RU2709515C1 - Fuel composition formed from light oil of low-permeability reservoir and fuel oils with high content of sulfur - Google Patents

Abstract

FIELD: manufacturing technology.

SUBSTANCE: invention relates to fuel for marine or ground application engines, in turbines operating on gas combustion products, or in fire-furnaces containing 100 parts per billion or less of metals containing 0.5 wt% sulfur or less, wherein said fuel contains a range of hydrocarbons from about C5 to about C20 or higher, said hydrocarbons having an initial boiling point which is the lowest boiling point of light oil component of low-permeability reservoirs or lighter materials obtained from said hydroconversion, combined so, and the highest boiling point is the highest boiling point of the component of said cleaned soluble deasphalted oil obtained from furnace oil with high sulfur content or from other oil residues combined in this way. Invention also relates to fuel versions and method of fuel production.

EFFECT: obtaining ultra-pure fuel with very low content of sulfur and nitrogen and, in fact, not containing metals.

13 cl, 1 tbl, 5 dwg

Description

The present invention provides new methods for producing fuel and preparing compositions that simulate fuels having a wide range (from C3 or C5 to C20 or higher) of hydrocarbons produced from crude oil. Preferred crude oils for refining of the present invention are hydrocarbon sources that do not always prefer to use conventional refineries as feedstocks, such as, for example, intermediate refineries, high sulfur fuels, lower sulfur fuels or light oil of low permeability reservoirs, condensates, ultra-heavy crude oil, tar sands and dilbit. The types of fuel proposed by the present invention are ultra-pure fuels with a very low sulfur and nitrogen content and with such a low metal content that it is difficult to detect using many measurement methods, and this fuel is essentially metal free, and it is particularly cost effective not only for use on board large marine transport vessels, but also on land by large land turbines operating on the products of gas combustion, boilers, fire stoves and vehicles, and trains and.

DETAILED DESCRIPTION OF THE INVENTION

BACKGROUND OF THE INVENTION

The present invention aims to at least address three issues: (1) the conversion of low-calorie hydrocarbons to more high-calorie fuels, (2) a cost-effective reduction of sulfur and nitrogen, and the significant elimination of metals from such fuels, and (3) adaptation such fuels for use in marine or land-based engines, in gas-fired turbines, or in fire stoves such as boilers.

Certain hydrocarbon sources are not desirable as raw materials for oil refining and, therefore, can be attributed to low-calorie sources by oil refineries. Conventional refineries seek to split each barrel of crude oil, having a full or wide range of hydrocarbons, into a large number of fuel products and petrochemical feedstocks from the subsequent processing of chemicals. Refineries often prefer petroleum feedstocks having a wide range of hydrocarbons. In order to compete in such an arena, which often has very narrow borders, some refineries require a large part of the full range of hydrocarbon crude oil to balance the material and energy costs needed for refineries that seek to use all the technological operations of the units, as well as fulfillment of supply obligations to customers, but these refineries also prefer to use crude oil that is not It gives problems with the processing or does not increase the processing costs.

Traditional refineries face problems in refining, for example, very heavy types of crude oil, such as Maua (Mexico), BCF-17 (Venezuela) and Oriente (Ecuador), which incurs costs for devices, operating and investment costs that may also arise in the processing of bituminous shale obtained from sedimentary kerogen-containing rocks rich in organic compounds and condensates.

Traditional refineries are also faced with the problems of refining light oil of low-permeability reservoirs, which, compared with crude oil, could be described as “oil that lacks most of the lower fractions of the barrel.” Light oil of low permeability reservoirs (also called simply shale oil), which is now widely available as oil produced from shale and other low permeability formations such as sandstone or carbonate rocks. Compared to traditional types of crude oil, shale oil may contain an excessive amount of light fractions, but relatively little or no hydrocarbons within the ranges that oil refineries may refer to as materials of the heavy oil ranges: the “vacuum gas oil” range or ranges A “heavy oil residue” or “vacuum residue” that boils at a temperature above about 425 ° C. or 565 ° C., respectively, or a range of “lower barrel fractions . See Refining America New Light Tight Oil Production, OPIS 16th Annual National Summit, Las Vegas, October 2014) by Baker & O'Brien (Baker & O'Brien).

The term “shale oil”, “light oil of low permeability reservoirs” or “LTO” as used herein means a wellhead condensate, free natural gas condensate or shale gas condensate having (i) a sulfur content in the ranges from almost unmeasured or lacking content (0) mass. % to 0.2 mass. %, (ii) density, API (city) in the range from 38 to 57 degrees, (iii) traces of metal content and (iv) a wide variety of sources of hydrocarbon ranges. Not all shale oil is the same. The types of LTO obtained from various sources will differ in the ranges of distillate cut fractions. Using the description of the ranges that some refineries can use to characterize the fractions, we can give examples of LTO options that can contain (a) from 5 to 20 masses. % range of liquefied petroleum gas, (b) from 10 to 35 mass. % naphtha, (s) from 15 to 30 mass. % range of kerosene / jet fuel, (d) from 15 to 25 mass. % of diesel fuel and heavier distillates, (e) from traces to 10% or more vacuum gas oils and (f) from the absence of content (0%) to about 5 wt. % or more heavy refinery waste.

Such types of light oil of low permeability reservoirs, especially those that contain a trace of heavy gas oil, and which essentially do not contain or contain a very small amount of heavy refinery waste, do not contain a significant amount of heavier hydrocarbons located in the ranges of their lower fractions in gas oil and ranges of refinery waste in order to ensure the balance of processing for desulfurization or other hydrotreatment, and also do not contain the corresponding refinery waste in the amount of, residual to maintain the hydrogen production process to ensure a cost-effective refining of such light crude oil for hydrotreating in order to reduce the sulfur and metal content required for decontamination, or in order to provide lubricity sufficient to support use in some types engines. See, for example, in the Study of the Properties of Bakken Crude Oil by the North Dakota Oil Council. Characteristics of the Bakken Crude Oil Compiled by the Analytical Group ”(2014) by Turner and Mason (The North Dakota Petroleum Council Study on Bakken Crude Properties. Bakken Crude Characterization Task Force (2014), Turner & Mason), (Turner & Mason) offer song ranges for certain types of shale oil. Those skilled in the art understand that in order to balance a mixture of product streams obtained from a crude oil distillation column so as to fit many oil refining operations, blending shale oil types with heavy asphalt crude oil makes sense, since the compound may lead to the desired a distillation profile for many refineries. However, this practice can also lead to compatibility problems, for example, destabilization of asphaltenes. See the paper “Overcoming the problems of processing shale oil. Processing of Shale Raw Materials (2014) Benoit et al. (Overcoming the Challenges of Tight / Shale Oil Refining. Processing Shale Feedstocks (2014) Benoit et al.).

Refining issues are also faced by traditional refineries using high sulfur fuels or “HSFOs”, which could be described by comparing with crude oil as part of the “lower oil residue of the barrel” or “oil that lacks most of the upper oil residue barrels. " Depending on various applications in the art, the term “high sulfur fuel oil” or “HSFO” has been assigned to various, often heterogeneous, conflicting, and confusing terms in various technical articles, patents, and regulations, some of which change over time. The use in the broad sense of the phrase “high sulfur fuel oil” was used to describe materials in a wide range of ranges, including those that go beyond the use of fuel, starting from a lighter one with a lower boiling point, but with a high sulfur content (and therefore and emitting a large amount of smoke) kerosene to heavy marine bunker fuel with a sulfur content of more than 3.5 mass. % of fuel oil or other heavy oil residual materials of the “lower oil residue of the barrel”, which in some cases do not have a clear or uniformly applied technical characteristic. Some HSFO index reporting systems mean flue oil with a sulfur content of RMG 3.5% fuels in accordance with ISO 8217 specifications, while others use a different sulfur content.

As used in the specification and claims, “high sulfur fuel oil t” or “HSFO” means any material used as fuel with a sulfur content exceeding 0.50% by weight (0.5% by weight). The terms “heavy fuel”, “heavy residual oil”, “refinery waste”, “oil residue” or “other heavier oils”, “tar sands” and “ultra-heavy crude oil”, such as petroleum hydrocarbon materials, as used herein origin with a sulfur content exceeding 0.50% by mass (0.5 mass%). The term "high sulfur content" means the excess of the target limit sulfur content in the fuel or the limit of sulfur established by regulatory legal acts, where applicable, depending on which limit is lower.

Another problem is that markets for high sulfur fuels have shrunk, and a large amount of HSFO cannot be blended or transported. In many countries where power plants burned HSFOs to meet electricity needs, natural gas has been replaced by local gas supplies. For example, during around 2015, Mexico became an HSFO exporter instead of a net importer when power plants switched to local natural gas supplies.

For example, in some parts of the United States, some states have changed their sulfur content requirements for household liquid fuels to 500 ppm by mass or less, instead of 2,000 ppm by mass or higher. This has led to the fact that, for example, some pipelines and distribution networks refuse to transport “high sulfur content fuels,” which has led to overstocking of high sulfur content fuels in some areas, especially where local refineries do not have petroleum feedstocks, devices or technologies for the efficient processing of low sulfur fuels. For many managers of oil refineries, there is practically no choice of options for refining the oil residue, which would allow to receive income from investments in HSFO, and the necessary capital costs would be much lower than with alternative investments. The use of HSFO for turbine fuels leads to corrosion and pollution problems, and loss of reliability.

In the current level of technology, the design of an oil refinery is designed in such a way that atmospheric distillation of crude oil and / or vacuum distillation units, solvent separation, hydrotreating, gasification and many other unit technological operations are used, each barrel of crude oil is divided into a large number of products, each The product has its own technical characteristics, in accordance with various applications or in accordance with further oil refining.

When using hydroskimming in oil refining, crude oil is converted into a large number of products similar to products obtained by distillation of light fractions, but usually a number of heavy naphtha reforming units are added, which also produce hydrogen consumed by hydrotreating units in the production of diesel fuel. Hydro skimming plants, as well as plants for distillation of light fractions, usually produce a wide range of varieties of gasoline, kerosene, diesel fuel and heating oil for local consumption, and not just one product. Various aspects of hydrotreating adaptation are known from the state of the art, including a separate row or zones of parallel hydrotreating plants, or zones of complex hydrotreating reactors. PCT / US1999 / 00478 (1998), published by Cache et al. (Cash et al), and the references cited therein disclose complex hydrotreatment of dissimilar petroleum feedstocks, where hydrogen containing fluids and fluid from separate hydrotreating zones are separated or combined by the method described herein.

Purification of heavy crude oil and refinery waste by hydroconversion of oil residue using fluidized bed reactors was known in the art since fluidized bed systems were previously described in US Pat. Nos. 2,987,465 (1961) and 3,197,288 (1965) by Johanson. The fluidized bed reactor, which includes the contact of gushing heavy hydrocarbon liquids with hydrogen in the presence of a catalyst inside the reactor vessel, with the corresponding various auxiliary gas-liquid separators and make-up hydrogen, and recirculation flows, and sulfur-containing gas purification systems, are well known, and there is a commercial practice of them application in the art. US Pat. No. 6,270,654 to Collier et al. Describes a number of fluidized bed reactors, and US Pat. No. 6,447,671 describes a hydroconversion step by a fluidized bed reactor and a hydrotreating step by means of a fixed bed hydrotreater. In the publication number US20140221713A1 (US13 / 758,429) 2014, Baldassari et al. Describe various catalysts for hydroconversion, hydrocracking and hydrotreating, as well as methods for hydroconversion, hydrocracking and hydrotreating, including options for complex hydroconversion, hydrocracking and hydrotreating. Baldassari et al. Further provides a summary of options for the catalyst compositions and ranges of heavy fuel distillation and hydrotreatment conditions, and provides various conditions for hydrocracking and hydroconversion of oil residue, all of which are known to those skilled in the art of hydroprocessing.

Various aspects of the use of solvent separation to extract deasphalted oil from asphalt in heavy oil residue streams and the use of deasphalted oil as a raw material for hydroprocessing are known in the art for the production of a large number of oil product streams. For example, US patent 7,686,941 (2010) by Brierley et al. (Brierley et al) discusses solvent deasphalting to produce deasphalted oil without cracking or degradation by separating the solubility based feed in a liquid solvent such as propane or another paraffinic solvent such as butane and pentane, and in the asphalt residue, which has a high content of metals and sulfur. In Brierly, deasphalted oil is hydrocracked and hydrotreated to remove sulfur, nitrogen, and metals, as described in this link, to produce several products, including naphtha, kerosene, diesel, and oil residue material.

