact with a source of hydrogen. Examples 21-22: Contact of a Crude Feed with a Gaseous Hydrogen Source in the Presence of Water and a Catalyst of K2C03 / Rb2CQ3 / Cs2C03 or Silicon Carbide. The apparatus in Examples 21 and 22 was the same as in Example 9, except that hydrogen gas was used as a source of hydrogen. In Example 21, 130.4 grams of Cerro Negro Crude was combined with 30.88 grams of K2C03 / Rb2C03 / Cs2C03 catalyst to form a crude feed mixture. In Example 22, 139.6 grams of Cerro Negro Crude was combined with 80.14 grams of silicon carbide to form the crude feed mixture. The crude feed mixture was charged directly to the reactor. The hydrogen gas was supplied at 250 cm3 / min in the reactor during the heating and temperature holding periods. The crude feed mixture was heated at 300 ° C for 1.5 hours and kept at 300 ° C for 1 hour. The reaction temperature was increased to 400 ° C in 1 hour and maintained at 400 ° C during 1 hour. After the reaction temperature reached 400 ° C, water was introduced to the reactor at a rate of 0.4 grams / min "in combination with hydrogen gas.Water and hydrogen were supplied to the reactor for the remaining periods of heating and holding the temperature. After maintaining the reaction mixture at 400 ° C, the reaction temperature was increased to 500 ° C and maintained at 500 ° C by 2 hours . The steam generated from the reactor was collected in the cold traps and in a gas bag. The liquid product of the cold traps collected and analyzed. In Example 21, 86.17 grams (66.1% by weight, based on the weight of the crude feed) of a dark reddish brown liquid hydrocarbon (crude product) and water (97.5 grams) were produced from the feed contact crude with the catalyst K2C03 / Rb2C03 / Cs2C03 under a hydrogen atmosphere. In Example 22 steam and a small amount of reactor gas were produced. The reactor was inspected and a viscous dark brown liquid hydrocarbon was removed from the reactor. Less than 50% by weight of the dark brown viscous liquid was produced at the contact of the crude feed with silicon carbide in the hydrogen atmosphere. An increase of 25% yield of crude product was observed in Example 21 in relation to a crude product yield produced in Example 22. The. Example 21 demonstrates an improvement in the properties of the crude product produced using the methods described herein in relation to the raw product produced using hot water. Specifically, the crude product in Example 21 had lower boiling than the crude product of Example 22, as demonstrated by the crude product produced in Example 22 which was not capable of being produced as steam. The crude product produced in Example 21 had outstanding flow properties with respect to the crude product produced in Example 22, as determined by visual inspection. Examples 23 - 24: Contact of a Crude Feed with a Hydrogen Source in the Presence of a KC03 / Rb2C03 / Cs2C03 Catalyst to Produce a Crude Product with Higher Volume in Relation to the Volume of Crude Product Produced under Non-Catalytic Conditions. The apparatus, the crude feed, inorganic catalyst and the reaction procedure were the same as those described in Example 9, except that the crude feed was introduced directly into the reactor and hydrogen gas was used as a source of hydrogen. The crude feed (Crudo Cerro Negro) had an API gravity of 6.7 and a density of 1.02 g / mL at 15.5 ° C. In Example 23, 102 grams of crude feed (100 mL of crude feed) and 31 grams of K2C03 / Rb2C03 / Cs2C03 catalyst were fed 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 ° C (112 mL) was produced. In Example 24, 102 grams of crude feed (100 mL of crude feed) and 80 grams of silicon carbide were charged to the reactor. A crude product was produced (70 grams) with an API gravity of 12 and a density of 0. 9861 g / mL at 15.5 ° C (70 mL). Under these conditions, the volume of crude product produced in Example 23 was approximately 10% greater than the crude feed volume. The volume of crude product produced in Example 24 was significantly lower (40% lower) than the volume of crude product produced in Example 23. A significant increase in volume improves the producer's ability to generate more volume of crude product by volume of oil. Raw at the entrance. Example 25: Contact of a Crude Feed with a Hydrogen Source in the Presence of a Catalyst of K2C03 / Rb2C03 / Cs2C03, Sulfur and Coke. The apparatus and the reaction procedure were the same as in Example 9, except that the steam was supplied to the reactor at 300 cm 3 / min. The catalyst of K2C03 / Rb2C03 / Cs2C? 3 was prepared with the combination of 27.2 grams of K2C03, 32.2 grams of Rb2C03 and 40.6 grams of Cs2C03. The crude feed (130.35 