JP2022051963A - Fuel and compounding combination thereof - Google Patents

Abstract

PROBLEM TO BE SOLVED: To provide the fuel and compounding combination that is useful as the fuel, wherein the fuel is manufactured using a light tight oil and a high sulfur fuel oil, has very low sulfur and nitrogen, and is substantially metal free.

SOLUTION: The fuel is obtained by combining the light tight oil with a hydrogen-conversion reaction effluent having lighter materials derived from a treated soluble deasphalting oil and a high sulfur fuel oil, or with other residues treated by residues hydrogenation. An unconverted oil passes through solvent separation to remove insoluble residual metals and asphaltene, then, a soluble deasphalting oil is formed, followed by hydrogen-treatment or hydrogen-conversion to form said treated soluble deasphalting oil. Sulfur content of the fuel obtained in combination is 0.5 wt.% or less.

SELECTED DRAWING: Figure 1

COPYRIGHT: (C)2022,JPO&INPIT

Description

The present invention is a novel method of producing fuel and a wide range (C3 or C5 ~) produced from crude oil.
Provided is a novel method for preparing a composition assuming a fuel having a hydrocarbon of C20 or higher).
Preferred feedstocks in the methods of the invention are in conventional refineries such as refinery intermediate residues, high sulfur fuel oils, low sulfur fuel oils or light tight oils, condensates, superheavy oils, tarsands and asphalt. Is a hydrocarbon source that has been considered unfavorable as a raw material oil. The fuel provided by the present invention is an ultra-clean fuel having a very low amount of sulfur and nitrogen and a very low amount of metal as measured by many techniques, with almost no metal detected and substantially containing metal. It is a particularly cost-effective fuel not only for use on large marine transport vessels, but also on land for large onshore combustion gas turbines, boilers and transport vehicles and trains.

The present invention has at least three problems: (1) converting low-value hydrocarbons to high-value fuels, (2) cost-effectively reducing sulfur and nitrogen and substantially removing metals from the fuels.
And (3) to adapt the fuel for use in combustion heaters such as offshore or land engines, combustion gas turbines, or boilers.

Certain hydrocarbon sources are not desirable as a refinery feedstock and may be undervalued by the refinery. Traditional refineries seek to divide each barrel of crude oil with all or a wide range of hydrocarbons into feedstock from multiple fuel and downstream chemical products. In many cases, refineries prefer feedstocks with a wide range of hydrocarbons. In competition where margins are often very small, a particular refinery not only meets the customer's supply constraints, but also balances the materials and energy required to meet all unit operations. To achieve
Although requiring most of the total carbon range of crude oil, these refineries also tend to opt for feedstocks that do not cause processing problems or increase operating costs.

Traditional refineries have operational problems with very heavy crude oil such as Maya (Mexico), BCF-17 (Venezuela), and Oriente (Ecuador), which cause problems with equipment, operating and investment costs. encounter. Such problems can occur similarly with the treatment of oil shale obtained from organic-rich sedimentary kerogen-containing rocks and condensates.

Traditional refineries also face the problem of processing light tight oil, which is sometimes described as "missing most of the bottom of the barrel" compared to crude oil. Light tight oils (also simply referred to as tight oils) are now widely available as made from shale and other low permeability formations such as sandstone and carbonates. Compared to conventional crude oil
Tight oils have excess gas ends, but are boiled or "boiled above 425 ° C or 565 ° C, respectively" in the refinery, called "vacuum gas oil" range or "heavy residue" or "vacuum residual oil" range, respectively. There is little or no hydrocarbon in the "bottom of the barrel" heavy range material. See Non-Patent Document 1.

"Tight oil", "light tight oil" or "LT" as used herein.
The terms "O" are (i) almost unmeasurable or zero (0) sulfur content in the range of% to 0.2% by weight, (ii) density, API (degrees) in the range of 38 to 57 degrees, (. iii) Petroleum Iguchi condensates, unaccompanied natural gas condensates or shale gas condensates with traces of metal and (iv) wide variation of sources based on hydrocarbon ranges, but not all are the same. LTOs from different sources have different distillation withdrawal fraction ranges. According to the description used for the range of fractions characterized by a particular refinery, exemplary variations in LTO are (a) 5-20% by weight liquefied petroleum gas range, (b) 10-35% by weight. Naphtha, (c) 15-30% by weight kerosene / jet range, (d) 15-25% by weight diesel and heavy fraction, (e) trace level to 10% or more decompressed gas oil, and (f). It may have a heavy residue of zero (0%) to about 5% by weight or more.

Such light tight oils, especially those with a small amount of heavy light oil and substantially zero or very small amounts of heavy residue, are substantially free of heavy hydrocarbons in the bottom fraction in the light oil. ,
Sulfur and metals in such light crude oils that do not contain a range of residues to provide a processing balance for desulfurization or other hydrogenation treatments or the corresponding residues sufficient to maintain process hydrogenation. It is capable of cost-effective hydrogenation for reduction and decontamination, or has sufficient lubricity for use in certain types of engines. See, for example, Non-Patent Document 2 which provides a range of components for a particular tight oil. Mixing tight oil with heavy asphalt crude oil is a desirable distillation profile for many refineries in order to balance the mixture of product withdrawals from the crude oil distillation column and adapt it to the operation of many refineries. It is meaningful because it brings about. This is recognized by those skilled in the art,
Doing this also leads to compatibility issues such as asphaltene instability (Non-Patent Document 3).

Also in high sulfur fuel oils or "HSFO", which may be described as part of "the bottom of the barrel" or "the one lacking most of the top of the barrel" compared to crude oil. Traditional refineries face processing problems. For other uses in the art, "
The term "high sulfur fuel oil" or "HSFO" has been assigned different, sometimes dissimilar, contradictory and confusing meanings in various technical articles, patents and legislation, some of which change over time. It is a thing. The widely used term "high sulfur fuel oil" is a light, low-boiling, but high-sulfur (and therefore high-smoke) kerosene containing more than 3.5% by weight of sulfur, including those other than those used in fuels. Heavy marine bunker fuel or mast with quantity
It is used to describe a wide range of materials, including t) or other heavy residues, up to the "barrel bottom" material, and in some cases does not have a clear or uniformly applicable specification. The specific index reporting system is based on the ISO8217 specification, which is based on HSFO with sulfur content of RMG.
It is used as a fuel oil with a ratio of 3.5%, but different sulfur contents are used elsewhere.

As used herein and in the claims, "high sulfur fuel oil" or "HSFO".
"" Means a substance used as a fuel having a sulfur content of more than 0.50% m / m (0.5% by weight). "Heavy oil", "heavy residual oil", "residue", "residue" as used herein.
The terms "residue" or "other heavy oils", "tar sands" and "ultra-heavy oils" are petroleum-derived hydrocarbons with a sulfur content of more than 0.50% m / m (0.5% by weight). Contains system substances. "
The term "high sulfur" means the lower of the fuel's target sulfur content limit or the applicable statutory sulfur limit.

Another problem is that the market for high-sulfur fuel oil is shrinking and it is not possible to add a large amount of HSFO.
It cannot be transported. Many countries that burn HSFO to meet electricity demand are substituting natural gas for local supply. For example, in 2015 Mexico became an exporter of HSFO from a net importer when power plants switched to a local supply of natural gas.

For example, in some parts of the United States, the requirement for petroleum for home heating has been changed to sulfur content of 500 weight ppm or less instead of sulfur content of 2,000 weight ppm or more. As a result, certain pipelines and distribution networks will have high sulfur fuel oils in certain areas, especially in areas where local refineries do not have the feedstock, equipment or technology to efficiently process low sulfur fuel oils. Refining to transport "high-sulfur fuel oil" in connection with the impact of oversupply. For many refinery managers, the practical choice to improve the quality of the residue to better address the required investment with HSFO return on investment is much lower than alternative investment. The use of HSFO as a turbine fuel causes corrosion and contamination problems and is unreliable.

In prior art refinery designs using atmospheric crude oil and / or vacuum distillation units, solvent separation, hydrotreating, gasification and many other unit operations, each barrel of crude oil feedstock has different uses or downstream treatment. Divide into multiple products with different specifications for each.

Hydrogenation skimming refineries convert crude oil into multiple products similar to topping refineries, but typically weight to reformers that also produce the hydrogen consumed by the hydrotreat in diesel production. Addition of quality naphtha is limited. Hydrogenation skimmers, such as topping refineries, are not a single product, but typically a wide range of gasoline for local consumption.
Make kerosene, diesel and fuel oil. Various aspects of adapting hydrogenation including separate series or parallel hydrogenation reactor zones or integrated hydrogenation reactor zones are known in the art. Patent Document 1 of Cash et al. And the references cited therein disclose integrated hydrocracking and hydrotreating of different feedstocks, containing hydrogen and liquids from separate hydrotreating zones. Containing streams are distributed or combined by the disclosed methods.

Early boiling systems were described in Johannson's Patent Documents 2 (1961) and 3 (1961).
1965), a hydrogenation conversion treatment of heavy oil and residues with a boiling bed reactor is known in the art. The boiling bed reactor has fluid contact between the heavy hydrocarbon solution and hydrogen in the presence of a catalyst in the reaction vessel, with various associated auxiliary gas-liquid separators and hydrogen composition and regeneration flow, and sulfur content. Gas treatment systems are well known and are commercially practiced in the art. Patent Document 4 of Collyar et al. Describes a series of boiling reactors, and Patent Document 5 describes a hydrogenation conversion step by a boiling reactor and a hydrogenation treatment step by a fixed bed hydrogenator. Pat. Hydrogenation decomposition and hydrogenation treatment catalysts are also described. Baldassari et al. Further summarize the various catalytic compositions and condition ranges for distillation and heavy oil hydrogenation treatments and classify the conditions for hydrocracking and residue hydroconversion. All of these are known to those of skill in the art in the art of hydrogenation treatment.

Various aspects of the use of solvent separation to extract the deasphalized oil from the pitch in the heavy residue stream and use the deasphalized oil as a raw material for the hydrogenation process to produce multiple product streams. As used, it is known in the art. For example, Patent Document 7 (2010) of Brierley et al. Separates the feedstock based on its solubility in liquid solvents such as propane or other paraffinic solvents such as butane and pentane, and deasphaltizes without cracking or decomposition. Describes solvent deasphaltization for oil production. The pitch residue contains a high content of metal and sulfur. According to Brierley et al., De-asphalated oil is used to remove sulfur, nitrogen and metals as described in the references for the production of some products including naphtha, kerosene, diesel and residues. It is hydrolyzed and hydrotreated.