PCT / FR2006 / 000671 (US 11 / 912,771) 2009 Lenglet describes a crude oil pretreatment process for the production of two types of non-asphaltic oils and asphaltene oils, including pre-distillation, vacuum distillation, solvent deasphalting, hydrotreating, hydrocracking and oil hydroconversion residue for the production of a large number of products. Revamping Diesel Hydrotreaters For Ultra-Low Sulfur Using IsoTherming Technology, Reconstruction of Diesel Hydrotreaters for Ultra-Low Sulfur Content Using IsoTherming Technology, discusses unit design, catalyst selection, hydrogen consumption and other working conditions conditions for removing sulfur by hydrogenation to produce a product having a sulfur content of less than 8 ppm by mass using a highly active nickel / molybdenum (Ni / Mo) catalyst. In “Optimizing Hydroprocessing Catalyst Systems for Hydrocracking and Diesel Hydrotreating Applications, Flexibility Through Catalyst,” Shiflet et al., P. 6 Advanced Refining Technologies Catalagram Special Edition also discusses hydrotreating issues to levels of up to 10 ppm by mass or less by using a highly active cobalt / molybdenum (Co / Mo) catalyst to remove uncomplicated sulfur and a highly active nickel / molybdenum (Ni / Mo) catalyst for the remaining sterically hindered sulfur.

Thus, although many improvements have been made to solve technical problems arising from the processing of light oil of low permeability reservoirs and heavy oil residues in traditional refineries, significant problems have not been resolved. Such problems continue to create technical gaps leading to the underutilization of largely light oil of low permeability reservoirs and high sulfur fuel oils.

SUMMARY OF THE INVENTION

The present invention fills a technical gap by permitting the use of light oil of low permeability reservoirs and high sulfur fuel oil for efficient, low cost production of large quantities of fuel with very low sulfur and nitrogen and substantially no metal content. Such fuels are particularly suitable for use by sea for use at sea, as well as for use by large coastal structures onshore, for example, turbines operating on the products of gas combustion, to generate electricity. Used in the description and in the claims, the terms "essentially free of metals" or "zero metal content" means a metal content in the range from zero to less than 100 parts per billion by mass or less, or a content that is so low that it is difficult accurately measure with conventional online tools.

The present invention provides new methods for preparing a composition of high sulfur fuel oil and light oil of low permeability reservoirs that simulates fuel produced from crude oil, which fuel has a wide range (from C3 and C5 to C20 + or higher) of hydrocarbons. The preferred petroleum feedstocks for the methods of the present invention are hydrocarbon sources that do not always prefer to use conventional refineries as feedstocks, for example, high sulfur fuels or light oil of low permeability reservoirs.

The fuel proposed by the present invention is an ultrapure fuel with a very low sulfur and nitrogen content, and essentially free of metals, and it is especially economically advantageous not only for use on board large marine transport vessels, but also on land by large surface turbines, working on gas products, boilers and vehicles, and trains

In traditional refining, refinery feedstock is divided into a large number of parts, and each part is sent to the corresponding market. In contrast to the above, we found that we can take light oil of low permeability reservoirs from the “upper oil residue of the barrel” and heating oil with high sulfur content from the “lower oil residue of the barrel” and combine them economically to produce fuel that simulates fuel, produced from crude oil and having a wide range of hydrocarbons.

The present invention provides an inexpensive system for combining light oil of low permeability reservoirs with residual oils in an economical manner to produce a large commercial volume of environmentally friendly fuels, which replaces high sulfur bunker fuels and other heavy refinery wastes used in merchant ships and fuel burning power systems . The present invention provides these fuels, as well as methods and apparatus for producing such fuels, in order to reduce emissions of sulfur, nitrogen and harmful metals into the atmosphere in a cost-effective manner. For the shipping industry, the new configurations of the present invention offer low-cost marine fuel with low sulfur levels in quantities necessary to achieve global reduced sulfur goals.

In one embodiment of the present invention, the fuel also provides an alternative to burning crude oil or heavy refinery waste in large onshore gas turbines that are used by utilities, such as single-cycle power plants or combined-cycle power plants such as electric power plants and demineralized water. The turbines burning the fuel of the present invention produce significantly less emissions of turbine flue gases: nitrogen oxides, sulfur oxides, carbon dioxide, soot, harmful metals and other by-products of combustion, as well as less corrosion in their combustion zones or pollution in the conditions of ash formation during combustion of contaminated heavy crude oil or residual oil refining oils, depending on the source of raw materials.

These new methods use counterintuitive steps to reduce production costs while controlling the sulfur content in the final product at or below target sulfur levels in an unexpectedly effective way. In traditional refining, separation of shoulder straps does not occur with their subsequent recombination.

For example, in the traditional blending scheme, the focus is on mixing different grades of oil to form gasoline or mixtures for the formation of diesel fuel, or mixtures for the formation of jet fuel, but not on mixing all the products resulting from individual oil refining processes to form only one type of fuel. That is, crude oil is not separated by distillation into various fractions, followed by recombination of all of them. For example, according to the existing scheme, it is not allowed to obtain blending from any large number of materials in the range of diesel fuel and materials in the range of gasoline. Also, end users are not recommended to receive blending from diesel fuel and gasoline. The same confusion is observed around the terms “kerosene” and “light distillate” due to the fact that these terms often endow with the same, overlapping or even different meanings in different reference materials, instead of giving them a uniform definition, only on the basis of the borders of shoulder straps products in a column of atmospheric distillation of crude oil at temperature ranges (for example, from 190 ° C to 250 ° C or from 180 ° C to 230 ° C or in accordance with another standard developed). For example, the IEA (International Energy Agency) gives the following definition: “Middle distillates: General classification of refined products containing distillate heating oil and kerosene”. Thus, the boundaries of the shoulder straps of oil products at temperature ranges are determined by the technical characteristics of each product obtained from traditional oil refining, which is often set locally and not determined on the basis of sulfur content. In our opinion, this is not the best option.

The term “constituent element” is used herein to reflect unexpected phenomena that we have discovered by “combining constituent elements” in practice of the present invention, or simply obtaining blending from ingredients. The term “ingredient” is usually used when it comes to combining substances by human intervention, when the result is predictable due to the presence of the ingredient. That is, the ingredient, when added, gives the expected characterization of the physical or chemical properties in general.

Traditional refineries do not mix gasoline with diesel fuel or refined residual oils to produce fuel. Instead, epaulets for various types of engines are separated.

What hitherto is not known to specialists in the field of oil refining from the prior art, but disclosed in the present invention, is a new fuel composition, and information on how to select and obtain it, or to obtain from many light (L), medium (M) and heavy (H) constituent elements (which will be given and defined below), and how to best combine the selected constituent elements to form a low sulfur fuel and substantially metal free. This is very similar to a baker who looks at a warehouse full of ingredients for cooking, but who does not have a recipe for making the lowest-calorie pie at the lowest cost, and who does not know that some amazing interaction phenomena occur by cleaning the ingredients and combining them in a certain way .

BRIEF DESCRIPTION OF THE DRAWINGS

FIGURE 1 is a schematic drawing showing the main apparatus and steps of a method for combining crude light oil of low permeability reservoirs with refined high sulfur fuel oil to form very low sulfur fuel.

FIGURE 2 shows a simplified refining of light oil of low permeability reservoirs and high sulfur fuel oils for the production of low sulfur fuel with a correct flash point.

FIGURE 3 is a schematic drawing showing the arrangement of the device and the steps of the method for using crude oil either separately or with light oil of low permeability reservoirs and high sulfur fuel oil for producing ultrapure fuels having a very low content of sulfur, nitrogen and metals.

FIGURES 4 and 5 show new fuels and recipes for combinations of at least one Component element containing light (L), medium (M) and / or heavy (H) materials to form such a fuel.

FIGURE 4 is a schematic drawing showing the volume fraction and density profile of the reference fuel produced by the method of the present invention and its (L), (M) and (H) ranges.

FIGURE 5 shows the volume fraction and density profile of the reference light condensate, which can be used as the constituent elements of the “upper oil residue of the barrel” (having a natural majority (L) of materials, a small amount of natural (M) and (H) materials), which combine with the addition of (H) from another source, such as a constituent element of the “lower oil residue of a barrel” (H) to form the fuel of the present invention.

DETAILED DESCRIPTION OF EMBODIMENTS OF THE INVENTION

The present invention provides a method for converting various hydrocarbon petroleum feedstocks obtained from sources other than conventional crude petroleum, either separately or together with conventional petroleum feedstocks to form a fuel having a wide range of hydrocarbons. In embodiments of the present invention, fuels formed from petroleum feeds consisting of light oil of low permeability reservoirs and petroleum feeds consisting of high sulfur fuel oils have a wide range of hydrocarbons containing hydrocarbons having from the lowest boiling point to light oil of low-permeability reservoirs, forming the aforementioned fuel, to a maximum boiling point of liquids subjected to hydroconversion, obtained from high-fuel oil Erzhanov sulfur to form the aforementioned fuel.

In one embodiment of the present invention, at least one type of high sulfur fuel oil is fed to the oil residue hydroconversion zone and contacted with hydrogen in the presence of a catalyst under oil residue hydroconversion conditions in a fluidized bed reactor to form (1) an effluent from a hydroconversion reactor that is separated into hydroconverted liquid products, purge gases containing hydrogen and sulfur, and (2) unconverted oils that are sent to solvent separation. Such unconverted oil is sent to form (A) a soluble deasphalted oil that is recycled as a petroleum feed in the hydroconversion reactor or separately, or in a place with added petroleum feed consisting of high sulfur fuels, in the aforementioned reactor and (B) insoluble asphalt , which is directed to the cleaning of asphalt. The fuel product is formed by combining all or at least one portion of light oil of low permeability reservoirs with the aforementioned hydroconverted liquid products. In one embodiment of the present invention, before being used as part of a combination, light oil of low permeability reservoirs is fractionated to remove the upper refinery gases so as to leave the bottom fractions of the distillation column which are combined with the liquid products obtained in the hydroconversion zone to form fuel. In another embodiment of the present invention, a portion of the petroleum feed intended for solvent separation includes added high sulfur fuel oil that is directly added to the solvent separation or combined with unconverted oil from the hydroconversion reactor to feed into the solvent separation. In addition, the additional sulfur-rich heating oil may be combined with the aforementioned soluble deasphalted oil in order to form a portion of the petroleum feed to the hydroconversion reactor. In order to set the flash point and, for other reasons, light oil of low permeability reservoirs can be fractionated before being added to the fuel combination to remove the upper refinery gases to form a lighter fraction of the upper zone containing naphtha hydrocarbons and the lower fraction with a higher boiling point. In one embodiment of the present invention, at least one portion of such a lighter fraction contains a large amount of naphtha and can be sent to a reformer or to undergo another process operation of an aromatics production unit where it is brought into contact with hydrogen under conditions reforming to form light oil low permeability reservoirs. In another embodiment of the present invention, the entire stream or portion of the aforementioned light purified stream, the crude light stream and a high boiling lower fraction are combined with the aforementioned hydroconversion liquids to form a fuel. In yet another embodiment of the present invention, the effluent from the hydroconversion reactor can be separated by fractionation into a number of purified liquid fractions, at least one of these fractions having a sulfur content above the target sulfur content, which is sent as part of the crude oil to the reactor hydroconversion of oil residue or, as part of the crude oil, to solvent separation.

In one embodiment of the present invention, the oil residue hydroconversion zone combines the oil residue hydroconversion reactor with a hydrotreater of a heavy fuel range feedstock and a distillate range hydrotreater, combining at least one gas and liquid separators, hydrogen streams, purge gases, sulfur recovery steps and total recovery of purified liquids. In another embodiment of the present invention, such a combination is configured to allow the recovery of individual purified liquids so as to measure the sulfur content of each individual stream and adjust the volume of the stream entering the pool to form a fuel having actual sulfur content corresponding to or below the target sulfur content. In one embodiment of the present invention, the stream of refined products coming from the upper zone of the stream leaving the zone of the hydroconversion reactor can be separated by fractionation into a certain amount of liquid fractions that have undergone hydroconversion, at least one such fraction having a sulfur content exceeding the target sulfur content is sent to a separate hydrotreatment zone for contacting with hydrogen in the presence of a catalyst under hydrotreating conditions to form hydrotreated a stream with a reduced sulfur content having a sulfur content below the target sulfur level, and then such a hydrotreated stream is combined with other liquid fractions that have undergone a hydroconversion and with the aforementioned crude stream obtained from light oil of low permeability reservoirs to form a fuel having an actual content, corresponding to the target sulfur content or below it.

In one embodiment of the present invention, a petroleum feed consisting of light oil of low permeability reservoirs has an API density in the range of 45 to 55 degrees, and the aforementioned high sulfur fuel oil has an API density in the range of 14 to 21 degrees, the aforementioned liquids hydroconverted have an API density in the range of 26 to 30 degrees, and the above combined fuel product has an API density in the range of 37 to 43 degrees and a sulfur content of less than 0.5 mass. % sulfur. The actual sulfur content in the fuel of the present invention can be adjusted, as described herein, to meet the target sulfur content in accordance with the IMO (International Maritime Organization) technical specification for marine fuel, or in accordance with the technical specification of the turbine manufacturer designed for a turbine operating gas combustion products.