grams) and the K2C03 / Rb2C03 / CsC03 catalyst (31.6 grams) were charged to the reactor. The Cerro Negro Crude included, per gram of crude feed, 0.04 grams of total aromatics content in a boiling range distribution between 149 - 260 ° C (300 - 500 °), 0.000640 grams of combined nickel and vanadium, 0.42 grams of sulfur and 0.56 grams of residue. The API gravity of the crude feed was 6.7. The contact of the crude feed with methane in the presence of K2C03 / Rb2C03 / Cs2C03 catalyst produced, per gram of crude feed, 0.95 grams of total product and 0.041 grams of coke. The total product included, per gram of total product, 0.91 grams of crude product and 0.28 grams of hydrocarbon gas. The total gas collected included, per mole of gas, 0.16 moles of hydrogen, 0.045 moles of carbon dioxide and 0.025 moles of C2 and C4-C3 hydrocarbons, determined by GC / MS. The gas balance was methane, air, carbon monoxide and a trace (0.004 moles) of raw evaporated product. 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 ° C. The total liquid product mixture included 0.006 grams of ethyl benzene (a monocyclic ring compound with a boiling point of 136.2 ° C to 0.101 MPa) per gram of mixture. This product was not detected in the crude feed. The catalyst used ("first used catalyst") was removed from the reactor, weighed and then analyzed. The first catalyst used had an increase in weight of 31.6 grams for a total weight of 37.38 grams (an increase of 18% by weight based on the weight of the original K2C03 / RbC03 / Cs2C03 catalyst). The first catalyst used included 0.15 grams of additional coke, 0.0035 grams of sulfur, 0.0014 grams of Ni / V and 0.845 grams of K2C03 / Rb2C03 / Cs2C03 per gram of catalyst used. An additional crude feed (152.71 grams) was put in contact with the first used catalyst (36.63 grams) to produce 150 grams of total product recovered after losses. The total product included, per gram of total product, 0.92 grams of crude liquid product, 0.058 grams of additional coke and 0.17 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 C2-C5 hydrocarbons. The gas balance was methane, nitrogen, a little air and traces of evaporated oil product (<1% mol). The crude product included a mixture of hydrocarbons with a boiling range between 100 - 538 ° C. The portion of the mixture with a boiling range distribution below 149 ° C included, per mole of total liquid hydrocarbons, 0.018 mole% ethyl benzene, 0.04 mole% toluene, 0.03 mole% meta-xylene and 0.060% molar of para-xylene (monocyclic ring compounds with boiling points below 149 ° C to 0.101 MPa). These products were not detectable in the crude feed. The catalyst used ("second used catalyst") was removed from the reactor, weighed and then analyzed. The second catalyst used had an increase in weight of 36.63 grams for a total weight of 45.44 grams (an increase of 43% by weight based on the weight of the original catalyst KC03 / Rb2C03 / Cs2C03). The second catalyst used included 0.32 grams of coke and 0.01 grams of sulfur and 0.67 grams per gram of the second catalyst used. An additional crude feed (104 grams) was contacted with the second used catalyst (44.84 grams) to produce, per gram of crude feed, 104 grams of total product and 114 grams of coke were collected. A portion of coke was attributed to the formation of coke in the addition vessel due to overheating of the "addition vessel, since 104.1 grams of the 133 grams of crude feed transferred were crude feed, the total product included, per gram of total product, 0.86 grams of crude product and 0.025 grams of hydrocarbon gas The total gas included, per mole of gas, 0.18 moles of hydrogen, 0.052 moles of carbon dioxide and 0.03 moles of C2 - Cs hydrocarbons. gas was methane, air, carbon monoxide, hydrogen sulfide and small traces of evaporated oil.The crude product included a mixture of hydrocarbons with a boiling range between 100 - 538 ° C. The portion of the mixture with a range distribution of boiling below 149 ° C included, per gram of hydrocarbon mixture, 0.021 grams of ethylbenzene, 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 catalyst used ("third used catalyst") was removed from the reactor, weighed and then analyzed. The third catalyst used had an increase in weight of 44.84 grams for a total weight of 56.59 grams (an increase of 79% by weight based on the weight of the original K2C03 / Rb2C03 / Cs2C03 catalyst). A detailed elemental analysis of the third catalyst used was carried out. The third catalyst used included, per gram of additional material, 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 chlorine, the rest being other transition metals such as chromium, titanium and zirconium.