Patent Document 8 (2009) by Lenglet describes a method for pre-producing crude oil for producing two non- asphaltene oils and pre-distillation, vacuum distillation, solvent deasphaltification, hydrogenation treatment, hydrocracking and residues of asphaltene oil. It describes the preparation of multiple products with hydroconversion. In Non-Patent Document 4, sulfur is removed by hydrogenation and highly active Ni / M.
o Unit design, catalyst selection, hydrogen consumption and other operating conditions for producing products with less than 8 ppm sulfur by the use of catalysts are described. Page 6 of Non-Patent Document 5, Advanced Purification Technology, Publication No. 113/2013 of Specified Edition of Catalagram also has high activity CoM.
o Described is a hydrogenation treatment in which sulfur without steric hindrance using a catalyst is removed by a highly active NiMo catalyst to remove residual steric hindrance sulfur to 10 ppm.

Thus, traditional refineries have made many improvements to address the technical problems that arise from treating light tight oils and residues, but serious problems remain without a solution. ing. Such problems create technical ditches and result in substantially inadequate use of light tight oils and high sulfur fuel oils.

PCT / US1999 / 00748 U.S. Pat. No. 2,987,465 U.S. Pat. No. 3,197,288 U.S. Pat. No. 6,270,654 U.S. Pat. No. 6,447,671 U.S. Patent Publication No. 20140221713 (U.S. Patent Application No. 13/75 8,429) U.S. Pat. No. 7,686,941 International Application PCT / FR2006 / 000671 (US Patent Application No. 11 / 912,771)

"Refining America's New Light Tight Oil Production", OPIS 16th Panasonic National Supply Summit, Las Vegas October 2014) Baker & O "The North Dakota Petroleum Council Study on Bakken Creator Proties" (2014), Turner & M. Benoit et al., "Overcoming the Challenges of weight / shale oil refining," Proc essing, Shale Feedstocks, (2014). Ackerson et al., "Revamping Diesel Hydrrators For Ultra-Low Sulfur Using IsoTherming Technology" Shiflet et al., "Optimizing Hydroproc essing Catalyst Systems for Hydrocrack ing and Diesel Hydrotreating Applicati ons, Flexibility Through Catalyst", Adva nced Refining Technologies Catalagram Special Edition Issue No. 113/2013, page 6

The present invention makes it possible to use light tight oils and high sulfur fuel oils to produce fuels with very low sulfur and nitrogen and virtually no metals in large quantities, effectively and at low cost. And fill the technical gap. The fuel is particularly useful for large-scale onshore applications such as combustion gas turbines for power generation, as well as for marine applications. The terms "essentially / substantially metal-free" or "zero metal" as used herein and in the claims range from zero to less than 100 ppb. It means a metal content or a content that is too low to be reliably measured by conventional online instruments.

The present invention provides a novel method for preparing a composition having a wide range (C3 or C5 to C20 or more) of hydrocarbons and assuming a fuel produced from crude oil from high sulfur fuel oil and light tight oil. A preferred feedstock for the method of the invention is a hydrocarbon feedstock, such as a high sulfur fuel oil or light tight oil, which has been previously unfavorable as a feedstock in conventional refineries.

The fuel of the present invention is an ultra-clean fuel that is very low in sulfur and nitrogen and is substantially free of metals, especially for use on large marine transport vessels on board, as well as large onshore combustion gas turbines, boilers and transport. It is a particularly cost-effective fuel on land for vehicles and trains.

In conventional refining, crude oil feedstock is extracted into many parts, each part being sent to a separate market channel downstream. In contrast, the inventors have taken "barrel top" light tight oil and "barrel bottom" high sulfur fuel oil and combined them at low cost to produce from crude oil.
We have found that fuels can be produced assuming fuels with a wide range of hydrocarbons.

The present invention provides a low cost system that combines light tight oil and residual oil at low cost to produce a large amount of clean fuel on a commercial scale. The fuel replaces high sulfur bunker fuels and other heavy residues used in commercial transport vessels and power plant combustion systems. The present invention
Such fuels and methods and devices for producing such fuels are provided to reduce sulfur, nitrogen and toxic metal emissions in a cost-effective manner. For the shipping industry, the novel configuration of the present invention provides the amount of low cost low sulfur marine fuel required to meet or exceed global marine sulfur reduction targets.

In addition, the fuels of the invention are also crude oil or heavy in large onshore combustion turbines deployed in single-cycle or combined-cycle power plants, such as those that produce equipment, eg electric power and desalinated water. It provides an alternative to burning the residue. The turbine that burns the fuel of the present invention has significantly lower turbine exhaust gas emissions of NOx, SOx, CO _2, soot, harmful metals and other combustion by-products, and is contaminated heavy oil depending on the source. Or when burning refined residual oil, there is less contamination in high temperature zones or under ash formation conditions.

These new processes use empirical steps to reduce manufacturing costs while controlling the sulfur content of the final product below the target sulfur level in a surprisingly effective way. In conventional purification, the extracts are separated and then recombined.

For example, in the prior art of compounding, the focus of compounding is to form a gasoline, diesel, or jet fuel, and all of the separate refinery products are compounded to form a single fuel. is not it. That is, crude oil is not separated into a large number of fractions by distillation, but all are then recombined. For example, the technique avoids blending large amounts of diesel range material into the gasoline range. Also, the end user does not have to mix diesel with gasoline. Similarly, the confusion associated with the terms "kerosene" and "light fraction" is the distillation column fraction boundary point or other at normal pressure over the temperature range (eg 190 ° C to 250 ° C or 180 ° C to 230 ° C). Not uniformly defined on the basis of established standards alone, often due to the use of these terms with different meanings among the same, overlapping, or different reference substances. For example, the EIA defines "intermediate distillates: refined petroleum products containing general classifications of distilled fuel oils and kerosene". Therefore, the purification boundary point in the temperature range is determined by the specifications of each product from the conventional refinery, is often set for each region, and is not defined based on the sulfur content. We have found that this is not optimal.

As used herein, the term "component" is used in contrast to the unexpected phenomenon found by "combining components" in the practice of the present invention, in contrast to simply blending the components. To. The typical use of the term "ingredient" when referring to a combination of those with human intervention gives hope for the consequences of the presence of the ingredient. That is, the ingredients are
When added, it gives the expected physical or chemical properties that are characteristic as a whole.

Traditional refineries do not mix gasoline with diesel or processed residual oil to produce fuel. Instead, separate the ejectors for different engine types.

What was not known to those skilled in the art of the essential oil technology until now disclosed by the present invention is a novel fuel formulation, with many light (L), intermediate (M) and heavy (H) configurations. It is the best way to select and / or obtain from the elements (taught and defined below) and to combine selected components to form a low sulfur, substantially metal-free fuel. Such ones are looking at a warehouse filled with cooking ingredients, but there is no recipe for the lowest cost and lowest calorie cake, and the amazing interactions that occur by processing and combining the ingredients in a particular way. It's very similar to a bakery who doesn't even know about the phenomenon.

Schematic diagram showing the basic equipment and processing process of combining untreated light tight oil and treated high sulfur fuel oil to form a fuel with unusually low sulfur. Explanatory drawing showing the production of low-sulfur yellow fuel with adjusted flash point by simplifying the processing of light cycle oil and high-sulfur fuel oil. Schematic diagram showing equipment layout and processing steps using crude oil alone or with light tight and high sulfur fuel oils to produce ultra-clean fuels with very low sulfur, nitrogen and metals. Teaching recipes for combinations of one or more components with new fuels and light (L), intermediate (M) and / or heavy (H) materials for forming such fuels, according to the invention. Explanatory drawing schematically showing the volume fraction and density profile of the reference fuel produced by the method, and the ranges of (L), (M) and (H) thereof. Teach recipes for combinations of one or more components with light (L), intermediate (M) and / or heavy (H) materials to form new fuels and such fuels (naturally). The volume fraction and density profile of the reference light condensate which has the majority of the existing (L) and can be used as the "upper barrel" (where the naturally occurring (M) and (H) are small) is shown. Explanatory drawing of the upper part of the barrel, combined with (H) from other sources such as the "barrel bottom" (H) component, to constitute the fuel of the present invention.

The present invention provides a method of converting various hydrocarbon-based feedstocks from sources other than conventional crude oil, alone or with conventional feedstocks, to form fuels with a wide range of hydrocarbons. In the modified example, the fuel formed by the light tight oil supply material and the high sulfur fuel oil supply material is a hydroconverted liquid derived from the high sulfur fuel oil from the lowest boiling point of the light tight oil forming the fuel. It has a wide range of hydrocarbons up to the maximum boiling point of and forms the fuel.

In one embodiment, one or more high sulfur fuel oils are supplied to the residue hydrogenation conversion zone.
In the presence of a catalyst in a boiling bed reactor, contact with hydrogen under residual hydrogenation conversion conditions (1)
It forms a hydrogenation conversion product solution, a hydrogenation conversion reactor effluent separated into a purge gas containing hydrogen and sulfur, and (2) unconverted oil towards solvent separation. Such unconverted oil is (A)
) As a feedstock, together with the separately or added high sulfur fuel oil feedstock, the soluble deasphalized oil recovered in the hydrogenation conversion reactor and (B) the insoluble pitch sent to the pitch treatment are formed. The product fuel is formed by combining all or part of the light tight oil with the hydrogenation conversion product liquid. In one variant, before use as part of the combination, the light tight oil is fractionated to remove the overhead distillation gas, leaving the bottom of the separator combined with the hydroconversion zone product liquid to form the fuel. .. In another variant, some of the feedstock for solvent separation has high sulfur total oil that is added directly to the solvent separation or supplied to the solvent separation in combination with the unconverted oil in the hydroconversion reactor. .. Further, the additional high sulfur fuel oil can be combined with the soluble deasphalted oil and supplied as a part of the feedstock to the hydrogenation conversion reactor. Fractionalizing light tight oil prior to addition to the fuel combination, removing overhead distillation gas, taking into account ignition points and others, upper zone light distillates with naphtha range hydrocarbons and high boiling bottom fractions. Fractions can be formed. In one variant, at least some of such light fractions are naphtha-rich and sent to reformers or other fragrant oil unit operations to contact hydrogen under reforming conditions for light treatment flow. Form. In another modification, all or part of the light treated stream, the untreated light stream and the high boiling bottom fraction are combined with the hydroconversion liquid to form a fuel. In yet another modification, the effluent from the hydrogenation conversion reactor is fractionated and separated into two or more treated liquid fractions, at least the fraction having a sulfur content higher than the target sulfur content. One is used as part of the feedstock for the residue hydrogenation conversion reactor or as part of the feedstock for fractional distillation.