In another embodiment of the present invention, there is provided a method for processing crude oil together with light oil of low permeability reservoirs and high sulfur fuel oil. We define a “break point” for technical specifications and claims, with reference to the analysis of crude oil or another method of determination, designating the mass or volume of crude oil in% along the X axis, and the sulfur content along the Y axis, as the point at which the sulfur content begins to increase rapidly from the horizontal line or close to it, or increases exponentially, from the point of view of a high rate of change of excess per unit cycle, where the delta for the cycle is a change in unit volume fraction, and the delta for exceeding nent a change in the sulfur content of units, and the slope represents the excess over the cycle. The slope of this excess over the cycle starts from zero or horizontally, quickly moves to 0.2, quickly moves to 1, towards some exponential break in the increase in sulfur content, the break point will change depending on whether crude oil or other raw materials are supplied into the distillate column. The “shoulder strap” or “shoulder with sulfur content at the break point”, thus, serves to determine the separation of hydrocarbon-containing liquids that boil at a temperature above the end point of the range for naphtha, for example, above the end point of the range for unstabilized straight-run naphtha, but below or at the break point of what, as noted, is the point at which the sulfur content begins to increase rapidly or increase exponentially, in terms of a high rate of change of excess per unit cycle.

We define a basic “shoulder strap with precise break” or a basic “shoulder strap with sulfur content at the break point” for the purpose of technical specifications and claims for the designation, with reference to the sulfur content in the fraction, of hydrocarbon-containing liquids that boil at a temperature above the end point of the range for unstabilized straight-run naphtha, but below or at the break point, and when such a break point is chosen so that when the fuel product stream is formed from a combination of all the crude streams at or below the break point, and If all streams that are above the break point are selected for addition to such a combination, then the combined fuel would have an actual sulfur content that does not exceed the target sulfur content. In embodiments of the present invention, the fuel may be produced in accordance with the fact that the target sulfur content is a break point of the sulfur content or higher or lower than the break point of the sulfur content, and the combination of streams forming the fuel is carried out effectively with reference to the break point of such so that the actual sulfur content of the above fuel does not exceed the target sulfur content.

Hydrocarbon petroleum feedstocks, including crude oil and high sulfur content, which have a relatively high sulfur, nitrogen and metal content, are fed to atmospheric and vacuum distillation and separated into (1) light overhead refinery gases, (2) sulfur-containing liquid fractions at or below the break point, (3) fractions with a sulfur content above the break point, containing (A) distillate range fractions containing sulfur, (B) vacuum gas oil range fractions containing sulfur, and (C) sulfur-containing vacuum oil residue , and ( 4) purge gases containing sulfur, such as gases containing a small amount of sulfur, which are obtained from refinery gases of a distillation unit, stripping columns and as a result of technological operations of other units conducted from above. Liquid fractions with a sulfur content at or below the fracture point, being crude liquids, direct the pooling zone to form at least a portion of the fuel. Fractions of the distillate range and fractions of the vacuum gas oil range are sent to distillate and vacuum gas oil purifiers to be contacted with added hydrogen in the presence of a catalyst under hydrotreating conditions to form at least one hydrotreated liquid that is sent to the combining zone and purge gases, containing sulfur. The vacuum residue is sent to the hydroconversion zone of the oil residue in the fluidized bed to be brought into contact with the addition of hydrogen in the presence of a catalyst under hydroconversion conditions in the fluidized bed to form (1) another purified liquid, which is sent to the combining zone to form part of the fuel, (2) purge gases containing sulfur and (3) unconverted oil, which is sent to solvent separation to form (A) soluble deasphalted oil, which is sent to oil of the remainder, either separately or together with the vacuum residue, and (B) insoluble asphalt, which is sent to the asphalt. The crude liquids are combined with the aforementioned purified liquids to form a fuel having an actual sulfur content corresponding to or below the target sulfur content. In a preferred embodiment of the present invention, at least one of the aforementioned hydrotreated streams is an ultra low sulfur stream having 10 ppm by mass or less sulfur, which is used for adjustment by reducing or adding the amount of such stream to the combination, forming the aforementioned fuel in such a way that its actual sulfur content matches the target sulfur content or lower.

Variants of the methods of the present invention allow to obtain essentially all hydrocarbon compositions from the aforementioned refinery feedstock, which was separated into fractions for subsequent recombination to form the aforementioned fuel, which is a liquid fuel monoproduct, and not a large number of hydrocarbon products, with the exception of hydrocarbon compositions, containing hydrocarbons within (i) light overhead distillate gases obtained from distillation, (ii) asphalt; and (iii) streams used to recover sulfur or metals. Such fuels may contain a combination of hydrocarbons ranging from a portion of the aforementioned crude liquid fraction obtained from atmospheric distillation having the lowest boiling point, to a portion of a stream extracted from solvent separation having the highest boiling point and a stream subsequently purified either in a hydrotreating reactor or in a hydroconversion reactor, recovered and combined in the aforementioned fuel. In one embodiment of the present invention, at least one of the hydrotreated streams is an ultra low sulfur stream having less than 10 ppm by weight of sulfur, and the crude fraction has a sulfur content exceeding the target sulfur content, and the aforementioned untreated fraction is used as a balance control, by reducing or adding the amount of such a crude fraction to the above combination to form a fuel having an actual sulfur content, The appropriate target sulfur content or below. In one embodiment of the present invention, the first hydrotreated stream is a sulfur-reduced stream having a sulfur content of less than 10 ppm by weight of sulfur, and the second hydrotreated fuel fraction is a sulfur-reduced stream having a sulfur content in the range of 0 , 12 to 0.18 mass. % sulfur, and the crude fraction has a sulfur content exceeding the target sulfur content, and either the aforementioned first hydrotreated stream, or a second hydrotreated stream, or both of these streams are used as balance control, by reducing or adding a certain amount of such streams to the above combination for the formation of fuel having an actual sulfur content corresponding to or below the target sulfur content.

In one embodiment of the present invention, the oil residue and hydrotreatment hydroconversion zone comprises a separate distillate hydrotreatment reactor, a heavy fuel hydrotreatment reactor and an oil residue hydroconversion reactor, wherein each reactor forms a separate purified effluent, and each purified effluent is separately directed to a separator with a common a wall for the formation of a common top gas containing sulfur, and at least one separate liquid purified effluent with decreasing the total gas content associated with each effluent purified in the reactor, which is separately recovered from the aforementioned separator at a speed corresponding to its corresponding sulfur content, and is directed or (a) to the aforementioned combination with the aforementioned crude liquid stream to form a fuel having the actual sulfur content corresponding to or below the target sulfur content, or (b) to a back-up storage facility for subsequent adjustment of the balance of sulfur content in the fuel. In some embodiments of the methods of the present invention, the volume of fuel produced may exceed the total amount of incoming petroleum feed, the increase in volume being caused, at least in part, by the addition of hydrogen.

These new methods make it possible to adjust the sulfur content of the fuel combination of the fuel; it is necessary to adjust to meet the target sulfur content in accordance with the IMO technical specifications for marine fuel or in accordance with the technical specifications of the turbine manufacturer designed for turbines operating with gas combustion products. Thus, such fuels are particularly suitable for use in marine or land-based engines, in turbines operating on the products of gas combustion, or in fire furnaces. Certain fuel options obtained by combining light oil of low permeability reservoirs and refined high sulfur content fuels, while high sulfur fuels are processed by hydroconversion of the oil residue, produce fuel having an actual sulfur content of 0.5 mass. % or less, containing a range of hydrocarbons derived from crude oil from about C5 to about C20 or more, the aforementioned hydrocarbons having an initial boiling point that is the lowest boiling point of any fraction within the crude streams combined in the aforementioned fuel, and the highest boiling point is the highest boiling point of a portion of the stream leaving the solvent separation, which is subsequently purified either by hydrotreating or by hydroconversion, and combined to form a portion of the aforementioned fuel.

FIGURE 1 is a general overview of one embodiment of the present invention and shows, in a simplified form, the main components for a method for converting a hydrocarbon petroleum feed containing sulfur and metals to form fuel. Petroleum feedstocks consisting of light oil of low-permeability reservoirs 1, in a preferred embodiment of the present invention, were distilled during previous production, shipment or other processing in main gas-liquid separators to separate light trapped gases or subjected to stabilization, removal of water and sediments, or other minor conditioning . The crude oil, consisting of light oil of low permeability reservoirs 1, contains a substantially light and medium range of hydrocarbons having a relatively small amount of sulfur and metals and a relatively small amount of heavy fuel, and it is sent without further purification to the combining zone 600 in the form of a crude liquid stream.

A high sulfur fuel oil containing sulfur, nitrogen and metals is fed via line 41 to the hydroconversion zone of oil residue 401 to bring such oil 41 into contact with hydrogen in the presence of a catalyst under conditions of hydroconversion of the oil residue in an oil residue hydroconverter, such as a reactor fluidized bed or other suitable device for hydroconversion, selected in accordance with the composition of the crude oil, within zone 401 to form (1) a segment of the stream exiting the reactor, which is separated on the spot searched hydroconverted liquids 411 (the term “hydroconverted liquids” herein means a type of refined liquids containing a substantially complete range of hydrocarbons from about the boiling range of C5 to the minimum boiling point of unconverted oils 409, which are oil residues resulting from hydroconversion, purge gases 420 containing purged hydrogen and exhaust gases, components of liquid petroleum gas and acid gases containing sulfur, and (2) non ertirovannymi oils 409. Such separation, in a preferred embodiment of the present invention is carried out in a vacuum distillation, and in some cases for some types of petroleum feedstock - distillation, close to the atmospheric distillation may be effective for the separation of the unconverted oil. Unconverted oils 409 are sent for solvent deasphalting in zone 301. Solvent deasphalting separation 301 leads to the formation of (A) soluble deasphalted oil 311, which is recycled as a petroleum feed in the hydroconversion reactor in zone 401 or separately, or in a place with added high-content heating oil sulfur 41 in the aforementioned reactor. Solvent deasphalting separation 301 also leads to the formation of (B) insoluble asphalt 351, which is sent to clean the asphalt to the site where the utilities 501 are located. In one embodiment of the present invention shown in FIGURE 1, asphalt 351 is directed to the site on which are located Utilities 501, where asphalt is cleaned. In this example, asphalt can be burned in at least one gasifier (not shown) to generate electricity and at least a portion of hydrogen for the aforementioned hydroconversion and to capture at least a portion of the aforementioned metals in the gasifier solids that remove .

The crude liquids of line 1 are combined with the aforementioned purified liquids 411 to form fuel in the pool zone 600. Thus, fuel 600 combines the (i) lighter and medium hydrocarbons of a petroleum feed consisting of light petroleum low permeability reservoirs, condensate or other petroleum feed 1 many hydrocarbons from (ii) hydrocarbons of a heavier range of high sulfur fuel oil 41 contained in purified liquid streams 411 exiting the hydroconversion zone 401, while the fuel 600 has a wide range of hydrocarbons containing hydrocarbons from C5 to C20 or higher. The fuel thus formed has a wide range of hydrocarbons containing hydrocarbons, ranging from hydrocarbons with the lowest boiling point in the aforementioned light oil of low permeability reservoirs forming the aforementioned fuel to hydrocarbons with a maximum boiling point via line 311, which are dissolved in solvent separation 301 and subsequently purified by hydrogen in zone 401 and form part of the effluent 411 to form the aforementioned fuel. The amount and flow rate of components 1 and 411 can be adjusted based on the corresponding sulfur content, so that fuel 600 has an actual sulfur content corresponding to or below the target sulfur content. For purposes of example, and not limitation, if it is found that stream 1 has an elevated sulfur content at an unacceptable level, which makes it unsuitable for combining in zone 600, then crude stream 1 can be fractionated (distillation column not shown), and any portion of the heavy bottom fractions with a higher sulfur content can be sent to the complex hydrotreater in zone 401 for cleaning, and another portion of stream 1 can be left untreated and transferred to the pool zone 600. However, shoulder straps with a higher sulfur content formed resulting from the processing of the overhead stream in a hydroconverter, such as a stream of lower fractions resulting from atmospheric distillation, will not be directed to hydroconversion, as part of stream 41, since they will be hydrocracked under hydroconversion conditions, not necessarily with the consumption of hydrogen, and with obtaining lighter materials initially contained within petroleum feedstocks consisting of light oil of low permeability reservoirs. Such shoulder straps with a higher sulfur content will instead be directed to a separate hydrotreatment zone, as shown in the following embodiment of the present invention. In this embodiment of the present invention, the streams leaving the zone of purified products from at least one reactor within 401 can be separated by fractionation into a number of liquid fractions that have undergone hydroconversion, and if at least one of of such fractions has a sulfur content higher than the target level of sulfur content, then such a fraction or fractions can be sent either separately or together with other streams with the same sulfur content and boiling range, from the external zone 401 into at least one separate hydrotreating zone located within zone 401 for contacting with hydrogen in the presence of a catalyst under hydrotreating conditions to form a hydrotreated stream having a reduced sulfur content, in a preferred embodiment of the present invention is in the range 0.5 mass. % or less, or in a more preferred embodiment of the present invention, up to 0.2 mass. % or less, and the aforementioned sulfur-reduced hydrotreated stream is combined with the aforementioned crude stream obtained from light oil of low permeability reservoirs or with streams left from fractionation or resulting from other refining of light oil of low permeability reservoirs to form a fuel having an actual content sulfur, corresponding to the target sulfur content or below it. In one embodiment of the present invention, a series of hydrotreaters or complex hydrotreaters provide a sulfur content of 10 ppm by mass or less to 0.1 mass. %, depending on the amount of purified liquid with ultra-low or low sulfur content, which is necessary for the combined stream in order to obtain a sulfur content corresponding to the target sulfur content or below it.