As demonstrated in this example, the coke, sulfur and / or metals deposited on and / or in the inorganic salt catalyst do not affect the overall yield of the crude product (at least 80% for each test) produced by contact of a feed of crude with a source of hydrogen in the presence of the inorganic salt catalyst. The crude product had a monocyclic aromatic content of at least 100 times the monocyclic ring aromatic content of the crude feed in a boiling range distribution below 149 ° C. For all three tests, the average yield of crude product (based on the weight of the crude feed) was 89.7% by weight with a standard deviation of 2.6%; the average yield of coke was 7.5% by weight (based on the weight of the crude feed), with a standard deviation of 2.7% and the average yield by weight of gaseous cracked hydrocarbons was 2.3% by weight (based on the weight of the crude feed) with a standard deviation of 0.46%. The comparatively high standard deviation for both liquid and coke was due to the third test, in which the temperature controller of the feed container failed, overheating the feed of the crude in the addition vessel. Even so, there is no significantly alarming visible effect despite the large amounts of coke tested here on the activity of the catalytic system. The total C2 to C2 olefin ratio was 0.19. The total C3 to C3 olefin ratio was 0.4. The ratio of alpha olefins to internal olefins of C4 hydrocarbons was 0.61. The cis / trans C4 olefins ratio was 6.34. This ratio was substantially higher than the ratio of cis / trans olefins predicted by the thermodynamics of 0.68. The ratio of alpha olefins to internal C5 hydrocarbon olefins was 0.92. This ratio was greater than the ratio of C5 alpha olefins to C5 internal olefins predicted by the thermodynamics of 0.194. The cis / trans C5 olefins ratio was 1.25. This ratio was greater than the cis / trans C5 olefins ratio predicted by the thermodynamics of 0.9. Example 26: Contact of a Crude Feed Containing Relatively High Sulfur with a Source of Hydrogen in the Presence of a Catalyst K2C03 / Rb2C03 / Cs2C03. The aparats and the reaction procedure were the same as in Example 9, except that the feed of crude, methane and steam were continuously fed to the reactor. The feed level in the reactor was monitored using a change in reactor weight. The methane gas was continuously supplied at 500 cm3 / min to the reactor. The steam was continuously supplied at 6 g / min to the reactor.

The inorganic salt catalyst was prepared with the combination of 27.2 grams of K2C03, 32.2 grams of Rb2C03 and 40.6 grams of Cs2C03. The K2C03 / Rb2C03 / Cs2C03 catalyst (59.88 grams) was charged to the reactor. A crude feed (bitumen, Lloydminster, Canada) with an API gravity of 9.4, a sulfur content of 0.02 grams of sulfur and a residual content of 0.40 grams, per gram of crude feed, was heated in the addition vessel at 150 ° C. The hot bitumen was supplied continuously from the addition vessel at 10.5 g / min to the reactor in an attempt to maintain the level of crude feed liquid at 50% of the reactor volume, however, the speed was insufficient to maintain that level . The methane / vapor / crude feed was contacted with the catalyst at an average internal reactor temperature of 456 ° C. When contacting the methane / vapor / crude feed with the catalyst produced a total product (in this example in the form of effluent vapor from the reactor). A total of 1640 grams of crude feed was processed for 6 hours. For the difference between the initial weight of the catalyst and the weight of the waste / catalyst mixture, 0.085 grams of coke per gram of crude feed remained in the reactor. From the contact of the crude feed with the methane in the presence of the catalyst K2C03 / Rb2C03 / Cs2C03, 0.93 grams of total product per gram of crude feed were 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. For the amount of hydrogen sulfide generated, it can be estimated that the sulfur content of the crude feed was reduced by 18% by weight. As shown in this example, hydrogen, carbon monoxide and carbon dioxide were produced. The molar ratio of carbon monoxide to carbon dioxide was 0.04. The C2-C5 hydrocarbons included, per gram of hydrocarbons, 0.30 grams of C2 compounds, 0.32 grams of C3 compounds, 0.26 grams of C4 compounds and 0.10 grams of C5 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. Compounds C4 had, per gram of compound C4, a butadiene content of 0.003 grams. The weight ratio of C alpha olefins to internal C olefins was 0.75. The weight ratio of C5 alpha olefins to C5 internal olefins was 1.08. The data in Example 25 demonstrate that the continuous processing of a crude feed relatively high in sulfur with the same catalyst in the presence of coke did not decrease the activity of the inorganic salt catalyst and produced a crude product suitable for transport. Example 27: Contact of a Crude Feed with a Hydrogen Source in the Presence of a Catalyst of K2C03 / Rb2C03 / Cs2C03 and Coke. The apparatus and the reaction procedure were employed using the conditions described in Example 26. The K2C03 / Rb2C03 / Cs2C03 catalyst (56.5 grams) was charged to the reactor. A total of 2550 grams of raw food was processed for 6 hours. From the difference between the initial weight of the catalyst and the weight of the waste / catalyst mixture, 0.114 grams of coke per gram of crude feed remained in the reactor, based on the weight of the crude feed. A total of 0.89 grams of total product was produced per gram of crude feed. 