In one embodiment, the residue hydrogenation conversion zone integrates the residue hydrogenation conversion reactor with a heavy oil range hydrogenation treatment device and a distillation range hydrogenation treatment device, a gas-liquid separator, a hydrogen stream, a purge gas,
Integrate one or more of the sulfur recovery process and common treatment liquid recovery. In another variant, in such an integration, the treatment liquid recovery could be configured separately, allowing the measurement of the sulfur content of each stream and the adjustment of the flow rate to the combination zone, respectively, in practice. Form a fuel whose sulfur content is less than or equal to the target sulfur content. In the modified example, the treated product flow from the upper zone of the hydrogenation conversion reactor zone effluent is separated into two or more hydrogenation conversion liquid distillates, and the sulfur content is higher than the above target sulfur content. At least one of the distillates having hydrogen is sent to another hydrogenation treatment zone, and in the presence of a catalyst, it is brought into contact with hydrogen under hydrogenation treatment conditions, and a low sulfur hydrogenation treatment having a sulfur content less than the above target sulfur content is performed. Form a flow. Then
The hydrogenation treatment flow is combined with other hydrogenation conversion liquid distillates and the untreated flow derived from the above-mentioned light tight oil to form a fuel having an actual sulfur content of less than or equal to the target sulfur content.

In one embodiment, the light tight oil feedstock has an API density in the range of 45-55 degrees, the high sulfur fuel oil has an API density in the range of 14-21 degrees, and the hydroconversion liquid has 2
With an API density in the range of 6-30 degrees, the combined fuel product has an API density in the range of 37-43 degrees and a sulfur content of less than 0.5% by weight. The actual sulfur content of the fuels of the present invention is adjusted to meet the target sulfur content within the IMO specifications for marine fuels or the turbine manufacturer's specifications for combustion gas turbines, as disclosed herein. can do.

Another embodiment of the present invention provides a method for co-treating crude oil with light tight oil and high sulfur fuel oil. Within the scope of the present specification and claims, the present inventors have defined the mass% or volume% of crude oil on the x-axis and the sulfur content on the y-axis in connection with the analysis or other measurement method of crude oil. Plot and define the "breaking point" as the point where the rate of increase per unit operation is high, the sulfur content begins to increase sharply or exponentially from a horizontal or near position. The difference in operation is the change in the unit volume of the distillate, and the difference in the rise is the change in the sulfur content.
Slope is the amount of increase in operations. The slope with respect to such an increase in operation rapidly moves above 0.2 from zero or near-horizontal values and rapidly exceeds 1 towards an exponential increase in sulfur content. Movement, break points vary based on crude oil or other feedstock to the distillation column. Therefore, "break point retrieval" or "sulfur break point retrieval" exceeds the end point of the range of naphtha, for example, the end point of the range of unstabilized wild straight naphtha, but as described above, per unit operation. Provided is a means for determining the division of a hydrocarbon-containing liquid that boils below the break point where the rate of increase is high and the sulfur content begins to increase rapidly or exponentially.

In the specification and claims, the base "break point retrieval" or the basis "sulfur break point retrieval" exceeds the end point of the range of unstabilized wild straight naphtha with respect to the sulfur content of the distillate. , Means a hydrocarbon-containing liquid that boils below the break point. If the fuel product flow is formed from a combination of all untreated flows below the break point and all flows above the break point fetch selected to be added to form the combination, then the break. The points are selected so that the actual sulfur content of the combined fuel does not exceed the target sulfur content. In a variant, fuel can be produced when the target sulfur content is at the sulfur break point, or is higher or lower than the sulfur break point, and the combination of flows that produce the fuel is that of the fuel. It is efficiently made based on the above break point so that the actual sulfur content does not exceed the above sulfur target.

A hydrocarbon-based feedstock containing crude oil and high sulfur oil with relatively high sulfur, nitrogen and metal content is supplied for atmospheric and vacuum distillation, (1) light overhead distillation gas, (2) below the sulfur break point. Liquid distillates, (3) (A) distillation range distillates containing sulfur, (B) decompressed light oil range distillates containing sulfur and (C) distillates above the sulfur break point with decompression residues containing sulfur. , And (4) Distillation Units Separated into sulfur-containing purge gases such as distillation gases, strippers and other unit operating overheads that contain small amounts of sulfur. The liquid fraction below the sulfur break point is supplied to the combination zone as an untreated liquid to form at least a portion of the fuel. The distillation range fraction and the reduced gas oil range fraction are brought into contact with the added hydrogen under the hydrogenation treatment conditions in the presence of a catalyst in a distillation and reduced pressure gas oil hydrogenation treatment device to produce one or more hydrogenated liquids. Form. The hydrotreated liquid is sent to a combination zone and a purge gas having sulfur. The decompression residue is sent to the boiling residue hydrogenation conversion zone, comes into contact with the added hydrogen under boiling hydrogenation conversion conditions in the presence of a catalyst, and is supplied to (1) the combination zone to form part of the fuel. Another treatment liquid, (2) purge gas with sulfur, and (3) soluble deasphalized oil supplied for solvent separation and (A) either alone or in combination with decompression residues for residual hydrogenation conversion. And (B) unconverted oil, which forms the insoluble pitch sent to the pitch process. The untreated liquid is combined with the treated liquid to form a fuel whose actual sulfur content is less than or equal to the target sulfur content. Preferably, at least one of the hydrogenation treatment streams is an ultra-low sulfur stream having sulfur of 10 ppm by weight or less, and the actual sulfur content can be increased by increasing or decreasing the amount of the stream with respect to the combination. The above fuel is formed by adjusting the sulfur content to be less than or equal to the target sulfur content.

In a modification of the method of the present invention, the crude oil is described except for (i) a light overhead distillation gas of the distillate, (ii) pitch and (iii) a hydrocarbon composition having a hydrocarbon in sulfur or metal recovery steam. Substantially all hydrocarbon compositions of feedstock can be separated into each fraction and subsequently recombined to form the fuel, which is a single liquid fuel product rather than multiple hydrocarbon products. can. The fuel is treated with a hydrocarbon in the range from the lowest boiling point portion of the untreated liquid fraction from atmospheric distillation to the highest boiling point of the flow recovered from solvent separation, followed by hydrogenation treatment or hydroconversion reactor. Can have a combination with a stream that is collected, recovered and incorporated into the fuel. In one variant, at least one of the hydrogenated steams is 10.
When the untreated fraction has a sulfur content exceeding the target sulfur content and the untreated fraction is used as a trim control, the combination is described in an ultra-low sulfur flow having sulfur of less than ppm by weight. By reducing or increasing the amount of such untreated fractions relative to, a fuel having an actual sulfur content below the target sulfur content is formed. In another variant, the first hydrotreated stream is made as a stream with a reduced sulfur content with a sulfur content of less than 10 wt ppm and the second hydrofuel fraction has a sulfur content of 0. Made as a stream with a reduced sulfur content in the range of .12 to 0.18 wt%, the untreated fraction has a sulfur content that exceeds the target sulfur content and is the first hydrotreated. Flows and / or second hydration treatment flows are used for trim control to form fuels whose actual sulfur content is less than or equal to the target sulfur content by increasing or decreasing the amount of such flow relative to the above combination.

In one variant, the residue hydroconversion and hydrotreating zones have separate distillation hydrotreating reactors, heavy oil hydrotreating reactors and residue hydroconversion reactors, each of which is separate. Forming treated effluents, each treated effluent is fed to a separate shared wall separator, forming a common overhead gas with sulfur and reducing one or more separately associated with each reactor treated effluent. The gas-liquid treated effluent was separately removed from the separator at a rate based on the respective sulfur content and sent to (a) in combination with the untreated liquid stream, where the actual sulfur content was the target sulfur content. It forms a fuel that is less than or equal to the amount, or (b) is sent to pre-storage for subsequent trim control of the sulfur content of the fuel. In certain variations of the method of the invention, the amount of output product fuel may exceed the total amount of input feedstock, at least in part due to the volume increase caused by the addition of hydrogen.

These novel methods can adjust the sulfur content of the combined fuel to meet the target sulfur content within the IMO specifications for marine fuels or the turbine manufacturer's specifications for combustion gas turbines. Therefore, the fuels are particularly useful for offshore or land engines, combustion gas turbines or combustion heaters. Certain fuel variants induced by the combination of light tight oil and high sulfur fuel oil treated by residue hydroconversion have an actual sulfur content of less than 0.5% by weight and crude oil derived hydrocarbons. A fuel in the range of about C5 to C20 or higher is produced. The hydrocarbon has an initial boiling point, which is the lowest boiling point of any fraction in the untreated stream combined with the fuel, and the highest boiling point of the effluent portion of the effluent from solvent separation, followed by hydrogenation. Alternatively, it is treated by hydroconversion and combined to form part of the fuel.

FIG. 1 outlines an embodiment of the present invention and simplifies the main components of a method for converting a hydrocarbon-based feedstock having sulfur and a metal to form a fuel. The light tight oil feedstock 1 is preferably passed through a basic gas-liquid separator prior to manufacture, shipment or other handling to separate or stabilize light companion gases, or to remove water and precipitates, or. Receive other minor adjustments. The light tight oil feedstock 1 contains a relatively light and intermediate range of hydrocarbons with a relatively small amount of sulfur and metal and a relatively small amount of heavy oil, and is combined as an untreated liquid stream in the combined zone 600 without additional treatment. Provided to. The high sulfur fuel oil having sulfur, nitrogen and metal is supplied to the residue hydrocarbon conversion zone 401 via the line 41, and the residue hydrocarbon conversion such as a boiling bed reactor selected based on the feedstock composition. A reaction in which the oil 41 is brought into contact with hydrogen in a vessel or other suitable hydroconversion device in the presence of a catalyst under residual hydroconversion conditions, and the zone 401 is divided into (1) treated hydroconversion liquid 411. Vessel-classified effluent (in this specification, the "hydroconverted liquid" referred to as a type of treatment liquid contains substantially the entire range of hydrocarbons from the boiling range of about C5 to the minimum boiling point of unconverted oil 409. It forms (2) unconverted oil 409, which has hydrocarbon conversion residues, purged gas 420 with purged hydrogen and off-gas, components of liquid petroleum gas, and acidic gas with sulfur). Such separation is preferably in the form of vacuum distillation, and in the case of certain feedstocks, distillation close to atmospheric distillation may be effective in separating unconverted oils. The unconverted oil 409 is supplied for solvent deasphaltification in Zone 301. The solvent-de-asphalated separation 301 forms (A) soluble de-asphalated oil 311 and serves as a feedstock for the hydrogenation conversion reactor in the zone 401.
Recycled separately or in combination with the high sulfur fuel oil feedstock 41 added to the reactor. The solvent deasphalted separation 301 also forms an insoluble pitch 351 supplied to the pitch treatment in (B) Utility Island 501. In the modification shown in FIG. 1, the pitch 351 is supplied to the utility island 501 and processed.
In this embodiment, the pitch is burned in one or more gasifiers (not shown) to capture power and at least a portion of the metal removed in the hydrogenation conversion and gasifier solids. Can produce at least a portion of the hydrogen for.