In the system of hydroconversion of oil residues 401, shown in FIGURE 1, make-up hydrogen-containing gas 502 from the site on which the utilities 501, which is part of the gasification system, are located in quantities necessary for hydrotreating, together with the hydrogen produced during internal recirculation in the hydroconversion unit oil residues 401, compress and heat to effective operating temperatures, pressures, space velocities and pressures, which are adjusted taking into account the selected catalyst and other conditions known in this technical field to achieve the desired level of hydroconversion. The stream leaving the zone of the reactor 401, containing purified liquids and a hydrogen-containing gas, is separated in a high-pressure separator (not shown), and such liquids are collected in zone 401, and, if necessary, they can be sent for fractionation, and the hydrogen content is recovered. Purge gases containing acidic and acidic gases are sent via line 420 to the site where utilities 501 are located, which contains asphalt and sulfur removal systems. Asphalt cleaning may include incineration carried out either separately or with diluent in at least one boiler to generate electricity and steam, and, if necessary, may include auxiliary plants to reduce or remove sulfur and metals from flue gases and other process gases, and a hydrogen generation unit with a differential pressure absorption unit. In another embodiment of the present invention, asphalt cleaning is carried out by transferring to asphalt production or by using green coke as raw material for coke production. In yet another embodiment of the present invention, asphalt is burned in at least one gasifier to generate electricity and at least a portion of hydrogen for hydroconversion or hydrotreatment and to capture at least a portion of the above metals contained in the gasifier solids , to remove metals through such solids. The optimal choice of asphalt processing option will depend on the amount of asphalt produced, the availability of an inexpensive source of hydrogen and potential markets for asphalt.

FIGURE 1 is not shown, but there are various auxiliary gas-liquid separators of high, medium and low pressure known to specialists in the field of hydroconversion, in-line heaters, gas recirculation and purge lines, containers for irrigation of gases or lights and liquid separation, compressors, cooling systems and other auxiliary equipment. In addition, various amine or other absorbers of sulfur recovery agents and stripping systems used for cleaning with acid gas or acid gas could be included in the hydroconversion zone 401 if they are not located on a common area where the 501 utilities are located.

The parameters for choosing a catalyst for hydroconversion of oil residues and adjusting the processing conditions in the zone of hydroconversion of oil residues 401 are within the competence of a person employed in the oil refining industry and do not require additional explanation of the practical implementation of technological processes in the segments of hydroconversion of oil residues of the present invention. In the reaction zones, used catalysts for the hydroconversion of oil residues include any catalytic composition suitable for the catalytic hydroconversion of heavy hydrocarbon feedstocks to increase its hydrogen content and / or remove sulfur, nitrogen, oxygen, phosphorus, Conradson coke residue and heteroatomic metal impurities. The types of specific catalysts and various auxiliary devices, and particle size configurations used, and the selected conditions for the hydroconversion of oil residues will depend on the composition of the hydrocarbon feed, as well as on the sulfur and metal content and the heavy hydrocarbon oil residue of each portion of the other petroleum feed resulting from recirculation , or other streams and the required reduced content of sulfur and metals in the product stream obtained from each zone. Such a catalyst may be selected from any catalysts suitable for the hydroconversion of petroleum residues of hydrocarbon petrochemical feedstocks. In the publication number US 20140221713 A1 (US 13 / 758,429) 2014 Baldassari et al., Which is incorporated herein by reference, describes a wide variety of different catalysts suitable for the hydroconversion of oil residues, as well as suitable methods for the hydroconversion of oil residues, including options for integrated hydroconversion of oil residues. Baldassari et al. Further provides a summary of variations of the catalyst compositions and ranges of hydroconversion of distillates and heavy fuel residues, and various conditions for the hydroconversion of oil residues, all known to those skilled in the art of hydroconversion of oil residues. In one preferred embodiment of the present invention, fluidized bed hydroconversion is carried out in the range of reaction temperatures from 380 ° C to 450 ° C and at a reaction pressure in the range of 70 bar to 170 bar (partial pressure of hydrogen) with a preferred hourly space velocity of the liquid in the range of 0.2 to 2.0 hr-1, and conversion up to 550 ° C minus will be in the range from thirty percent (30%) to eighty percent (80%).

In another preferred embodiment of the present invention, asphalt 351 is fed into an integrated gasification combined cycle system 501 containing at least one gasifier to partially oxidize the above asphalt 351 in the presence of steam and oxygen and, if necessary, a carbon-containing suspension for cooling to form synthesis gas, at least one portion of which is converted into hydrogen, which is sent along line 502 for use in the hydroconversion system 401, and synthesis gas for combustion in a gas turbine of an energy unit with a combined cycle included in the system of sites where utilities 501 are located to generate electricity within 504 for use in the process and for other purposes, as well as the generated hot gases of the turbine, and also containing a heat recovery generator for recovering heat from such hot gases produced by a gas turbine to produce steam recovered via line 507, for use in an internal process, or for controlling steam a new turbine in order to additionally generate electricity sent in the form of energy of 504. Each gasifier also produces metal-rich soot, which can be in the form of solid particles that contain metal impurities obtained from high sulfur and / or heavy oil feed oils while solid particles are sent along line 506 from each gasifier to remove metals. The support systems comprise at least one gas purification unit to which all gas streams containing sulfur, whether sulfur-containing gas or acid gas, are supplied from all technological operations of the sulfur removal unit according to 508. In a preferred embodiment of the present invention, such Sulfur removal systems are part of the site where the utilities are located, which includes a gasification system. In a more preferred embodiment of the present invention, at least one sulfur-containing gas stream is directed to the industrial production of sulfuric acid as part of the total sulfur removal. The gasification system located within the utilities zone 501 typically includes an acid gas removal unit and an acid carbon monoxide replacement system that optimize in capacity and configuration to produce the desired hydrogen from at least a portion of the raw synthesis gas produced in gasification system.

In one embodiment of the method of the present invention shown in FIGURE 2, a fluid stream 411 obtained from petroleum feeds consisting of high sulfur fuel oils 41 is combined with a fluid flow 15 obtained from petroleum feeds consisting of light oil of low permeability reservoirs 3, in a pool zone 600 for producing a fuel having an actual sulfur content corresponding to or below a target sulfur content.

Light oil of low-permeability reservoirs enters the production process through line 3 and is sent to distillation column 101, where the oil feed 3 is separated into at least two fractions: (a) the overhead of zone 5, which contains at least a portion of the hydrocarbons in the range naphtha contained in petroleum feedstock consisting of light oil of low permeability reservoirs 3, and all hydrocarbons of a lighter range, and (b) a lower fraction containing essentially a fraction that is not within (a). The bottom fraction 11 of the distillation column 101 is sent along lines 11 and 15 to the combining zone 600 to form a portion of the fuel product. The naphtha of the upper zone and the lower overhead 5 contain (i) light refinery gases which are distilled in a separator (not shown) and carried through line 7 for internal use as process fuel or for capture for other purposes and (ii) stream 9, which contains hydrocarbons predominantly naphtha range. After the removal of light gases, all or part of stream 9 can either be sent (along lines 9 and 17, the connector is not shown) directly along line 15 for direct combining to form a portion of fuel in zone 600, or, taking into account the flash point of combination 600, at least a low flash point, a portion of stream 9 can be transferred to a processing unit 151, for example, to a complex of traditional aromatic substances, which has a catalytic reforming unit, well known in the field of oil refining, while 9 is contacted with the catalyst in the unit 151 for the production of hydrogen by-lung 505 and raffinate stream 155 recovered via line 159 for non-fuel products or for other use. Unit 151 may produce suitable by-products, such as liquefied petroleum gas 153, which may be used for internal fuel production processes or for capture for other uses.

In FIGURE 2, a high sulfur fuel oil, either alone or with another heavy oil residue or superheavy oil, enters the process through line 41 and is sent to a hydroconversion zone of oil residues 401 to produce a very low sulfur 41 liquid stream As was explained in FIGURE 1 above, the parameters for selecting a device for the hydroconversion of oil residues and catalyst, and adjusting various processing conditions in the complex zone of hydroconversion of oil residues 401 are within the competence July people working in the oil refining industry, and do not require additional explanation of the practical implementation of technological processes in the segments of the hydroconversion of oil residues of the present invention. In embodiments of the present invention, as shown, complex zone 401 comprises a hydroconversion reactor to which high sulfur fuel oil and other heavy oil feed contained in 41 are sent. Such heavy oil feed 41, in a preferred embodiment of the present invention, is purified in the zone of hydroconversion of oil residues 401, having a fluidized bed reactor in zone 401, to form (1) a segment of the stream exiting the reactor, which is separated into purified liquids 411, purge gases 420 containing hydrogen and sulfur, and (2) unconverted oils 409. Unconverted oils 409 are sent to solvent separation 301. Solvent separation 301 leads to the formation of (A) soluble deasphalted oil 31, which is recycled as a crude oil in the aforementioned reactor 401 or separately , or a site with added petroleum feed consisting of high sulfur fuel oil 51, in the aforementioned solvent separation zone 301. Solvent separation 301 also forms (B) a substantially insoluble enrichment of metals, asphalt 351, which in the embodiment shown in FIGURE 2, is directed at the purification of asphalt.

In one embodiment of the utilities shown in FIGURE 3, asphalt 351 is sent to a boiler, where the asphalt is burned to generate steam so that the steam turbine generates electricity 561, while at least a portion of the flue gases 429 of the boiler is cleaned in zone 701, either separately or through acid gases 420 of zone 401 contained in purge and other gas streams leaving the hydroconversion zone 401, for example, through various amine or other absorbers of sulfur recovery agents and stripping systems used for acid g for or acid gas for trapping and removing sulfur along line 565 and, in embodiments of the present invention, separate systems for trapping and removing metals along line 563. FIGURE 2 does not show, but there are various auxiliary gas-liquid separators known to those skilled in the art of hydroconversion and hydrotreatment high, medium and low pressure, in-line heaters, gas recirculation and purge lines, containers for irrigation of gases or lights and separation of liquids, compressors, cooling systems, and for other auxiliary flax use. In one shown embodiment of the present invention, in addition to the secondary hydrogen 505 obtained from the process unit 151, if necessary, another feed of hydrogen to the zone 401 is carried out via lines 503 and 509 from the hydrogen production unit 517 having a hydrogen source 519, for example, and not for limitation, natural gas is supplied to a steam cracking unit with an absorption unit with a differential pressure, while the cracking unit can use at least a portion of boiler steam from utilities zone 501, as udet described hereinafter.

The combined heavy crude oil feed to the zone of the hydroconversion reactor 401 is sent to be contacted with hydrogen in the presence of a catalyst under conditions of hydroconversion of oil residues in a fluidized bed reactor in zone 401 to form (1) a stream segment exiting the reactor, which is separated into refined liquids 411, a portion of purge gases 420 containing hydrogen and sulfur, and (2) unconverted oils 409. In addition, various amine or other absorbers of sulfur recovery agents and stripping systems used to clean stki acidic gas or an acid gas, could be included in or hydroconversion zone 401 or in a separate sulfur recovery zone 701, where the purge gases with a high sulfur content 428 could be directed. The cleaned steam 411 is sent to the combining zone 600 to combine with the crude stream 15 to form a fuel product so that the combination assumes that the actual sulfur content of the fuel product matches or below the target sulfur content.

In one embodiment of the method of the present invention shown in FIGURE 3, a stream of contaminated crude oil containing sulfur, hydrogen and metals enters a process carried out on line 2 after pretreatment, such as desalination, which is preferred for crude oil . In this example, the crude oil 2 may be a single crude oil or a mixture of at least one type of crude oil, or a mixture of crude oil, or a separate oil feed or light oil of low permeability reservoirs, or residual oil, for example, high-content heating oil sulfur. In one shown embodiment of the present invention, the crude oil 2 and the crude oil consisting of light oil of low permeability reservoirs 3 are separately sent to an atmospheric distillation column 100, in a preferred embodiment of the present invention, so that light oil of low permeability reservoir 3 is fed to the top a portion of crude oil 2 located in or near the evaporation zone of the column 100, where the crude oil is separated into light upper gases 4 and a large number of shoulder straps. Light overhead gases 4 include non-condensable refinery gases 6 suitable as process fuels, or they may be entrained for other purposes. In one preferred embodiment of the present invention, the capital costs associated with the stabilization system are excluded in relation to such overhead gases 4; however, depending on local needs, for example, on the technical characteristics of a special marine fuel with a maximum hydrogen sulfide content, a stabilization system can be included.