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 sulphide produced it can be estimated that the sulfur content of the crude feed was reduced by 14% by weight, based on the weight of the crude 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 C2-C3 hydrocarbons included, per gram of C2-C3 hydrocarbons, 0.44 grams of C2 compounds, 0.31 grams of C3 compounds, 0.19 grams of C4 compounds and 0.068 grams of C5 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 C4 compounds had, per gram of C4 compounds, a butadiene content of 0.003 grams. This example demonstrates that the repeated processing of a crude feed relatively high in sulfur (2550 grams of crude feed) with the same catalyst (56.5 grams) in the presence of coke did not decrease the activity of the inorganic salt catalyst and produced a crude product suitable for transport. Further modifications and alternative embodiments of various aspects of the invention will be apparent to those skilled in the art in view of the present disclosure. Consequently, the present description should be considered only as illustrative and for the purpose of teaching those with experience in the art of the general manner of carrying out the invention. It will be understood that the forms of the invention shown and described herein should be taken as examples of modalities. The elements and materials can be replaced by those illustrated and described herein, parts and processes can be reversed and certain features of the invention can be used independently, all as would be evident to someone skilled in the art after having the benefit of the present description of the invention. Changes can be made to the elements described herein without departing from the spirit and scope of the invention as described in the following claims. It is noted that in relation to this date, the best method known to the applicant to carry out the aforementioned invention, is that which is clear from the present description of the invention.

Claims

CLAIMS Having described the invention as above, the content of the following claims is claimed as property:. 1. A crude product characterized by having, per gram of crude product: up to 0.05 grams of waste; at least 0.001 grams of hydrocarbons with a boiling range distribution of up to 204 ° C (400 ° F) at 0.101 MPa, at least 0.001 grams of hydrocarbons with a boiling range distribution between 204 ° C and 300 ° C at 0.101 MPa, at least 0.001 grams of hydrocarbons with a boiling range distribution between 300 ° C and 400 ° C to 0.101 MPa, and at least 0.001 grams of hydrocarbons with a boiling range distribution between 400 ° C and 538 ° C 0.101 MPa; and more than 0 grams, but less than 0.01 grams of one or more catalysts, wherein at least one of the catalysts comprises one or more alkali metals.
2. The crude product according to claim 1, characterized in that at least one of the catalysts shows a change of gas emitted from a gas emitted in a temperature range between 50 ° C and 500 ° C, determined by Temporary Product Analysis (TAP) and / or a heat transition in a temperature range between 200 ° C and 500 ° C, as measured by differential scanning calorimetry at a heating rate of 10 ° C per minute.
3. The crude product according to claim 1 or 2, characterized in that at least one of the catalysts additionally comprises a transition metal.
4. The raw product according to any of claims 1 to 3, characterized in that at least one of the catalysts further comprises a transition metal sulfide.
5. The crude product according to claim 4, characterized in that the atomic ratio of alkali metal to transition metal is in a range from 0 to 1.
6. The crude product according to any of claims 1 to 5, characterized in that the alkali metals comprise sodium, potassium, rubidium, cesium, or mixtures thereof.
7. The crude product according to any of claims 1 to 6, characterized in that at least one of the catalysts comprises bartonite.
8. The crude product according to any of claims 1 to 7, characterized in that at least one of the catalysts further comprises an alkaline earth metal and / or zinc.
9. A method of producing fuel for transportation, fuel for heating, lubricants, or chemicals, characterized in that it comprises processing of a crude product according to any of claims 1 to 8 or a mixture of crude product with a crude.
The method according to claim 9, characterized in that the processing comprises distilling the crude product or the mixture in one or more fractions of distillates.
11. The method according to claim 9 or 10, characterized in that the processing includes hydrotreating.