The untreated liquid of line 1 is combined with the treated liquid 411 and combined with the combination zone 600.
Form fuel inside. The fuel 600 is a high sulfur fuel in which the light and intermediate range hydrocarbons (i) of a light tight oil feedstock, condensate or other light feedstock 1 are present together with the treated liquid effluent 411 of the hydroconversion zone 401. Heavier range of hydrocarbons in oil 41 (ii)
Combined with many of the above, the fuel 600 has a wide range of hydrocarbons from C5 to C20 or higher. The fuel thus formed has a wide range of hydrocarbons, from the lowest boiling point of the lighttight oil forming the fuel to the highest boiling point of the hydrocarbon of line 311 dissolved in the solvent separation 301. Then, it is treated with hydrogen in the zone 401 to form a part of the effluent 411 for forming the fuel. Compositions 1 and 41
The amount of 1 and the flow velocity can be adjusted so that the actual sulfur content of the fuel 600 is equal to or less than the target sulfur content based on the respective sulfur contents. For example, if, but not limited to, the stream 1 has an unacceptably elevated sulfur content and cannot be used for combination within the zone 600, the untreated stream 1 is fractionated (separated). (Not shown), the heavy bottom portion of any higher sulfur content can be sent to the integrated hydrogenation treatment equipment in Zone 401 for treatment, and the other parts of Flow 1 remain untreated in the combined zone. It can pass through 600. However, the extraction of higher sulfur content resulting from the treatment upstream of the hydroconverter, for example, the bottom of atmospheric distillation, is hydrodegraded under hydroconversion conditions, unnecessarily consuming hydrogen and is essentially light. It produces a lighter material present in the tight oil feedstock and is not fed to the hydroconversion as part of the flow 41. Instead, such higher sulfur removal is sent to a separate hydrogenation zone, as shown in the variants below. In this variant, the production zone effluent treated by one or more reactors in Zone 401 can be separated into two or more hydroconversion liquid distillates by fractional distillation, at least one such distillate. If one has a hydrogen content higher than the target hydrogen content, such fractions alone or with other flows having similar sulfur content and boiling range from outside Zone 401. Sent to one or more separate hydrogenation zones within Zone 401 to contact hydrogen in the presence of a catalyst under hydrogenation conditions and reduced sulfur content, preferably 0.5% by weight or less. , More preferably to form a hydrogenation treatment flow of 0.2% by weight or less,
The low sulfur hydrogenation treatment flow is combined with the untreated flow from the light tight oil or the flow remaining from fractional distillation or other treatment of the light tight oil so that the actual sulfur content is below the target sulfur content. Form a certain fuel. In one variant, the in-series or integrated hydrogenation system is 10 ppm by weight or less, depending on the amount of ultra-low sulfur or low-sulfur treated liquid required for the combined flow having a sulfur content below its target sulfur content. Yields a sulfur content of 0.1% by weight.

In the modification of the residue hydrogenation conversion system 401 shown in FIG. 1, the constituent hydrogen-containing gas 502 in the amount required for hydrogenation conversion from the utility island 501 gasification system is inside the residue hydrogenation conversion block 401. With recycled hydrogen, compressed, heated and effective operating temperature, pressure, space known in the art to achieve the desired level of hydrogenation conversion based on the selected catalyst and other conditions. Adjusted to speed and pressure. The effluent and hydrogen-containing gas of the Zone 401 reactor having the treatment liquid are separated and recovered by a high-pressure separator (not shown). Purge gas with sour and acid gas is supplied via line 420 to Utility Island 501 with a pitch treatment and sulfur recovery system.
Pitch treatment can have combustion in one or more boilers to produce electricity and steam, alone or with diluent, and in some cases sulfur from flue gas and other process gases. And ancillary equipment for removing or reducing metal and a hydrogen generation unit with a pressure swing absorption unit can be used. In another variant, pitch processing is by transfer for asphalt production or use as a coke feedstock for raw coke production. In yet another variant, the pitch is burned in one or more gasifiers to generate at least a portion of the metal for power generation, hydroconversion or hydrotreating and in the gasifier solid. Produce at least a portion of hydrogen to capture for metal removal through such solids. The optimal choice of how to handle the pitch depends on the amount of pitch produced, the effectiveness of the low cost hydrogen source, and the potential sales channels for the pitch.

Although not shown in FIG. 1, various auxiliary high, medium and low pressure gas-liquid separators, steam heaters, gas reuse and purge lines, reflux drums for separating gas or light components from liquids. , Compressors, cooling systems, and other ancillary applications are known to those of skill in the art of hydroconversion technology. Also, the common Utility Island 501
If not located within, within the hydroconversion zone 401 will include various amine or other sulfur recoverant absorbers and stripping systems for sour gas or acid gas treatment.

The parameters for the selection of the residue hydrogenation conversion catalyst and the adjustment of the process conditions of the residue hydrogenation conversion zone 401 are within the technical scope of those skilled in the oil refining industry and the residue hydrogenation conversion of the present invention. No additional explanation is needed for the implementation of the division. In the reaction zone, the residue hydrogenation conversion catalyst used increases the hydrogen content and / or sulfur,
Includes any catalytic composition useful for catalyzing the hydrogenation conversion of heavy hydrocarbon feeds for removing nitrogen, oxygen, phosphorus, Conradson carbon and metal heteroatomic contaminants. The specific catalyst type and various supports and particle size configurations used and the residue hydroconversion conditions selected are as well as sulfur and metal content and heavy carbon residues, respectively, from recovery or other streams. Hydrogenation of feedstock Depends on the feedstock composition, the desired reduced sulfur and metal content in the product flow from the reactor. Such catalysts can be selected from any catalyst useful for the residual hydrogenation conversion of hydrocarbon feedstocks. US Pat. The hydrogenation conversion catalyst is also described. Ba
ldassari et al. Further summarize the various catalytic compositions and condition ranges for distillation and hydrogenation conversion of heavy oil residues, and distinguish the conditions for hydrogenation conversion. All of these are known to those of skill in the art in the art of residual hydrogenation conversion. In a preferred embodiment of the invention
The boiling bed hydrogenation conversion has a reaction temperature range of 380 ° C to 450 ° C and a reaction pressure range of 70 bar to 17
Performed at 0 bar (hydrogen partial pressure), preferably in the liquid space velocity range 0.2-2.0 h ^-1 , 550
The conversion to ° C-minus ranges from 30% to 80%.

In another preferred variant, the pitch 351 is an integrated gasification having one or more gasification furnaces for partial oxidation of the pitch 351 in the presence of steam and oxygen, and any carbon-containing slurry quench. It is supplied to the composite cycle system 501 to form a syngas, at least a part of which is converted to hydrogen and syngas, similar to the formation of high temperature turbine gas.
The hydrogen is sent to the hydroconversion system 401 via line 502 for use, and syngas is the gas turbine of the combined cycle power unit in the utility island system 501 for power generation within 504 for process and other applications. To burn. Integrated gasification-
The combined cycle system 501 further has a heat recovery generator, recovers heat from high temperature turbine gas and the like, produces steam extracted through the use of line 507 internal processes, or drives a steam turbine, via 504. Directed to additional power generation as electricity. Each gasifier
It also produces metal-rich soot. The soot may be in the form of a granular solid and has metal contaminants derived from high sulfur fuel oil and / or heavy feedstock. The solid is from each gasifier on line 506.
The metal is sent to the removal via. The support system has one or more gas treatment units for sulfur removal via 508, regardless of whether all sulfur-containing gas flows from all unit operations are sour gas or acid gas. Is supplied to the above gas processing unit. Preferably, such a sulfur removal system is part of a utility island of which the gasification system is also a part. More preferably, one or more sulfur-containing gas streams are used for commercial sulfur acid production as part of the overall sulfur removal. The gasification system within the utility zone 501 is typically an acid gas treatment optimized in capacity and configuration to produce the required hydrogen from at least a portion of the source synthetic gas produced within the gasification system. It has a unit and an acid CO shift system.

In the embodiment of the method of the present invention shown in FIG. 2, the liquid flow 4 from the high sulfur fuel oil supply raw material 41
11 is combined with the liquid flow 15 from the light tight oil feedstock 3 in the combination zone 600 to produce a fuel whose actual sulfur content is less than or equal to the target sulfur content.

The light tight oil enters the process of line 3 and heads for the separator 101, where the feedstock 3 has at least two fractions, (a) at least a portion of the naphtha range hydrocarbons in the light tight oil feedstock 3. Upper zone extraction containing all of the lighter, lower hydrocarbons 5
, And (b) are separated into bottoms, including those that are substantially outside the scope of (a). Separator 101
The bottom 11 is supplied to the combination zone 600 via lines 11 and 15 to form part of the product fuel. The upper zone naphtha and the lower take-out 5 pass through (i) a separator (not shown) and through line 7, a process fuel or a light distilled gas used for internal use as a capture or for other purposes. And (ii) Flow 9 which is mainly naphtha range hydrocarbons
Have. After removal of the light gas, all or part of the flow 9 is sent directly to line 15 for direct combination (via connectors, lines 9 and 17 not shown) and zone 60.
At least the low ignition part of the flow 9 is such as a conventional aromatic oil composite with a catalyst reformer well known in the essential oil technology field, either forming part of the fuel at 0 or considering the flash point of the combination 600. The flow 9 is brought into contact with the catalyst in the unit 151 through the treatment unit 151 to produce the by-product hydrogen 505 and the light treatment flow 155 recovered via the line 159 for non-fuel or other applications. Unit 151 may be manufactured in a useful by-product, eg, liquefied petroleum gas 153, which is used internally as a process fuel or captured for other uses.