In one embodiment of the present invention shown in FIGURE 3, multiple shoulder straps will include at least one stream within these ranges: (1) unstabilized straight run naphtha on line 4 on line 16, (2) shoulder strap with sulfur content at fracture on line 18, (3) light distillate on line 24, (4) middle distillate on line 26, (5) first heavy distillate on line 28, (6) atmospheric oil residue on line 30. In a preferred embodiment of the present invention, combination of flows (1) unstabilized virgin naphtha via line 4 to line 16, and (2) distillate having a sulfur content at the point of inflection on the line 18 is expected to have a sulfur content in the range of less than 0.06 wt. % to 0.08 mass. % sulfur, if the target sulfur content of the fuel combination of 600 is 0.1 mass. % sulfur or less, and the sulfur content in the cleaned streams is less than 10 ppm by mass, where the flow rate of the crude streams 10 and the cleaned streams 65, 7 5 and 85 directed to the combination are adjusted so that in the fuel combination 600 is not there was an excess of the target sulfur content. In one embodiment of the present invention, the crude light oil stream of low permeability low sulfur and metal reservoirs is fed via line 53 directly to combination 600 in addition to the combination along lines 10, 65, 75 and 85 to adjust the final sulfur content and other parameters in the zone associations 600.

In FIGURE 3, atmospheric oil residue is sent via line 37, either separately or with the addition of residual oil 35, for example, high sulfur fuel oil, to a vacuum distillate column 200 to produce (1) a second heavy distillate on line 32, (2) light vacuum gas oil on line 36, (3) heavy vacuum gas oil on line 38 and (4) vacuum oil residue on line 50. Vacuum oil residue 50 is sent along lines 57 and 317, either separately or with the addition of residual oil 55, for example high fuel oil iem sulfur zone in the integrated hydroconversion and hydrotreatment of petroleum residue zone 401.

The parameters for choosing a device for complex hydroconversion and hydrotreating of oil residues and a catalyst, and adjusting various process conditions in the zone of complex hydroconversion and hydrotreating of oil residues 401 are within the competence of a person employed in the oil refining industry and do not require additional explanation of the practical implementation of the segments of hydroconversion and hydrotreating of oil residues of the present invention. In the shown embodiments of this embodiment of the present invention, the complex zone 401 comprises (A) a hydroconversion reactor zone 490, where the heaviest, most contaminated oil feed is supplied via lines 57 and 317, for example, vacuum oil residue 50, and added sulfur fuel oil and other heavy petroleum feeds are supplied via line 55, (B) the zone of the heavy oil hydrotreatment reactor 460, where the heaviest distillates and gas oils are fed via line 39, for example, as shown, containing (1) light vacuum gas oil per liter lines 36 and (2) a heavy vacuum gas oil on line 38, and vacuum oils separated in zone 410 from a stream leaving the hydroconversion reactor, for example, from a liquid product stream obtained by vacuum distillation leaving the reactor, can also be fed ( C) the area of the distillate hydrotreatment reactor 430, where lighter, less polluted oil feed is supplied via line 20, for example, through line 29, containing (1) light distillate on line 24, (2) the middle distillate on line 26, (3) the first heavy distillate on line 28 and line 32 containing (4) watts This is a heavy distillate, and distillate range materials separated in zone 401 from a stream leaving the hydroconversion reactor can also be fed. For example, the second heavy distillate on line 32, in an alternative embodiment of the present invention, can also be directed to a heavy oil hydrotreater 460, depending on the composition on line 32, and it is necessary to balance the load on the hydrotreating reactors within zones 430 and 460 and control the levels sulfur content. In such a complex hydroconversion and hydrotreatment zone of oil residues 401, recycle and make-up hydrogen streams 410 and 414 and purge gas streams 412 and 416 have complex recirculation, separation and removal systems known to those skilled in the art of refining. It is not shown in FIGURE 3, but there are various auxiliary gas-liquid separators of high, medium and low pressure known to specialists in the field of hydroconversion and hydrotreating, in-line heaters, gas recirculation and purge lines, containers for irrigation of gases or lights and separation of liquids, compressors, cooling systems, and for other auxiliary use. In one shown embodiment of the present invention, hydrogen 503 is supplied from a hydrogen production unit 517, which has a hydrogen source 519, for example, and not for limitation, natural gas is supplied to a steam cracking unit with a differential pressure absorption unit, wherein the cracking -installation can use at least a portion of boiler steam from utilities zone 501, as will be described later.

The combined heavy oil feed 317 fed to the zone of the hydroconversion reactor 490 is sent to be contacted with hydrogen in the presence of a catalyst under the conditions of hydroconversion of oil residues in the fluidized bed reactor in zone 401 to form (1) a stream segment exiting the reactor that is being separated, in a preferred embodiment of the present invention, by means of a second vacuum distillation unit (not shown) on (1) purified liquids 85 containing, (i) naphtha, (ii) middle distillates and (iii) vacuum gas oils, a portion of purge gases 416 and 428 containing hydrogen and sulfur, and (2) unconverted oils 409. In addition, various amine or other absorbers of sulfur recovery agents and stripping systems used for cleaning with acid gas or acid gas could be included in either a hydroconversion zone 401, or a separate sulfur recovery zone 701, where purge gases with a high sulfur content of 428 could be directed. At least a portion of the catalyst used for hydroconversion in the fluidized bed reactor 490, containing metals and / or other contaminants deposited thereon, or other substances accumulated by the catalyst during the processing in the fluidized bed reactor 490, is discharged via line 421 and is replaced by a make-up catalyst along line 423 known in the art. In one embodiment of the present invention, the purified liquids 85 containing (i) naphtha, (ii) the middle distillates and (iii) the vacuum gas oils are fractionated, and the middle distillates are sent to the distillate hydrotreater 430, and the vacuum gas oils are routed to the heavy oil hydrotreater 460.

Non-converted hydroconversion oils 409 are sent to solvent separation 301. Solvent separation 301 results in (A) soluble deasphalted oil 311 which is fed to the aforementioned hydroconversion reactor 490 or, in another embodiment of the present invention, to zone 460, either separately or together with vacuum oil residue 50, with added high sulfur fuel oil 55, if any, which is fed via lines 57 and 317 to the aforementioned hydroconversion reactor 490. Solvent deasphal Isolation separation 301 also leads to the formation of (B) insoluble metal-rich asphalt 351, which is sent to clean the asphalt to the site where the utilities 501 are located. In one embodiment of the utilities shown in FIGURE 3, asphalt 351 is sent to a boiler where the asphalt is burned to generate steam so that the steam turbine generates electricity 504, while at least a portion of the flue gases 429 of the boiler is cleaned in zone 701, either separately or by means of acid gases 428 of zone 401, for example by spilling GOVERNMENTAL amine absorbers or other sulfur recovery agents and stripping systems used for acid gas or the acid gas to sulfur capture and removal via line 561, and individual systems to capture and remove metal along line 563.

In one embodiment of the present invention, shown in FIGURE 3, the sulfur content of the fuel product 600 is controlled so that it matches or falls below the target limit sulfur level by: (a) feeding unstabilized straight run naphtha 16 to the combination 600 and a shoulder strap containing sulfur at break point 18, without additional purification of any such flow along line 10, then (b) adjusting the actual level of sulfur in product 600 by increasing or decreasing the amount sent to the plant at least one of any of the following: (1) streams of light distillate 24, middle distillate 26, first heavy distillate 28, and second heavy distillate 32, or by adding or decreasing the amount of middle distillates contained in the stream leaving the hydroconversion reactor formed in the complex zone 401, which is sent to the zone of the distillate hydrotreater 430, or (2) a stream 39 containing a light vacuum gas oil 36 and a heavy vacuum gas oil 38, or by adding or decreasing the amount of vacuum gas oil, retained in the stream leaving the hydroconverter (not shown) formed in the complex hydroconversion zone (401), which is fed to the heavy oil hydrotreater 460, and (c) a subsequent reduction in the amount fed to the combination 600 of at least one of any of the following : (1) streams obtained from the distillate hydrotreatment zone 430 via line 65, which are formed from a light distillate 24, a middle distillate 26, a first heavy distillate 28 and / or a second heavy distillate 32, and, if necessary, from a middle distillate, containing flowing from the converter, (2) streams obtained from the heavy oil hydrotreater zone 460 via line 75, which are formed from light vacuum gas oil 36, heavy vacuum gas oil 38 and, if necessary, from vacuum gas oil contained in the stream leaving from a converter, or (3) naphtha and other purified liquids of a stream 85 exiting the hydroconversion reaction zone 490, if any or all of them are needed, for any reason, to increase the actual level of sulfur in product 600 to the target sulfur level, or(d) increasing the amount sent to the combination of at least one of any of the following: (1) the above streams obtained from the distillate hydrotreater 430 through line 65, or (2) the streams obtained from the distillate hydrotreater 430 through line, or (3) the purified stream resulting from the hydroconversion reaction via line 85, if necessary, for any reason, to reduce the actual sulfur content of the product 600 so that it matches or falls below the target limit sulfur level. Due to this simplification, it is possible to efficiently produce a large number of sulfur grades, for example, sulfur grades used to produce fuels with a target sulfur content of 500 ppm by mass or less, which are used for offshore and onshore gas turbines, or different ranges for the same applications in various end-use locations where different levels of sulfur are required.

In embodiments using high sulfur fuel oil having a sulfur content exceeding the target limit sulfur content of the final fuel in a combination of 600, the high sulfur fuel oil is fed as part of at least one type of petroleum feed selected from various types of petroleum feedstock in at least one technological operation of each unit. Depending on the sulfur content, high sulfur fuel oil can be added to (a) feed line 2 for atmospheric distillation 100 or to line 30 along line 35 for vacuum distillation 200, or

(b) through lines 55, 57 and 317 to the hydroconversion reactor of oil residues 490, or (c) added to line 20 to a distillate hydrotreater 430, or separately, or together with at least one light distillate 24, a middle distillate 26, a first heavy distillate 26 or a second heavy distillate 32 fed to the aforementioned distillate hydrotreater 430, or (d) through line 39 to a hydrotreater of heavy oil 460, either separately or together with at least one light vacuum gas oil 36 or heavy vacuum gas oil 38, or (e) along line 59 to the solv zone a solid separation 301 to form a fuel combination 600 having an actual sulfur content corresponding to or below a target limit sulfur level.

In another embodiment of the present invention, clean fuel in the pool area 600 is formed by adding high sulfur fuel oil, which may have a sulfur content exceeding the target limit sulfur content, to at least one of the following: (a) a stream 10, formed from unstabilized straight-run naphtha 16 and shoulder straps with sulfur content at break point 18 without further purification, depending on the sulfur content in high sulfur fuel oil, or its up to flow to (b) stream 65 formed in a distillate hydrotreater 430 containing unstabilized naphtha and materials having a range of ultra low sulfur diesel fuel, or to (c) stream 75 formed in a heavy fuel hydrotreater 460 containing unstabilized naphtha, diesel fuel with an ultra low sulfur content and a second stream with a reduced sulfur content or (d) to the purified stream 85 leaving the hydroconversion reactor 85, and by adjusting the process conditions and the content of s each purified flow streams 65, 75 and 85 so that the fuel 600 had the actual content of sulfur corresponding to the target power limit sulfur or below, taking into account the content of sulfur, if any, flow of crude 10.

In one preferred embodiment of the present invention, where the use of high sulfur fuel oil in the manufacture of a fuel composition 600 is contemplated, a sulfur content is determined in such a high sulfur fuel oil, then a high sulfur fuel oil or is supplied as part of the crude oil 55 and 59 to at least one solvent separation unit 301, or to the reaction zone of hydrocarbon residues 490, depending on the specific sulfur content in the high oil fuels Erzhanov sulfur in order to optimize the adjustment of conditions in the hydroconversion zone 490 so that the sulfur content of the purified liquid effluent 85 allowed to form in the zone of 600 fuel having actual sulfur content corresponding to the target power limit sulfur or below.

The process diagrams depicted in FIGURE 1, FIGURE 2, and FIGURE 3, showing various intermediate individual products that serve for the purposes of example and understanding the main products and by-products in the effluents of each depicted process unit operation. The selected option of separation or purification by means of each technological operation of the unit depends on the selected crude oil and petroleum feedstocks, and on the optimization of the intermediate products produced to produce fuel corresponding to the target technical characteristic of sulfur content or lower. For example, the individual cleaned streams 65, 75 and 85 shown in FIGURE 3, leaving the hydrotreaters 430 and 460 and from the hydroconversion reactor 490, can be combined in complex zone 401 by using a common gas-liquid separator (not shown), for example, if diesel fuel ultra-low sulfur produced in hydrotreatment zone 430 is not separated from hydrotreated materials with higher sulfur produced in hydrotreater 460 or in a hydroconversion reactor 490, and all the purified materials 65, 75 and 85 are combined and fed as one stream into the combining area 600. As noted above, various parameters for adjusting the process conditions in an integrated hydroconversion zone and hydrotreating petroleum residues 401 are included in the competence of a person engaged in the petroleum industry; for example, hydroconversion and hydrotreating conditions will be adjusted to less stringent ones to avoid cracking when a small amount of light fractions are required in the mixture, and will be adjusted to more stringent ones if fewer heavy fractions are required.

FIGURES 4 and 5 show new fuels and recipes for combinations of at least one constituent element containing a range of light (L), medium (M) and / or heavy (H) materials to form such fuels.