In FIG. 2, the high sulfur fuel oil enters the treatment via line 41 alone or with other heavy residues or superheavy oils and is supplied to the residue hydrogenation conversion zone 401 with very low sulfur. The liquid flow 41 is manufactured. As mentioned above in FIG. 1, the parameters for the selection of the residue hydrogenation conversion apparatus and the adjustment of various process conditions of the integrated residue hydrogenation conversion zone 401 are within the technical scope of those engaged in the petroleum refining industry. No detailed description of the implementation of the residue hydrogenation conversion classification of the present invention is required. In the illustrated modification of the present embodiment,
The integrated zone 401 has a hydrogenation conversion reactor, and the high sulfur fuel oil and other heavy feedstock in 41 are supplied to the reactor. Such a heavy feedstock 41 is preferably treated in a residue hydrogenation conversion zone 401 having a boiling bed reactor and separated into (1) a treatment liquid 411 and a purge gas 420 having hydrogen and sulfur. Reactor classification spillage and (2) unconverted oil 4
Form 09. The unconverted oil 409 is supplied to the solvent separation 301. The solvent separation 301 forms (A) soluble deasphalted oil 31 and is combined as a feedstock to the reactor 401 separately or in combination with the high sulfur fuel oil feedstock 51 added to the solvent separation zone 301. And be collected. The solvent separation 301 is also supplied to (B) pitch processing, FIG.
The substantially insoluble metal rich pitch 351 according to the embodiment shown in the above is formed.

In the utility modification shown in FIG. 3, the pitch 351 is supplied to the boiler and burned to generate steam for steam turbine power generation 561. The boiler exhaust gas 429
At least a portion of the sour gas or acid for, for example, sulfur capture and removal via line 565, separately or with a hydrocarbon conversion zone 401 acid gas 420 purged from the hydroconversion zone 401 or in another gas stream. Processed within Zone 701 via a separation system for trapping and removing metal via line 563, via various amine or other sulfur recovery agent absorbers and stripping systems for the gas. To. Although not shown in FIG. 2, various auxiliary high, medium and low pressure gas-liquid separators, flow heaters, gas reuse and purge lines, recirculation drums for separating gas or light components and liquids, Compressors, cooling systems, and other ancillary equipment are known to those of skill in the art of hydroconversion and hydrotreating. In the illustrated variant, in addition to any by-product hydrogen 505 from the process unit 151, the other constituent hydrogen supply to the zone 401 is from the hydrogen generation unit 517 with the hydrogen source 519 via lines 503 and 509. A natural gas supply vapor cracker having, for example, but not limited to, a pressure swing absorption unit, is made, for example.
At least a portion of the boiler steam from the utility zone 501, which will be described later, can be used.

The combined heavy residue feedstock to the hydrogenation conversion reactor zone 401 was brought into contact with hydrogen in the boiling bed reactor in zone 401 under the residue hydrogenation conversion conditions in the presence of a catalyst (1). It forms a reactor compartmentalized effluent separated into a treatment liquid 411 and a purge gas 420 with hydrogen and sulfur, and (2) unconverted oil 409. Also, various amine or other sulfur recovery agent absorbers and stripping systems for sour gas or acid gas treatment are included in the hydroconversion zone 401 or separate sulfur recovery zones 701, wherein the high sulfur purge gas 4
28 is supplied. The product fuel is formed by a method in which the treated steam 411 is supplied to the combination zone 600, combined with the untreated flow 15, and the combination is formed so that the actual sulfur content is equal to or less than the target sulfur content.

In the embodiment of the method of the invention shown in FIG. 3, the stream of contaminated crude oil with sulfur, nitrogen and metal enters the treatment via line 2 after pretreatment such as desalting suitable for the crude oil. In this embodiment, the crude oil feedstock 2 can be a single crude oil, a mixture of one or more crude oils, or a crude oil and a residual oil such as light tight oil or high sulfur fuel oil, or a mixture of both. .. In the illustrated modification, the crude oil supply raw material 2 and the light tight oil supply raw material 3 are separately supplied to the atmospheric distillation column 100. Preferably, the light tight oil 3 is the column 1.
It is supplied to the upper part of the crude oil 2 or its vicinity in the feed material passage zone of 00, and the feed material is separated into the light overhead gas 4 and a plurality of ejected materials. The light overhead gas 4 contains a non-condensed distilled gas 6 useful as a process fuel or is captured for other uses. In one preferred variant, the investment associated with the stabilization system for such overhead gas 4 is avoided. However, depending on local needs, stabilization systems will be included, for example, special marine fuel maximum _H2S specifications.

In the embodiment shown in FIG. 3, the plurality of extracts are (1) unstabilized wild straight naphtha of line 16 via line 4, and (2) sulfur break point extraction of line 18.
One within the range of 3) the light fraction of line 24, (4) the intermediate distillate of line 26, (5) the first heavy distillate of line 28, and (6) the atmospheric residue of line 30. Or it may include multiple streams. Preferably, a combination of flows at the sulfur break point (1) line 16 via line 4
Unstabilized wild straight naphtha and (2) line 18 sulfur break point extraction contains 0.06% by weight to less than 0.08% by weight, and the target sulfur content of the fuel combination 600 is When 0.1% by weight or less and the sulfur content of the treatment flow is less than 10% by weight, the flow rate of the untreated steam 10 and the treatment flows 65, 75 and 85 to the combination is targeted at the fuel combination 600. Adjusted so that the sulfur content is not exceeded. In a variant, the untreated low sulfur low metal light tight oil stream is fed directly to the combination 600 via line 53 in addition to the combination of lines 10, 65, 75 and 85 to the final sulfur content and combination zone. Adjust the other parameters of 600.

In FIG. 3, the atmospheric residue is supplied to the vacuum distillation column 200 via the line 37, alone or together with the residual oil supply material 35 to which a high sulfur fuel oil or the like is added, to the (1) line 32. Double distillation, (2) light decompression gas oil on line 36, (3) heavy decompression gas oil on line 38 and (
4) A vacuum residue is produced on line 50. The reduced pressure residue 50 is sent to the integrated residue hydrogenation conversion and hydrogenation treatment zone 401 via lines 57 and 317, alone or with the residual oil 55 added, such as high sulfur fuel oil.

Parameters for integrated residue hydroconversion and selection of hydrotreating equipment and catalysts and adjustment of various treatment conditions within integrated residue hydroconversion and hydrotreating zone 401 are those skilled in the petroleum refining industry. It is within the technical scope of the present invention and does not require a detailed explanation of the implementation of the residual hydrogenation conversion and hydrogenation treatment classification of the present invention. In the illustrated modification of the present embodiment,
In the integrated zone 401, (A) the heaviest and most contaminated feedstock are lines 57 and 317.
Hydroconversion reactor zone 490, where high sulfur fuel oil and other heavy feedstock added via reduced pressure residue 50 and line 55 are supplied, for example, through (B) the heaviest distillation. Substances and light oil are supplied via line 39, for example, having (1) light decompression light oil of line 36 and (2) heavy decompression light oil of line 38, and hydroconversion reactor spills in zone 410. Heavy oil hydrotreated reactor zone 460 to which decompressed oil separated by decompression distillation of the reactor liquid product flow is supplied from the material, and (C) a lighter and less contaminated feedstock via line 20. For example, (1) the light distillation component of the line 24, (2) the intermediate distillation component of the line 26, (3) the first heavy distillation component of the lines 28 and 32, and (4) the second heavy distillation component. It has a distillation hydrotreated reactor zone 430, which is supplied via the line 29, and is supplied with a distillation range material separated into the zone 401 from the hydroconversion reactor effluent. For example, the second heavy distillate of line 32 can instead be fed to the heavy oil hydrotreating device 460 depending on the line 32 composition, loading onto the hydrotreating device reactors in zones 430 and 460. It is necessary to balance and control the sulfur content level. In such integrated residue hydrogenation conversion and hydrogenation treatment zone 401, reuse and constituent hydrogen flow 410
And 414 and purge gas streams 412 and 416 have integrated reuse, separation and removal systems known to those of skill in the art in the field of essential oil technology. Although not shown in FIG. 3, various auxiliary high, medium and low pressure gas-liquid separators, flow heaters, gas reuse and purge lines, recirculation drums for separating gas or light components and liquids, Compressors, cooling systems, and other ancillary equipment are known to those of skill in the art of hydroconversion and hydrotreating. In the illustrated modification, the hydrogen supply 503 is performed from the hydrogen generation unit 517 having the hydrogen source 519, and for example, the natural gas supply steam decomposition apparatus having a pressure swing absorption unit is described in the utility zone described later. At least a portion of the boiler steam from 501 can be used.

The heavy residue feedstock 317 combined with the hydrogenation conversion reactor zone 490 was brought into contact with hydrogen in the boiling bed reactor of zone 401 under the residue hydrogenation conversion conditions in the presence of a catalyst, (1) first. 2 By vacuum distillation unit (not shown), preferably (1) (i) naphtha, (ii) intermediate distillation and (iii) treatment liquid 85 with reduced pressure light oil, purge gases 416 and 428 with hydrogen and sulfur. It forms a reactor-classified effluent that is partially and (2) separated into unconverted oil 409. Also, various amine or other sulfur recoverant absorbers and stripping systems for sour gas or acid gas treatment are contained in the hydroconversion zone 401 or separate sulfur recovery zones 701, to which the high sulfur purge gas 428 is supplied. Sulfur. As is known in the art, during treatment in a hydrogenation conversion reactor 490 boiling bed containing a metal and / or other contaminants deposited on the boiling bed, or in the boiling bed of the reactor 490. At least a portion of the other material accumulated with the catalyst is removed via line 421 and line 423.
It is replaced with a constituent catalyst via. In one variant, the processing liquid 85 with (i) naphtha, (ii) intermediate distillation and (iii) decompressed gas oil is fractionated, the intermediary distillate is sent to the distillation hydrotreating apparatus 430, and the decompressed gas oil is It is sent to the heavy oil hydrogenation treatment device 460.

The hydrogenated unconverted oil 409 is sent to the solvent separation 301. The solvent separation 301 is (A).
) Steam hydrogenation conversion reactor 490 or, in other variants, the hydrogenation conversion reactor 490, separately or in combination with the reduced pressure residue 50, together with the high sulfur fuel oil feedstock 55 when added to Zone 460. It forms a soluble deasphaltified oil 311 supplied via lines 57 and 317 to. Solvent separation 301 also includes (B) Utility Island 501.
The insoluble metal rich pitch 351 supplied to the pitch processing inside is formed. In the utility variant shown in FIG. 3, the pitch 351 is sent to the boiler where the pitch is burned to produce steam for steam turbine power generation 504, where at least part of the boiler exhaust gas 429 is separated within zone 701. In or with Zone 401 Acid Gas 428, for example, treated with various amines or other sulfur recovery agent absorbers, sulfur trapped and removed via line 561 by a sour gas or acid gas stripping system, and line 563 by a separation system. The metal capture and removal process is performed via.