FIGURE 4 graphically depicts both the temperature and density profiles in comparison with the volume fraction of the reference fuel produced in accordance with the method of the present invention, and shows its (L), (M) and (H) ranges set as described in this document.

FIGURE 5 shows the temperature and density profiles in comparison with the volume fraction of the reference light condensate, which can be used as the "upper part of the barrel" for combination. That is, such a condensate contains the natural majority (L) of the constituent elements with a small amount of natural (M) and a small amount of (H) 1. The selected condensate is combined with the added (H) 2 from another source, for example, from the "lower part of the barrel" (H) in order to form the fuel of the present invention.

FIGURE 5 demonstrates by example that, although the “stock” reserves of refining materials that can be selected for a potential combination are large enough, the recipe for selecting an assortment is not described in this document.

An important requirement is that when the fuel of the present invention, when it is formed by combining a number of hydrocarbon constituent elements (L) + (M) + (H), the resulting combination is determined based on 100 volume percent in total, as follows:

(a) (L)% + (M)% + (H)% = 100% and

(b) (L)% = (H)% = (100% - (M)%) / 2) and

(c) if (M)% is zero or otherwise less than 100%, then the remainder is (L)% / (H)% in a ratio of 0.4 / 1 to 0.6 / 1, and

such a combination has the following properties: (1) density - 820-880 kg / m3 at 15 ° C, (2) sulfur content - 0.25 mass. % or less; and (3) the metal content is 40 ppm by mass or less. A lower sulfur and metal content is preferred as set forth herein.

In order for a specialist in the field of oil refining to know first how to choose what needs to be combined in accordance with the recipe of the present invention, the potential components (L), (M) and (H) are first summed over the measurement points of the reference industrial composition, then narrowed subject to restrictions in accordance with the requirements set forth above and below.

For example, for components in the “(L)” or “Light Component” range, certain components may fall within the range of options found on “stock” refining materials available locally, while others may require processing if they are not available. locally. In accordance with the requirements set forth in this document, potential (L) may include components of materials of the naphtha and kerosene range, but not all, for example, taking into account the requirements for sulfur content and density for the fuel combination. (L) as used in the description and in the claims, means the entire range of naphthas having an initial boiling point of 38 ° C (100 ° F) or less, having ninety percent (90%) plus a final boiling point of 190 ° C (374 ° F) to about 205 ° C (401 ° F). (L) can be (a) purified or partially purified, (b) crude, or (c) they can be extracted and used without undergoing any fractionation, hydrotreating or other processing except for the separation, if necessary, of light gases or water . For example, certain components (L) or precursors (L) are published on Piatts lists in the industrial product offer system; however, the materials in the proposed range are not based on the sulfur content at the break point, since the break point is new and requires consideration of the cleaning of materials added to the combination or alternative materials with low sulfur content. Thus, the descriptions of the components below provide guidance on where to search.

Such potential components (L) also include, but are not limited to, components within the definitions assigned by the IEA (with conversion factors from degrees F to degrees C in brackets) (i) “Naphtha: A general term applied to refined or partially refined oil fraction with an approximate boiling range between [50 ° C to 204.5 ° C] (122 ° F and 401 ° F). ”and (ii)“ Naphtha: Purified or partially purified light distillates with an approximate range of boiling point [from 50 ° C to 204, 5 ° C] (122 ° F and 401 ° F). Subjected to further blending or blending with other materials, they produce high-quality automotive gasoline or jet fuel. They are also used as solvents, petrochemical raw materials or as raw materials for the production of domestic gas. Thus, in the practical implementation of the aspects of the present invention, refiners are aware, subject to the requirements set forth herein, manufacturing or developing at least one suitable (L) or Light component, or developing starting materials for making such constituent elements. For example, (L) The constituent element, in a preferred embodiment of the present invention, has a sulfur content at or below a break point; however, the sulfur content may be greater than the break point, where the sulfur content (M) and (H), when combined, ensures that the combination does not exceed the maximum level of sulfur content in the fuel. In a preferred embodiment of the present invention, the range of the heavier portion (L) ends at the break point of the sulfur content for the crude oil from which it was obtained.

Potential components of the range “(M)” or “Middle component”, as used herein, mean a refined or partially refined oil fraction with an approximate boiling range between an initial boiling point of about 190 ° C ( 374 ° F) to about 205 ° C (401 ° F) 90% plus final boiling point from about 385 ° C (725 ° F) to 410 ° C (770 ° F), all subject to compliance on this document; however, it is preferable that the lighter portion of the range (M) begin at the break point of the sulfur content for the crude oil from which it was obtained. Components (M) may include portions of lower light oil fractions of low permeability reservoirs that are heavier than the naphtha range. In preferred embodiments of the present invention, the starting components (M) comprise a combination of middle distillates, about one third of the kerosene hydrocarbons and about two thirds of the diesel hydrocarbons, subject to other limitations in this document, and have a density in the range of 820 to 880 kg / m3 at 15 ° C, in accordance with ASTM D4052.

In the practical implementation of the aspects of the present invention, those skilled in the art of refining are aware, subject to the requirements set forth herein, of manufacturing or developing at least one suitable (M) or Middle component. In many embodiments of the present invention, found in “stock” supplies available for refining materials (M) includes, but is not limited to, the definitions assigned by the IEA (with conversion factors from degrees F to degrees C in brackets): (i) “ Middle distillates: General classification of refined products containing distillate heating oil and kerosene "when used in this document this type of boiling at a temperature of 385 ° C (725 ° F) or lower, (ii)" Kerosene: A light oil distillate, which It is used in space heaters, stoves and water heaters, and it is suitable for use as a light source when burning in wick lamps. Kerosene has a maximum distillation temperature [204, 4 ° C] (401 ° F) at a 10 percent recovery point, a final boiling point [300 ° C] (572 ° F) and a minimum flash point [37.8 ° C] (100 ° F). The classification includes No. 1-K and No. 2-K, two grades recognized in accordance with the technical specifications of ASTM D 3699, as well as all other grades of kerosene, called kerosene for stoves or stove fuel, which have properties similar to those of heating oil No. 1. "(iii)" Light gas oils: Liquid petroleum distillates are heavier than naphtha, with an approximate boiling range of [205 ° C to 343.8 ° C] (401 ° F to 650 ° F) "and (iv) this portion boils at 385 ° C (725 ° F) or lower (iv) “Heavy gas oil: Oil distillates with an approximate boiling range of 343.8 ° C to 537.8 ° C (from 651 ° F to 1000 ° F) ”, while repeating the requirement that within the limits of (M) there was only such a portion that boils at a temperature of 385 ° C (725 ° F) or lower. (M) also contains materials included in the IEA definitions, (v) “Jet fuel like kerosene”, (vi) “Distillate No. 1” (vii) “Diesel fuel No. 1” (viii) “Distillate No. 2”, (ix ) “Diesel fuel No. 2” (x) “Fuel oil No. 2” (xi) “Distillate fuel oil” and (xii), possibly a portion of Fuel No. 4 or Diesel fuel No. 4, provided that all of the above materials comply with the minimum boiling point at a temperature of approximately 385 ° C (725 ° F) or lower. The IEA defines diesel fuel in the broad sense as including mixtures containing residual oils, such as “Diesel: Fuel consisting of distillates obtained from oil refining, or mixtures of such distillates with residual oil used in motor vehicles. The boiling point and specific gravity of diesel fuel is higher than that of gasoline. ” Thus, since the residual oil may be present in the material identified as diesel, refiners will evaluate whether the tender diesel fuel is (M) or (H) based on factors due to the present invention. There are many types of diesel fuel that the IEA defines as “High sulfur diesel fuel (HSD): Diesel fuel containing more than 500 parts per million (ppm) sulfur” is likely to be within (M) or (N), taking into account other requirements of the present invention, as further explained herein. However, the IEA defines “Low Sulfur Diesel (LSD): Diesel containing more than 15 but less than 500 parts per million (ppm) sulfur” and “Ultra Low Sulfur Diesel (ULSD): Maximum Diesel 15 ppm sulfur ”is likely to be within (M), but may be within (H), subject to other requirements of the present invention, as explained later in this document.

A necessary attribute of the range (M) of the constituent element is that the average density (M) (often called bulk) for this range should be from 820 kg / m3 at 15 ° C to 880 kg / m3 at 15 ° C so that in this range, a portion of the combination of the present invention could be formed having a combination density of 820 to 880 kg / m3 at 15 ° C., subject to other limitations described herein. That is, the individual constituent elements (M) may fall outside the range, but together (M) is in the range from 820 to 880 kg / m3 at 15 ° C.

In embodiments of the present invention, the constituent element of the range (M) will have a sulfur content above the fracture point prior to purification carried out to remove sulfur, for example, by hydrotreating described herein; however, after purification, the sulfur content in (M) should be lower than the break point, except in rare cases when (M) The constituent element may be higher than the break point if the sulfur content in the cleaned (M) is, for example, as a stream leaving of a hydrotreater is combined with purified (H), for example, as a stream leaving the converter, and when both of them are combined with (L), then in such a combination of (L), (M) and (H) the limit level must not be exceeded sulfur content in the fuel. A higher level of the selected break point allows the maximum amount of material within (L) to avoid further processing, such as hydrotreating, if it is used to remove sulfur, and thereby reduce the cost of hydrogen production and other operating costs. In one embodiment of the present invention, (M) is hydrotreated to produce a very low sulfur effluent in the range of about 10 ppm by mass and with a very low metal content or substantially no metal content. The various grades of certain hydrotreated materials that can be selected for use are used as components (M) or precursors that are published on the Platte lists in the well-known industrial product offer system. If (M) is absent or not added, then the boundary between (L) and (H) must satisfy the requirements of (M).

The “(H)” or “Heavy constituent” components used herein mean refined or partially refined oil fractions having an initial boiling point of from about 385 ° C (725 ° F) to about 410 ° C ( 770 ° F) and a final boiling point of approximately 815 ° C (1499 ° F) or less, subject to the requirements set forth herein. This final boiling point (N) is an attribute (H) of the constituent element, which may be known after a purchase request or during production tests. In one embodiment of the present invention, the final boiling point (H) is determined by the petrochemical feedstock and / or process condition, such as the highest boiling point of a stream component recovered from solvent separation and then purified in a hydrotreating or hydroconversion reactor, recovered and combined in the above fuel.

One essential attribute of a constituent of the range (H) is that, during manufacture, a suitable amount of its components has been cleaned to reduce the presence of sulfur and some heavy asphaltenes and metals, for example, by solvent separation, as discussed hereinabove, and / or by hydroconversion and / or hydrotreating, as discussed herein, or by another purification method to reduce the sulfur and metal content to a level that allows it to be added to a combination of (L), (M) and (H) to suitably The fuel of the present invention contains sulfur and metal specifications. Another significant attribute of the range component (H) is that its contribution to the range density (H) and to the final fuel combination should provide the formation of a portion of the combination (L), (M) and (H) of the present invention, where the density of the fuel combination is 820 kg / m3 at 15 ° C and less than 880 kg / m3 at 15 ° C, subject to other restrictions described herein.

Thus, in the practical implementation of the aspects of the present invention, refiners are aware, subject to the requirements set forth herein, manufacturing or developing at least one suitable (H) or Heavy constituent element, or petrochemical feedstock, and methods thereof production. In many embodiments of the present invention, petroleum refining materials found in “stock” inventories, source materials for components (H) include, but are not limited to, the definitions assigned by the MEA to (i) a portion that boils at a temperature above about , 385 ° C (725 ° F) (iii) “Heavy gas oil: Petroleum distillates with an approximate boiling range of 343, 8 ° C to 537, 8 ° C (651 ° F to 1000 ° F)”, repeating the requirement so that within (H) there is only such a portion that boils at a temperature D above 385 ° C (725 ° F).

(H) also contains “Heavy gas oil: Petroleum distillates with an approximate boiling range of 651 ° F to 1000 ° F” with an initial boiling point of approximately 385 ° C (725 ° F), (ii) Residual heating oil: General classification for heavier oils, known as heating oils No. 5 and No. 6, which remain after the distillate heating oils and lighter hydrocarbons are distilled as a result of oil refining operations. This complies with ASTM D 396 and D 97 5 technical specifications and VV-F-815C Federal Technical Specifications. No. 5, a medium viscosity residual heating oil, also known as Navy Special, and is defined in the MIL-F-859E Military Specification, including Amendment 2 (NATO Symbol F-770). It is used by steam-powered vessels in the public service and onshore power plants. No. 6, the heating oil includes bunker C, the heating oil, and it is used for electricity generation, space heating, bunkering of ships and for various industrial purposes and (ii) is defined by the IEA “No. 6 Residual heating oil. "

FIGURE 4 shows one embodiment of a fuel composition of the present invention produced in accordance with the method of the present invention.

FIGURE 4 shows, for a reference crude oil refined according to the present invention, two profiles versus volume fraction: temperature profile 602 and specific gravity profile 604. That is, FIGURE 4, both for the upper block diagram and for the lower block diagrams, X-axis 610 represents the volume fraction of crude oil. In the upper block diagram, the Y-axis 612 shows the measuring points of boiling points in degrees Celsius for the various runs through which the temperature profile curve 602. In FIGURE 4, in the lower block diagram, the Y-axis 614 shows the specific gravity data for the reference crude oil through which the density profile curve 604 passes.