In the modification shown in FIG. 3, the sulfur content of the fuel product 600 is controlled as follows below the target sulfur content limit level. (A) Unstabilized wild straight naphtha 16 and sulfur break point extraction 18 without any additional treatment in any of such flows.
The combination 600 is supplied via line 10 followed by (b) actual product sulfur level 6
00 is (1) light fraction 24, intermediate distillate 26, first heavy distillate 28 and second heavy distillate 3
Increase or decrease the amount of two streams into one or more of the combinations, or integrate zone 401
Distillation of the intermediate distillate in the hydroconverter reactor effluent formed in the hydrogenation treatment device Zone 4
Add or reduce to 30, or (2) increase or decrease the amount of stream 39 with light depressurized gas oil 36 and heavy depressurized gas oil 38, or hydroconverter outflow formed in integrated hydroconverter (401). Diesel decompressed gas oil (not shown) is added or reduced to the heavy oil hydration treatment apparatus 460 to adjust it, and then (c) (1) light distillate 24, intermediate distillate 26, first heavy distillate 28 and / Alternatively, the distillation hydrotreating apparatus zone 4 formed from the second heavy distillate 32 via the line 65.
Flow from 30, and any hydroconverter effluent intermediate distillate, (2) light decompression gas oil 36,
Flow from heavy oil hydrotreating device zone 460 through line 75, formed from heavy decompression gas oil 38 and any hydroconverter effluent decompression gas oil, or (3) actual product 600 sulfur levels for some reason. One or more of the naphtha and other treated liquid effluent 85 from the hydroconversion reaction zone 490, if it is necessary to increase to the target sulfur level 6
Reduce the amount to 00 or (d) (1) Line 6 from Distillation Hydrogenation Device 430
If the above flow through 5, (2) the flow through the line from the heavy oil hydrogenation treatment apparatus 460, or (3) for some reason the actual product 600 sulfur content needs to be reduced below the target sulfur limit level. The amount of processing flow from the hydroconversion reaction zone through line 85 to one or more of the combinations 600 is increased. Through such promotion, for example, fuel supply for sulfur fuels of 500 ppm by weight or less for offshore and onshore gas turbines can be achieved.
Efficient production of multiple sulfur grades is possible, including different ranges for different end-use locations that require different target sulfur contents in the same application.

In a variant using a high sulfur fuel oil having a sulfur content higher than the target sulfur content limit level of the final fuel in combination 600, the high sulfur fuel oil is one of a variety of feedstocks. As a unit, it is supplied to one or more unit operations. Depending on its sulfur content, high fuel oil remains (a) to line 2 to feed line 2 to atmospheric distillation 100 or to line 30 to vacuum distillation 200 and (b) via lines 55, 57 and 317. Light fraction 24, intermediate distillate 26, first heavy distillate 26 or second added to the physical hydroconversion reactor 490, (c) separately or to line 20 to the distillate hydration treatment apparatus 430. In combination with one or more of the heavy distillate 32 feedstock, to the Distillate Hydrotreating Device 430, (d) separately or in combination with one or more of the light decompressed light oil 36 or the heavy decompressed light oil 38. Addition to line 39 to heavy oil hydration treatment apparatus 460 or via line 59 (e) to solvent separation zone 301 to form a fuel combination 600 with an actual sulfur content below the target sulfur content limit. be able to.

In another variant, the combined 600 zone clean fuel is a high fuel oil that can have a higher sulfur content than the target sulfur content limit level, (a) without additional treatment. Flow 10, formed from unstabilized wild naphtha 16 and sulfur break point take-out 18, added depending on the sulfur content of the sulfur fuel oil, (b) wild naphtha and ultra-low sulfur diesel range material. Formed from a stream 65 formed from a distillate hydration treatment device 430 containing, or (c) a heavy oil hydride treatment device 460 with a stream having a stream having (c) naphtha, ultra-low sulfur diesel and a second reduced amount of fuel. Addition to one or more of the stream 75, or (d) the treated effluent 85 from the hydroconversion reactor 85, and the treated streams 65, 7.
The treatment conditions and sulfur content of each of the flows 5 and 85 are such that the actual sulfur content of the fuel 600 is below the target sulfur content limit, if any, the sulfur content of the untreated steam 10. It is formed by adjusting while considering.

In a preferred embodiment in which a high sulfur fuel oil is used in the preparation of the fuel composition 600, after measuring the sulfur content of such a high sulfur fuel oil, the high sulfur fuel oil is used as a part of the feedstocks 55 and 59. As described above, the fuel is supplied to one or more of the solvent separation unit 301 or the residue hydrocarbon reaction zone 490, the adjustment of the hydroconversion conditions of the zone 490 is optimized, and the sulfur content of the treated liquid effluent 85 is adjusted. While determining by the sulfur content of the sulfur fuel oil, a fuel having an actual sulfur content of less than or equal to the target sulfur content limit is formed in the zone 600.

The flow sheets of FIGS. 1, 2, and 3 showing various intermediate individual products are for the purpose of explaining and understanding the major and by-products in the effluent of each unit operation depicted. Is.
The selected variant of separation or processing by each unit operation depends on the optimization of the selected crude oil and feedstock and the intermediate products produced to produce fuels with sulfur below the target specifications. For example, FIG. 3 from the hydrogenation treatment apparatus 430, 460 and the hydrogenation conversion reactor 490.
The respective treatment effluents 65, 75 and 85 shown in are combined within the integrated zone 401 by the use of a common gas-liquid separator (not shown). For example, the ultra-low diesel produced by the hydrogenation treatment device 430 may be the hydrogenation treatment device 460 or the hydrogenation conversion reactor 4.
All hydrotreated materials 65, 75 and 85 are combined and fed into any one stream to the combination zone 600, doubling not separated from the higher sulfur content hydrotreated material produced in 90. As mentioned above, the integrated residue hydrogenation conversion and hydrogenation treatment zone 40
The parameters for adjusting the various processing conditions within 1 are within the technical scope of those skilled in the art of the petroleum refining industry. For example, the conditions for hydroconversion and hydrotreating are adjusted more gently to avoid decomposition if you want to have less light parts in the mixture, and more severely if you want to have less heavy parts. It will be adjusted.

4 and 5 show a combination of one or more components having a novel fuel and a series of light (L), intermediate (M) and / or heavy (H) materials for forming such fuels. Teach the recipe.

FIG. 4 is a plot of both the temperature and density profiles relative to the volume fraction of the reference fuel produced by the method of the invention, and as specified herein (L).
), (M) and (H) are shown.

FIG. 5 shows the temperature and density profiles for the volume fraction of the reference light condensate that can be used as a "barrel top" for the combination. That is, such a condensate has most of the components of naturally occurring (L), with a small amount of naturally occurring (M) and (H) 1. The selected condensate is combined with the additive (H) 2 from another source, such as the "barrel bottom", to form the fuel of the present invention.

FIG. 5 teaches, by way of example, that the inventory material of a refinery's “warehouse” for selecting possible combinations is rather large, but the recipes for the choices taught herein are not. ..

The essential requirement is that if the fuel of the present invention is formed by combining a series of hydrocarbon components, (L), (M) and (H), the resulting combination will be based on 100% by volume of total volume: Is to be decided.
(A) (L)% + (M)% + (H)% = 100%,
(B) If (L)% = (H)% = (100%-(M)%) / 2) and (c) (M)% are zero (zero) or less than 100%, the remaining ( L)% / (H)
% Rate is 0.4 / 1 to 0.6 / 1,
Such a combination has (1) a density at 15 ° C. within 820 to 880 kg / M3, (2).
) The sulfur content is 0.25% by weight or less, and (3) the metal content is 40% by weight or less. As described herein, less sulfur and metals are preferred.

Potential ingredients of (L), (M) and (H) are industry compositions to allow those skilled in the art of essential oils to first know how to select the combination according to the recipe of the present invention. From a reference point of view, it is first summarized and then narrowed down by the limitations of the above and below requirements.

For example, with respect to components in the "(L)" or "light component" range, the particular component may be within a variant found in a locally available refined "warehouse" or otherwise. May require manufacturing if not available locally. As a requirement herein, applicable (L) may include, but not all, components of naphtha and kerosene range material, for example, depending on the sulfur and density requirements for the fuel combination. As used herein and in the claims, (L) is 90% plus end point 190 ° C (374 degrees Fahrenheit) to about 205 ° C (Fahrenheit) below the initial point 38 ° C. (100 degrees Fahrenheit). Means the entire range of naphtha with (401 degrees). (L) is a fractionation, hydrogenation or other treatment step other than (a) purification or partial purification, (b) unpurified, or (c) extraction and any separation of light gas or water. It can be used without doing it. For example, the specific component of (L) or the precursor of (L) is published in the industry-provided system Platts, but the range of substances provided is not based on the sulfur break point. Because the break point is new,
This is because the treatment of materials added to the combination or low sulfur alternatives needs to be considered. Therefore, the description of the components below is a guide on where to refer.

Such applicable components of (L) are also, but not limited to, EIA.
Within the definition specified by (including the conversion from Fahrenheit to Celsius in parentheses) (i) "naphtha: Purification or purification that boils in the range of approximately [50 ° C to 204.5 ° C] (122 to 401 degrees Fahrenheit). "General term for partially refined petroleum fraction", and (ii) "naphtha: generally [50 ° C-204"
.. A purified or partially purified light fraction having a boiling point in the range of 5 ° C.] (122-401 degrees Fahrenheit). Further compounded or mixed with other substances to form high-grade motor gasoline and jet fuel. It is also used as a solvent and petrochemical raw material oil, and is used as a raw material for urban gas production. Accordingly, when carrying out the teachings of the invention in accordance with the requirements taught herein, manufacturing or procuring one or more suitable (L) or light components, or manufacturing such components. Procuring starting materials to do
It is known to those skilled in the art of purification technology. For example, the component (L) preferably has a sulfur content below or near the break point, but the sulfur content is combined (M).
And, if the sulfur content of (H) does not exceed the fuel sulfur limit, it may exceed the break point. It is preferable that the range of the heavier portion of (L) ends at the sulfur break point of the crude oil in which the (L) is produced.

Ingredients to which the "(M)" or "intermediate component" range used herein apply are, as all requirements herein, from about 190 ° C (374 degrees Fahrenheit) to about 205 ° C (Fahrenheit). It means a refined or partially refined petroleum fraction with an initial distillate of (401 ° C.), 90% plus end point from about 385 ° C. (725 ° F.) to 410 ° C. (770 ° F.). However, it is preferable that the range of the lighter portion of (M) begins at the sulfur break point of the crude oil in which the (M) is produced. (M)
Ingredients can include the bottom portion of light tight oil, which is heavier than the naphtha range. In a preferred variant, as another requirement herein, the starting component of (M) has an intermediate distillate combination of hydrocarbons in the kerosene range of about 1/3 to the diesel range of about 2/3, and ASTM.
It has a density in the range of 820-880 kg / M3 at 15 ° C. according to D4052.

It is known to those skilled in the art of purification to manufacture or procure one or more suitable (M) or intermediate components when carrying out the teachings of the invention in accordance with the requirements taught herein. be. In many variants found within the available purification "warehouse", as (M), but not limited to, within the definition specified by the EIA, including the conversion from Hua to Celsius in parentheses. ) (I) "Intermediate Distillate: General Classification of Refined Petroleum Products Containing Distilled Fuel Oil and Kerosene", boiling below 385 ° C (725 ° C), (ii) "Kerosene: Space Heater, Cooking Light petroleum distillation and kerosene used for stoves and water heaters and as a light source when burning with a core lamp have a 10% recovery point maximum distillation temperature [204.4 ° C] (401 degrees Celsius) and an end point [300 degrees]. ° C] (572 degrees Celsius) and minimum ignition point [37.8 ° C] (100 degrees Celsius). Two grades No. 1-K and No. 2- certified by ASTN standard D3699.
K and No. 1 Includes other grades of kerosene, called range oils or stove oils, which have similar properties to fuel oils ", (iii)" Light oils: generally [205 ° C-343.8 ° C] (
A heavier liquid petroleum distillate than naphtha that boils in the range of 401-650 degrees Fahrenheit "and (iv
) The (iv) portion of "heavy light oil: a petroleum distillate that boils at approximately 343.8 ° C to 537.8 ° C (651 to 1000 ° F)" that boils below 385 ° C (725 ° F). It is required that (M) contains only the portion that boils at 385 ° C. (725 ° C.) or lower. (M) is also a material within the EIA definition (v) "kerosene jet fuel", (vi) ".
No. 1 Distillate ”, (vii)“ No. 1 Diesel Fuel ”, (viii)“ No. 2 Distillate ”, (ix)“ No. 2 Diesel Fuel ”, (x)“ No. 2 Fuel Oil ”, ( xi) "
Distilled fuel oil ”and (xii) No. if possible. 4 Fuel or No. 4 All of the above, including some of the diesel fuel, are required to boil at about 385 ° C (725 ° F) or lower. The EIA broadly includes diesel fuels as "diesel fuels: formulations having residual oils as fuels consisting of distillations obtained in petroleum refining operations or mixtures of such distillations with residual oils used in automobiles. Diesel fuel has a higher boiling point and specific gravity than petroleum. " Thus, since the residual oil is within a substance defined as diesel, whether a diesel is (M) or (H), based on the factors taught by the present invention by those skilled in the art of essential oils. Please be evaluated. EIA says "High Sulfur Diesel (H)
SD) Fuels: Many diesels defined as "diesel fuels containing more than 500 ppm sulfur" fall under (M) or (H) according to other requirements of the invention, as further described herein. do. However, as defined by the EIA, "Low Sulfur Diesel (LSD) Fuel: 1
"Diesel fuel containing sulfur exceeding 5 ppm but not more than 500 ppm" and "Ultra-low sulfur diesel (ULSD) fuel: Diesel fuel containing up to 15 ppm sulfur" are (M).
), But as further described herein, according to the other requirements of the invention, (H).
Can be applicable to.

According to the other requirements described herein, the required attribute of the (M) component range is 8 at 15 ° C.
To be able to form part of the combinations of the invention having a combination density of 20-880 kg / M3, the (M) standard (often referred to as bulk) density for such a range is It should be 820 kg / M3 to 880 kg / M3 at 15 ° C. That is, even if the individual components of (M) are outside the range, the aggregate of (M) is 82 at 15 ° C.
It corresponds to 0 to 880 kg / M3.

In the modified example, the (M) component range has a higher sulfur content than the pre-treatment break point, such as the hydrogenation treatment described herein for the removal of sulfur. However, except in limited cases where the (M) component may be above the break point, the treated (M) such as hydrogenation treatment equipment effluent is processed such as hydrogenation converter effluent. After treatment, the sulfur content when combined with (H) is adjusted so that the combination of (L), (M) and (H), both of which are combined with (L), does not exceed the fuel sulfur limit. (M) Sulfur content should be lower than the break point. Higher levels of the selected break point allow the maximum amount of material in (L) to bypass downstream treatments such as hydrogenation treatments if used for sulfur removal, hydrogenation costs and other Reduce operating costs. In one variant, (M) is hydrogenated to produce a very low sulfur content in the range of about 10 ppm by weight and a very low or substantially metal free effluent. (M)
Specific hydrogenated materials of various grades that can be selected for use as components or precursors of are published in Platts, a well-known industry-provided system. ((
If M) is absent or not added, then the boundary between (L) and (H) shall meet the requirement of (M).

The components of "(H)" or "heavy constituents" used herein are the first to be about 385 ° C (725 ° F) to about 410 ° C (770 ° F) as a requirement herein. Fahrenheit, about 815
It means a refined or partially refined petroleum fraction having an end point below ° C (1499 degrees Fahrenheit). Such (H) endpoints are attributes of (H) components that can be known by acquisition surveys or manufacturing tests. In one variant, the (H) endpoint is the highest boiling point of the components of the stream that are recovered from the solvent separation, subsequently treated by a hydrogenation or hydrogenation conversion reactor, recovered and combined to form the fuel. It is set according to the raw material oil such as and / or the processing conditions.

(H) One essential attribute of the component range is sulfur and certain heavy asphaltene and metals during production, eg, by treatment by solvent separation and / or hydrogenation conversion and / or hydrogenation as described above. The proper amount of ingredients processed to reduce the presence of, or (
Another processing step that reduces sulfur and metal to levels that can be added to the combination of L), (M) and (H) and meets the sulfur and metal specifications of the fuel of the present invention. Another essential attribute of the (H) range component is (H) range density and contribution to the final fuel combination, and the density of the fuel combination at 15 ° C. according to other requirements described herein. Is 820Kg / M3-880K
It is to enable the formation of a portion of the combination of (L), (M) and (H) of the present invention, which is g / M3.

Therefore, when the teachings of the present invention are carried out in accordance with the requirements described herein, (H)
Alternatively, the manufacture or procurement of one or more suitable components of a heavy component, or the feedstock and method of producing it, are known to those skilled in the art of essential oils. Available purification "
In many variants found in the "warehouse", the starting material for the component of (H) is, but not limited to, within the definition specified by the EIA (i) (iii) "heavy gas oil". :
A portion of a petroleum distillate that boils at 343.8 ° C to 537.8 ° C (651 ° C to 1000 ° F) above about 385 ° C (725 ° F) is mentioned, including 385 ° C (725 ° F). It is required that only the portion boiling above) is included in (H). (H) is also about 3
"Heavy gas oil: a petroleum distillate that boils in the range of approximately 651 to 1000 degrees Fahrenheit" with an initial distillate of 85 ° C (725 degrees Fahrenheit), ASTN standards D396 and D975 and federal standards VV-F.
(Ii) Residual fuel oil according to -815C: No. remaining after distillation removal of distilled fuel oil and light hydrocarbons by refinery operation. 5 and No. 6 Includes a general classification of heavy oils known as fuel oils. No. Reference numeral 5 is a medium-viscosity residual fuel oil, also known as Navy Special, which is a military standard MIL-F-85 including revision 2 (NATO Symbol F-770).
Defined in 9E, used by government agencies and steam-powered vessels at coastal power plants. No.
6 Fuel oil contains Bunker C fuel oil and is used for power generation, room heating, ship bunker ring and various industrial purposes, and (ii) EIA defines "No. 6 residual fuel oil".

FIG. 4 shows an embodiment of the composition of the fuel of the present invention produced by the method of the present invention.

FIG. 4 shows two profiles for volume fraction, temperature profile 602 and density profile 604, for the reference crude oil processed according to the present invention. That is, in FIG. 4, in both the upper chart and the lower chart, the x-axis 610 shows the volume fraction of crude oil.
The y-axis 612 of the top chart shows the boiling points in degrees Celsius of the various extracts with the temperature profile curve 602 as data points. The y-axis 614 of the lower chart of FIG. 4 shows the density data of the reference crude oil on which the density profile curve 604 is drawn.

Two vertical dotted lines LM606 and MH6 in both the upper and lower charts of FIG.
08 is drawn intersecting the temperature profile 602 and density profile 604 curves. The vertical lines LM602 and MH604 are depicted as volume fractions of the reference crude oil in the selected yield fractions (L) range 622 and (M) range 624. In FIG. 4, LM6
The intersection of 06 is 205 ° C and the intersection of MH608 is 385 ° C, determining the respective ranges of (L) 622 and (M) 624. For crude oil that is lighter or heavier than the reference crude oil, shift the line to the right or left.

Point 609 indicates the end point of the range (H) having reduced pressure gas oil cut up to 565 ° C. and de-asphalated oil from the reduced pressure residue remaining below 565 ° C. It is understood that the temperature at point 609 depends on the rise in deasphalted oil and no 100% by volume representing the pitch is shown from point 609. The temperature point 611 is a treated (H) heavy decompression gas oil boundary point portion used for the combination and has (H) 626 moieties from points 611 to 609, which are deasphalized oils. The corresponding density points are shown in FIG. 4 as 615 for the entire range of untreated crude oil. 613 is a straight line passing through the bulk densities of (L), (M), and (H) in the treated crude oil.

Therefore, the highest boiling end point in the (L) range 622 and the initial retention point in the (M) range 624 share a common vertical line LM606. The highest boiling end point in (M) range 624 and the initial boiling point in (L) range 626 share a common vertical line MH608. (H) The actual end point 609 of the precursor to range 626 is shown in other embodiments of the invention and, as described in the definition of (H), a particular heavy asphaltene and other complex hydrocarbons. A cutting point for removing and substantially removing metals, leaving a very low amount of sulfur (H) that contributes to the final fuel.