The upper and lower block diagrams of FIGURE 4 show two (2) vertical dashed lines LM 606 and MH 608 intersecting the temperature profile 602 and curves of the density profile 604. Vertical lines LM 602 and MH 604 run in selected sections of the distribution of the outputs of the volume fractions of the reference raw oil range (L) 622 and range (M) 624. In FIGURE 4, the intersection LM 606 is selected at a temperature of 205 ° C, and the intersection MH 608 is selected at a temperature of 385 ° C to determine the corresponding ranges for (L) 622 and (M) 624 For crude oil that is lighter or heavier than the reference crude th oil, the lines are shifted to the right or left.

Point 609 represents the end of the range (H), including vacuum gas oil overhead with temperatures up to 565 ° C and deasphalted oil raised from the remaining vacuum oil residue with temperatures above 565 ° C. The temperature at point 609 will depend on the raised deasphalted oil, having in this case, asphalt is not represented from point 609 to one hundred (100) volume percent. The temperature point 611 is part of the overhead point of the heavy vacuum gas oil purified (H) used for the combination, while the portion (H) 626 from point 611 to 609 is a deasphalted oil. The corresponding density points are shown in FIGURE 4 as 615 for the full range of untreated crude oil, and 613 is a straight line through the bulk densities (L), (M) and (H) for the processed crude oil.

Thus, the end point of the highest boiling point of range (L) 622 and the starting point of boiling point (M) 624 have a common vertical line LM 606. The end point of the highest boiling point of range (M) 624 and the starting point of boiling point (H) 626 have a common vertical line MH 608. The actual endpoint 609 of the range (H) 626 precursor is interrupted as described in other embodiments of the present invention and is discussed in definition (H) to remove certain heavier asphaltenes and other complex carbohydrates portly and essentially to remove metals and preservation of adding (H) with a very low sulfur content (H) in the final fuel.

FIGURE 4 further shows how the invention disclosed herein regarding fuel obtained in accordance with the method of the present invention proposes to combine constituent elements within (L), (M) and (H) to form a fuel composition that mimics fuel of the present invention produced in accordance with the method of the present invention. In the review, as one of the embodiments of the present invention, the constituent element is examined and the density is plotted against the volume fraction to find the center point of its range (M) within the required parameters: from 820 kg / m3 at a minimum temperature of 15 ° C on a line from 640 to 880 kg / m3 at a maximum temperature of 15 ° C on line 642, that is, point 630 (the angle of rotation of the density will be determined later), in which the density, compared with the volume, intersects the middle of the range (M), plus or minus ten percent by volume (+/- 10%), or if there are very few or no constituent elements of the range (M), then at a conditional point, such as the point located at the place where it ends (L), and (H ) begins, or between. The central dark square 630 represents the midpoint of the bulk density of the range (M), while the dark squares 631 and 633 represent the midpoints of the bulk density for the ranges (L) and (H), respectively.

If crude oil, which is lighter than the reference crude oil, is processed in accordance with the method of the present invention to obtain fuel, then the vertical lines LM 606 and MH 608 are shifted to the right, as are the ranges (L) 622, (M) 624 and (H) 626, that is, there is a larger volume of the lighter constituent element of the range (L) 622 and less lighter constituent element of the range (H) 626. The angle of rotation of density 630, moving slightly, remains within the center of rotation of density 632 (will be defined further), even though n otnostitsja fuel decreases. If a crude oil heavier than a reference crude oil is processed in accordance with the method of the present invention to produce fuel, the opposite situation arises. That is, the vertical lines LM 626 and MH 628 are shifted to the left, which means a larger volume of the constituent element (H) and a smaller volume of the constituent element (L). The angle of rotation point 630 of the fuel combination should remain in the density zone from 820 to 880 kg / m3 between lines 640 and 642, although the fuel density is increasing. In cases with such a lighter and heavier oil feed, for combined fuel there should be enough constituent elements (L) and (H) (as well as constituent elements (M), if present) with the total necessary densities in order to balance each the range (L) and (H) for the delivery of fuel having a bulk density in the range of 820 to 880 kg / m3 of the density zone of the fuel combination between lines 640 and 642.

Thus, very light petroleum feedstocks, such as light oil of low permeability reservoirs or condensates, which are the primary materials of the range (L), do not have sufficiently heavy materials (M) or (H) to serve as the only materials that allow volumetric the density of the final product, located within the center of rotation of the density, to such values that it was possible to obtain fuel in the range from 820 to 880 kg / m3 of the density zone of the fuel combination.

Used in the description and in the claims, the terms (a) "the center of rotation of the density" means the bulk density in the range between 820 and 880 kg / m3 at a temperature of 15 ° C, located in the center or at the corner of the rotation of the density, or nearby (as defined below ), within about 10 ten volume percent (+/- 10 vol.%) of the volume fraction range in the place of the density rotation angle. By way of example, and not limitation, a volume percent measured in the range of 43 to 53 volume percent for a nominal 48 volume percent, or from 80 to 90 volume percent for a nominal 85 volume percent and (b) "Density rotation angle" means the center point The center of rotation of the density, so that when equal volumes of the constituent elements (L) and (H) are combined with or without the constituent component (M), a balanced density can be achieved. All of the above-mentioned lines pass through the required volumetric Density Rotation Center, which plays an essential leading role in fuel preparation, in order to either raise one end of the density range of curve 604 or lower the end of curve 604, as a result of which both ends fall within the range of 820 up to 880 kg / m3, located between lines 640 and 642 so that the bulk density for the combination is at point 630.

Analyzing the density profile 604, as shown in FIGURE 4, it can be seen that the densities (volumetric) extend almost in a linear profile, undergoing slight changes, but have slopes outside the range of the parallel zone of the Rotation Center of density 632, and they are rotated in the center 630 The center of rotation of the density or near it. As shown, when the density range is from 882 to 880 kg / m3 at a temperature of 15 ° C, substantially equal volumes (L) and (H) will lift and rotate line 604 so that the entire mixture is in the range of bulk density between 640 and 642 of the clean fuel of the present invention.

If the density of the final combined fuel product is lower than the density of the center of rotation of density 632 (for example, lower, approximately, 820 - the requirement for lower density), then the heat of combustion decreases, which requires an increase in fuel consumption to achieve the same energy efficiency. If the density of the final product is higher than the highest density of the Center of rotation of density 632 (for example, higher, approximately, 880 is the requirement for the upper highest density boundary), then there are problems associated with the supply of fuel to the engine and with the feed systems, and with other end applications .

It is surprising that it is possible to significantly reduce or remove (M) without disturbing the balance at the Center of rotation of density, and at the same time form an acceptable fuel from (L) and (H), if all other conditions are met. This makes it possible to use certain upper and lower fractions of barrel combinations to derive the diesel fuel range from (M), but at the same time to form an acceptable fuel from the remaining (L) and (H).

FIGURE 5 shows, for example, how to use light oil of low permeability reservoirs, for example, a constituent element of the "upper barrel" range (L), together with another constituent element, such as a constituent element of the "lower barrel" range (H) (H) , to form a fuel composition that mimics the fuel produced in accordance with the method of the present invention.

In FIGURE 5, condensate is used as the type of reference light oil of low permeability reservoirs, shown at the top of the flow chart of FIGURE 5. This is an example of a light “top barrel” material having a temperature of 53 ° API, having approximately 69% vol. Range (L) 722, which ends on line 706, and it has only 28 vol.% Of the range (M) 724, which ends on line 708, and has about three percent (3 vol.%) Of atmospheric residue in the lower fractions (H) 1, shown as 726, which is added to the final combination. The yield curve of the reference condensate material 702 at various temperatures 712, graphically depicted in comparison with the volume fraction 710, is shown in the table of the block diagram of FIGURE 5. As already noted, the analysis of this reference material is interpreted as a general approximation to approximately 69% volume% of the range ( L) 722 and 28 volume% of the range (M) 724 and to a small extent to about 3 volume% of the range (H) 1,726. The endpoint 711 is shown as one hundred (100 volume%), since the lower fractions are materials of the relatively light range gas oil a small amount of heavy oil residue. If the center of rotation of the density were shown for reference only (without the addition of (H) 2, shown only in the lower block diagram of FIGURE 5), it would be far right around about 85% of the volume fraction of the original reference material without addition (H ) 2. Thus, to achieve balance of the combined curve within the target density range of 820-880 kg / m3 located between lines 740 and 742, at least additional constituent elements of the range (M) or, in a preferred embodiment of the present invention, will be required for the combination - constituent elements (M) + (H), or in a more preferred embodiment of the present invention, mainly material of the range (H) with components (M).

In this example, shown in the lower block diagram of FIGURE 5, for each barrel of this reference condensate naturally occurring in a volume of about 69 vol% (L) 722 and 28 vol% (M) 724 and 3 vol% of the H1 726 range , from another source add 0.69 barrels of non-condensate (H) 2 727, for example, produced in the form of a stream with a full range coming out of hydroconversion. The central dark square 730 represents the midpoint of the bulk density of the range (M), while the dark squares 731 and 733 represent the midpoints of bulk density for the ranges (L) and (H), respectively. This combination with added (H) 2 forms 1.69 barrels (100 volume percent shown in FIGURE 5 at the bottom of the flowchart), as (L) plus (M) plus (H) 1 plus (H) 2 designed pure the fuel of the present invention as a simulated fuel, has a density within the required range from 820 to 880 kg / m3 for the fuel product API from about 25 to 28, and this example is shown in Table 1:

where the developed fuel from Table 1 corresponds to the technical specification for low sulfur and metal content.

In yet another embodiment of the present invention, the amount of M added to the combination is reduced to substantially zero. This is due to a shortage of supplies of diesel fuel and other materials within the range (M), which are in high demand due to the requirements of low sulfur content in road fuel, and which are very in demand for the production of marine fuel with low sulfur content and fuel used in gas turbines. In this embodiment of the present

inventions, combinations of substantially equal parts (L) and (H) are made to form a developed fuel with or without a small amount (M). The choice of “heavier condensate” or light oil of low permeability reservoirs will provide a greater amount of atmospheric residue, and in some cases, a certain amount of gas oil range materials, and if you move the vertical lines (LM) to the left, then the Center of rotation of density will move upward as the density increases from - by adding heavier light oil to low permeability reservoirs.

In one embodiment of the present invention described above, we have a newly developed fuel containing a combination of at least one component from (L), (M) and (H), where, based on 100 volume percent in total, the combined appropriate amount is determined as follows: (a) (L)% + (M)% + (H)% = 100% and (b) (L)% = (H)% = (100% - (M)%) / 2), and (c) if (M)% is zero or otherwise less than 100%, then the remainder is (L)% / (H)% in a ratio of 0.4 / 1 to 0.6 / 1, however, such a combination has a fuel with (1) density - 820-880 kg / m3 at 15 ° С, (2) sulfur content - 0.25 mass. % or less and (3) a total metal content of 40 ppm by mass or less. In one embodiment of the present invention, the sulfur content is reduced to 0.1 mass. % or less, and the metal content is reduced to 25 parts per million by mass or less. In one embodiment of the present invention, (M) is present in a volume of 10 to 90%, and the remainder is (L) / (H) in a ratio of 0.4 / 1 to 0.6 / 1. In another embodiment of the present invention, the volume of presence (M) varies from 20 to 80%, and the remainder is (L) / (H) in a ratio of 0.4 / 1 to 0.6 / 1, and in yet another embodiment of the present invention, (M) is present in a volume of 30 to 70%, and the remainder is (L) / (H) in a ratio of 0.4 / 1 to 0.6 / 1. In a simplified embodiment of the present invention, ranges (M) are from 30% to 70% by volume, and the remainder is essentially equal parts (L) and (H) in (L) / (H) in a ratio of from 0.9 / 1 to 1 / 0.9, and in another embodiment of the present invention, the ranges (M) are from 40% to 60% by total volume, the density is in the range from 820 to 880 kg / m3 at 15 ° C, the sulfur content is 0.25 mass. % or less, and the metal content is 40 ppm by mass or less.

Thus, we found that the fuel with a very low sulfur content of 0.1 mass. % can be developed or obtained by targeting densities ranging from 820 to 880 kg / m3 at 15 ° C or less using manufactured precursors or constituent elements containing hydrocarbons obtained from a combination of light oil, low-permeability reservoirs and high sulfur, hydroconverted heating oil moreover, the aforementioned fuel has an initial boiling point, which is the lowest boiling point of any fraction of any of the aforementioned oils under atmospheric distillation conditions, the highest boiling point is the highest boiling portion of petroleum residue of the aforementioned fuel oils with high sulfur content, which is soluble in solvents suitable for solvent separation. For example, in the practice of the present invention, if heptane is chosen as the solvent for purchasing indicators for the acquisition of constituent elements of the combination or for production by using a portion of the solvent separation in accordance with the manufacturing method of the present invention, then the end point of the highest boiling point, regardless of purification or cleaning, within the combination will be higher than when choosing pentane as a solvent for the indicator or for manufacture.

We have found that we can use the above disclosed methods for selecting or purifying (L) + (M) + {H) precursors to simulate a developed fuel combination with a wide range of hydrocarbons suitable as pure turbine fuel having the following properties: (a) sulfur - from 0.05 mass. % (500 parts per million by weight) to 0.1 mass. % (1000 ppm by mass) in accordance with ISO 8754, (b) density - from 820 to 880 kg / m3 at 15 ° C in accordance with ASTM D4052, (c) total metal content - 25 ppm by mass or less, in a preferred embodiment of the present invention, less than 10 ppm by weight, and in an even more preferred embodiment of the present invention, less than 1 ppm by weight in accordance with ISO 14597, (d) HHV (High calorific value) - from 43.81 to 45.15 MJ / kg and (f) LHV (Low calorific value) - from 41.06 to 42.33 MJ / kg. The flash point will vary depending on the lowest flash point making up the elements of the combination. We have found that in the embodiments of the present invention, the following additional simulated properties are present: (a) kinematic viscosity at 50 ° C - less than 10 mm ² / s, where 1 mm ² / s = 1 cSt in accordance with ISO 3104, (b) the carbon residue is in the range of 0.32 to 1.5 in accordance with ISO 10370, (c) the actual dissolved resins are less than 5 in accordance with ISO 624-6, (d) the oxidative stability is approximately 0.5 in accordance with ASTM D2272 and (e) the acid number is less than 0.05 mg KOH / g in accordance with ASTM D664. For use as marine fuel, reference is made to the testing or calculation methods specified in ISO 2817-10.

Thus, the present invention is widely used for the production of fuels having a reduced sulfur content, low levels of sulfur and other pollutants, and the use of such fuels. Some features may be changed without departing from the principle or scope of the present invention. Accordingly, the present invention should not be construed as limited to the specific embodiments discussed or examples, but only as defined in the appended claims or in substantial equivalents of the claims.

Claims (38)

1. Fuel for engines of marine or land-based applications, in turbines operating on the products of gas combustion, or in fire furnaces, containing 100 parts per billion or less metals, containing 0.5 wt. % sulfur or less, wherein said fuel contains a hydrocarbon range from about C5 to about C20 or higher, said hydrocarbons having an initial boiling point that is the lowest boiling point of the light oil component of low permeability reservoirs or lighter materials resulting from the aforementioned hydroconversion combined in this way and the highest boiling point is the highest boiling point of a component of the above purified soluble deas altizirovannogo oil obtained from the combustion of oil with high sulfur content or other petroleum residues, thus united. 2. Fuel for engines of marine or land-based applications, in turbines operating on the products of gas combustion, or in fire furnaces, characterized in that the fuel is formed by combining a number of constituent elements of hydrocarbons (L) + (M) + (H) and is determined based on 100 volume percent in total, as follows: (a) (L)% + (M)% + (H)% = 100%, and (b) (L)% = (H)% = (100% - (M)%) / 2), and (c) if (M)% is zero or otherwise less than 100%, then the remainder is (L)% / (H)% in a ratio of 0.4 / 1 to 0.6 / 1, (d) wherein such a combination has a density of the final combination of 820-880 kg / m ³ at 15 ° C, (2) the sulfur content is 0.5 wt. % or less and (3) the total metal content is 40 ppm by mass or less, unless (M) is zero or otherwise less than 100% and the remainder is (L)% / (H)% in a ratio of 0.4 / 1 to 0.6 / 1, the sulfur content is 0.25 wt. % or less (e) wherein (L) contains components of materials of the naphtha and kerosene range that are processed or partially processed, not processed or recovered and used without subjecting them to any fractionation, hydrotreating or other technological process, except for separation, if necessary, light gas or water, has an initial boiling point of 38 ° C (100 ° F) or less, has ninety percent (90%) plus a final boiling point of 190 ° C (374 ° F) to about 205 ° C (401 ° F), where the components of the range (L) contribute to Removable density range (L) and the density of the final combinations, even though some constituent elements <L) may extend beyond the density range of the above combination, (f) wherein (M) contains refined or partially refined petroleum fractions having an initial boiling point of from about 190 ° C (374 ° F) to about 205 ° C (401 ° F) and 90% plus the final temperature boiling point from about 385 ° C (725 ° F) to 410 ° C (110 ° F), where the components of the range (M) contribute to the bulk density of the range (M) and to the density of the final combination, even though the individual constituent elements (M) may fall outside the density range of the above combination, and (g) wherein (H) contains refined or partially refined petroleum fractions having an initial boiling point of from about 385 ° C (725 ° F) to about 410 ° C (110 ° F) and a final boiling point of, approximately 815 ° C (1499 ° F) or less, where the final boiling point (N) is the highest boiling point of a component of the stream purified by solvent separation to reduce the presence of asphaltenes and metals, then recovered and subsequently purified by hydroconversion or hydrotreating to level allowing add l such a flow to the combination of (L), (M) and (H) to match the final sulfur content of the fuel combination, and where the components of the range (H) contribute to the bulk density of the range (H) and to the density of the final combination, even though individual constituent elements (H) may fall outside the density range of the above combination. 3. Fuel under item 2, characterized in that (M) is present in a volume of from 10 to 90%, and the remainder is (L) / (H) in a ratio of from 0.4 / 1 to 0.6 / 1. 4. Fuel under item 2, characterized in that (M) is present in a volume of from 20 to 80%, and the remainder is (L) / (H) in a ratio of from 0.4 / 1 to 0.6 / 1. 5. Fuel according to claim 2, characterized in that (M) is present in a volume of from 30 to 70%, and the remainder is (L) / (H) in a ratio of 0.4 / 1 to 0.6 / 1. 6. Fuel under item 2, characterized in that the sulfur content is 0.1 wt. % or less, the metal content is 25 ppm by mass or less. 7. Fuel for engines of marine or land applications, in turbines operating on the products of gas combustion, or in fire furnaces, characterized in that it is formed by combining a number of hydrocarbons (L) + (M) + (H) and is present in a volume of 30 to 70% by volume of the constituent elements (M) of the range, and the remainder are equal parts (L) and (H) in (L) / (H) in a ratio of 0.9 / 1 to 1 / 0.9, for 100 volume percent in total, and the density of the final combination is in the range from 820 to 880 kg / m ³ at 15 ° C, the total sulfur content is 0.25 wt. % or less, and metals - 40 parts per million by weight or less. (a) wherein (L) contains components of materials of the naphtha and kerosene range that are processed or partially processed, not processed or recovered and used without subjecting them to any fractionation, hydrotreating or other technological process, except for separation, if necessary, light gas or water, has an initial boiling point of 38 ° C (100 ° F) or less, has ninety percent (90%) plus a final boiling point of 190 ° C (374 ° F) to about 205 ° C (401 ° F), where the components of the range (L) contribute to the bulk density of the range (L) and the density of the final combination, even though the individual constituent elements (L) may go beyond the density range of the above combination, (b) wherein (M) contains refined or partially refined petroleum fractions having an initial boiling point of from about 190 ° C (374 ° F) to about 205 ° C (401 ° F) and 90% plus the final temperature boiling point from about 385 ° C (725 ° F) to 410 ° C (770 ° F), where the components of the range (M) contribute to the bulk density of the range (M) and to the density of the final combination, even though the individual constituent elements (M) may fall outside the density range of the above combination, and (c) wherein (H) contains refined or partially refined petroleum fractions having an initial boiling point of from about 385 ° C (725 ° F) to about 410 ° C (110 ° F) and a final boiling point of, approximately 815 ° C (1499 ° F) or less, where the final boiling point (N) is the highest boiling point of a component of the stream purified by solvent separation to reduce the presence of asphaltenes and metals, then recovered and subsequently purified by hydroconversion or hydrotreating to level allowing add l such a flow to the combination of (L), (M) and (H) to match the final sulfur content of the fuel combination, and where the components of the range (H) contribute to the bulk density of the range (H) and to the density of the final combination, even though individual constituent elements (H) may fall outside the density range of the above combination. 8. The fuel under item 7, characterized in that (M) ranges from 40 to 60% by volume, and the remainder is essentially equal parts (L) and (H). 9. Fuel under item 7, characterized in that the total sulfur content is 0.1 wt. % or less, metals — 25 ppm by mass or less, wherein the aforementioned fuel contains hydrocarbons obtained from a combination of light oil of low permeability reservoirs and high sulfur, hydroconverted firing oil, wherein the aforementioned fuel has an initial boiling point that is the lowest boiling point of any fraction of any of the above oils under atmospheric distillation conditions, and the highest boiling point is the highest boiling point of a portion of oil Nogo residue aforementioned fuel oils with high sulfur content, which is soluble in solvents suitable for solvent separation. 10. Fuel for engines of marine or land-based applications, in turbines operating on the products of gas combustion, or in fire furnaces, characterized in that it contains less than 100 parts per billion by mass of metals and is formed by combining a number of hydrocarbons (L) + (M ) + (H), and has the following properties: (a) sulfur content from 0.05 wt. % (500 parts per million by weight) to 0.25 wt. % (2500 ppm by mass), (b) the density of the final combination is from 820 to 880 kg / m ³ at 15 ° C, (c) a total metal content of 25 ppm by mass or less, (d) high calorific value - from 43.81 to 45.15 MJ / kg, and (e) low heat of combustion - from 41.06 to 42.33 MJ / kg, (f) wherein (L) contains components of materials of the naphtha and kerosene range that are processed or partially processed, not processed or recovered and used without subjecting them to any fractionation, hydrotreating or other technological process, except for separation, if necessary, light gas or water, has an initial boiling point of 38 ° C (100 ° F) or less, has ninety percent (90%) plus a final boiling point of 190 ° C (374 ° F) to about 205 ° C (401 ° F), where the components of the range (L) contribute to Removable density range (L) and the density of the final combinations, even though some constituent elements (L) can extend beyond the density range of the above combination, (g) wherein (M) contains refined or partially refined petroleum fractions having an initial boiling point of from about 190 ° C (374 ° F) to about 205 ° C (401 ° F) and 90% plus the final temperature boiling point from about 385 ° C (725 ° F) to 410 ° C (110 ° F), where the components of the range (M) contribute to the bulk density of the range (M) and to the density of the final combination, even though the individual constituent elements (M) may fall outside the density range of the above combination, and (h) wherein (H) contains refined or partially refined petroleum fractions having an initial boiling point of from about 385 ° C (725 ° F) to about 410 ° C (770 ° F) and a final boiling point of, approximately 815 ° C (1499 ° F) or less, where the final boiling point (N) is the highest boiling point of a component of the stream purified by solvent separation to reduce the presence of asphaltenes and metals, then recovered and subsequently purified by hydroconversion or hydrotreating to level allowing add l such a flow to the combination of (L), (M) and (H) to match the final sulfur content of the fuel combination, and where the components of the range (H) contribute to the bulk density of the range (H) and to the density of the final combination, although the individual components elements (H) may fall outside the density range of the above combination. 11. Fuel according to claim 10, characterized in that the fuel has at least one of the following additional properties: (a) kinematic viscosity at 50 ° C - less than 10 mm ² / s, where 1 mm ² / s = 1 cSt, (b) the carbon residue is in the range from 0.32 to 1.5, (c) the actual dissolved resins are less than 5, (d) oxidative stability of about 0.5, (e) an acid value of less than 0.05 mg KOH / g; and (f) sulfur content from 0.05 wt. % (500 parts per million by weight) to 0.1 wt. % (1000 parts per million by weight). 12. Developed fuel for marine or land-based engines, in gas-fired turbines, or in fire furnaces, containing light oil of low-permeability reservoirs and an effluent resulting from a hydroconversion reaction that boils at the highest temperature the purified soluble deasphalted component oils or other oil residues processed by the aforementioned hydroconversion, wherein the aforementioned fuel has a range of hydrocarbons from an initial rate boiling ratio, the density is in the range from 820 to 880 kg / m ³ at 15 ° C, the sulfur content is 0.5 wt. % or less and a metal content of 25 ppm by mass or less. 13. A method of producing fuel by combining light oil of low permeability reservoirs and an effluent resulting from a hydroconversion reaction containing purified soluble deasphalted oil and lighter materials derived from high sulfur fuels or other refinery residues processed by hydroconversion of the oil residue for the formation of an effluent containing purified liquids and unconverted oils, while the aforementioned unconverted oils and transferred to a solvent separation to remove insoluble remaining metals and asphaltenes to form a soluble deasphalted oil, which is subsequently purified either by hydrotreating or by additional hydroconversion to form the aforementioned purified soluble deasphalted oil, while the aforementioned fuel has an actual sulfur content of 0.5 wt. . % or less, the metal content is less than 100 parts per billion by mass and the initial boiling point, which is the lowest boiling point of the light oil component of low permeability reservoirs or lighter materials resulting from the aforementioned hydroconversion, thus combined, and the highest boiling point is the highest boiling point component of the aforementioned purified soluble deasphalted oil derived from high sulfur fuels s or from other oil residues combined in this way.

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