FIG. 4 further comprises forming a fuel composition that assumes the fuel of the invention produced by the method of the invention, which is disclosed herein with respect to the fuel produced by the method of the invention.
It shows how to combine the components within L), (M) and (H). In the outline as an example of modification, the components are investigated, the density is plotted against the volume fraction, and the line 640 with the minimum density of 820 Kg / M3 required at 15 ° C and the line with the maximum density of 880 Kg / M3 at 15 ° C. 64
Find the center point of the (M) range between 2 and 2. Center point 630 (density pivot defined later)
Is the intersection of density vs. volume in the middle of the (M) range, ± 10% by volume or very little or non-existent (M) range component, where (L) ends,
This is the attribution point where (H) begins. The black square 630 in the center is the (M) range bulk density center point.
631 and 633 are bulk density center points in the (L) range and the (H) range, respectively.

When processing crude oil lighter than the reference crude oil by the method of the present invention to produce a fuel, the vertical line LM
606 and MH608 are shifted to the right, and in the range (L) 622, (M) 624, (H) 626, the volume of the lighter component (L) range 622 is increased and the volume of the range (H) 626 is decreased. Means that. The density pivot 630 moves slightly and the fuel density decreases, but remains within the density fulcrum 632 (defined below). When heavy oil heavier than the reference crude oil is processed by the method of the present invention to produce fuel, the opposite occurs. That is, the vertical lines LM626 and MH6.
28 is shifted to the left, which means that the volume of the component (H) is increased and the volume of the range (L) is decreased. The fuel density increases, but the point of the fuel combination density pivot 630 is line 6.
It remains in the 820-880 kg / M3 density zone between 40 and 642. Examples of such lighter and heavier feedstocks are 820-880 kg / M3 for combined fuels.
Sufficient (L), along with the aggregate required density to balance each range of (L) and (H), to supply fuel with bulk density within to the fuel combination density zone between lines 640 and 642.
And (H) components (as well as (M) components, if any) are required.

Therefore, very light feedstocks such as lighttight oils and condensates, which are mainly in the (L) range, have a final product bulk density within the density fulcrum and a fuel combination density zone of 820-880 kg / M3. It does not have a sufficient amount of heavy substance (M) or (H) to act as a single substance that fuels it.

As used herein and in the claims, (a) the term "density fulcrum" has a bulk density of 820-880 KG / M3 at 15 ° C. and a volume of approximately ± 10% at the density pivot. Means the center located at or near the density pivot (defined below) within the fractional range. For illustration purposes, but not limiting, nominally 48% by volume is measured within 43-53% by volume and nominally 85% by volume is measured within 80-90% by volume. (B) The term "density pivot" means the center point of the density fulcrum, and when the components (L) and (H) of the same volume are combined, they are balanced with or without the component (M). Density can be achieved. All of the cited lines are at one end of the density curve 604, as both ends are within the 820-880 kg / M3 fuel combination density zone between lines 640 and 642 and the bulk density of the combination is at point 630. Whether the range is upward or downward, it passes through the required bulk density fulcrum, which serves as an essential guide for the fuel formulation.

Observing the density profile 604 shown in FIG. 4, the (bulk) density extends almost linearly and the variation is small, but it can be tilted out of the parallel zone range of the density fulcrum 632 and swivel near the center 630 of the density fulcrum. I understand. As shown, the density range is 882 at 15 ° C.
At ~ 880 kg / M3, substantially equal volumes of (L) and (H) lift and rotate wire 604 for the entire formulation and bulk between 640 and 642 of the clean fuel of the invention. It falls within the density range.

When the density of the final combination fuel product is lower than the minimum density of the density fulcrum 632 (eg, low density requirement less than about 820), the calorific value is reduced and the fuel consumption is required to achieve the same energy effect. Need to increase. If the density of the final product exceeds the maximum density of the density fulcrum 632 (eg, top density requirements above about 880), problems arise with respect to engine fuel feedstocks, handling systems, and other end use.

If all other conditions are met, then (M) without disturbing the balance of the density fulcrum.
) Can be substantially reduced or eliminated, and it is surprising that it is still possible to form a satisfactory fuel of (L) and (H). This allows the top and bottom of a particular barrel combination to recover the diesel range from (M) and still form a satisfactory fuel with the remaining (L) and (H).

FIG. 5 shows, for example, the method of the invention using light tight oil as (L) range component “top of barrel” and (H) other component as “bottom of barrel”. It shows how to form a fuel composition assuming the fuel to be produced.

In FIG. 5, the condensate is used as the reference light tight oil type material shown in the chart above FIG. This is an example of a light "barrel top" material with a 53 ° API, about 69% by volume (L) range 722 ending at line 706, and only 28% by volume (M) ending at line 708. ) 724 and has an atmospheric residual bottom of about 3% by volume as part of (H) 1 shown as 726 contributing to the final combination. Yield curves 702 of the above condensate reference material at various temperatures 712 plotted against volume fraction 710 are shown in the chart of FIG. As mentioned above, by this reference material analysis, as a general approximation, about 69% by volume (L) range 722, 28% by volume (M) range 724 and about 3% by volume (H) 1 range. Interpreted as 726. Since the bottom is a relatively light gas oil range material with very little heavy residue,
The end point 711 is 100% by volume. If the density fulcrum is shown for reference only (not including the added (H) 2 shown only in the chart below FIG. 5), it is about 85% of the volume fraction of the original reference without the added (H) 2. Appears on the right side of the area. Therefore, at least additional (M) range components, preferably (M) + ( The H) component, or more preferably the (H) range material, is required for the combination, along with the component of (M).

In this example shown in the chart below FIG. 5, about 69% by volume (L) 722, 28% by volume.
(M) 724 and (H) 2 non-produced as a full range effluent by other sources, eg, hydrogenation conversion, in each barrel of this reference condensate naturally occurring as H1 range 726 of 3% by volume. 0.69 barrels of condensate 727 are added. The black square 730 in the center is the (M) range bulk density center point, and 731 and 733 are the (L) range and the entire (H) range bulk density center points, respectively. The combination with addition (H) 2 is 1.69 barrels ((L) + (M) + (H) 1 +
As (H) 2, the assumed compounded clean fuel of the present invention (100% by volume shown in the chart at the bottom of FIG. 5) is formed, and the fuel is 820, which is a requirement range for a fuel product API of about 25 to 28.
It has a density of ~ 880 kg / M3, an example of which is shown in Table 1.

（配合燃料は、低硫黄及び金属仕様を満たす）

(The compound fuel meets low sulfur and metal specifications)

In yet another modification of the invention, the amount of M in the combination is reduced to near zero.
This is due to a shortage of diesel and other materials in the (M) range, which is sought after for ultra-low sulfur diesel route requirements and high demand for low sulfur offshore and gas turbine applications. In this variant, a combination of substantially equal (L) and (H) moieties is made that contains little or no (M) for the formation of the blended fuel. "Heavier condensate"
Or the choice of light tight oil results in more atmospheric residue and, in some cases,
Some gas oil range materials shift the vertical line (LM) to the left and the density fulcrum increases as the density increases due to the contribution of the heavier light tight oil.

In one embodiment to which the above applies, the inventors are composed of (L), (M) and (H).
Provided is a new compound fuel having one or a combination of a plurality of components. Here, each amount with respect to 100% by volume of the total amount to be combined is determined as follows. (A) (
L)% + (M)% + (H)% = 100%, (b) (L)% = (H)% = (100%-(M)
)%) / 2), and (c) (M)% are zero or less than 100%, the remaining (
The L)% / (H)% ratio is 0.4 / 1 to 0.6 / 1, and the combination is (1) a density of 820 to 880 kg / M3 at 15 ° C., and (2) 0.25% by weight. The following sulfur content, (3) 40
A fuel having a total metal content of less than ppm by weight. In one modification, sulfur is reduced to 0.1% by weight or less and metal is reduced to 25% by weight or less. In one variant, 10% -90%
(M) is present, and the (L) / (H) ratio of the remaining portion is 0.4 / 1 to 0.6 / 1. In another modification, the existing (M) is 20% to 80%, and the remaining (L) / (H) ratio is 0.
It is 4/1 to 0.6 / 1. In yet another variant, 30% to 70% (M) is present,
The (L) / (H) ratio of the remaining portion is 0.4 / 1 to 0.6 / 1. In a simplified embodiment, (M) is in the range of 30% to 70% by volume and the rest is substantially having an (L) / (H) ratio of 0.9 / 1/1 to 1 / 0.9. Consists of (L) and (H) parts equal to. In other embodiments, (M) is in the range of 40% by volume to 60% by volume and has a density of 820 to 60% by volume at 15 ° C.
880 kg / M3, sulfur is 0.25 wt% or less, and metal is 40 wt ppm or less.

Therefore, we have set a density at 15 ° C. at 820-880 kg / M3 or less and are precursors with hydrocarbons derived from a combination of light tight oil and hydroconverted high sulfur fuel oil. Alternatively, they have found that by utilizing the production of components, fuels with a very low sulfur content of 0.1% by weight can be blended or produced. The fuel has an initial boiling point which is the lowest boiling point of any distillate of the oil under atmospheric distillation conditions, and the highest boiling point of the residual portion of the high sulfur fuel oil which is soluble in a solvent suitable for solvent separation. Has a boiling point. For example, when implementing the present invention, if heptane is used as a solvent for acquisition metrics for obtaining combined components or as a solvent for manufacturing using the solvent separator in the manufacturing process of the present invention. The maximum boiling end point in the combination, whether treated or untreated, is higher than when pentane is selected as the metric or solvent for production.

The present inventors have selected (L) + (M) + (H) precursors for envisioning a wide range of hydrocarbon compounded fuel combinations useful as clean turbine fuels in the above-mentioned methods of the present disclosure. We found that it could be used for processing. The turbine fuel has the following characteristics. (A)
0.05% by weight (500% by weight ppm) to 0.1% by weight (1000) according to ISO8754
Sulfur (by weight ppm), (b) 820-880K at 15 ° C. by ASTM D4052
Density of g / M3, (c) 25 ppm by weight or less, preferably 1 according to ISO 14597
All metals less than 0 ppm by weight, more preferably less than 1 ppm by weight, (d) 43.81-4
HHV of 5.15 MJ / kg and (e) LHV of 41.06 to 42.33 MJ / kg.
The flash point varies based on the lowest flash point component of the combination. We have found variants with the following additional expected properties: (A) 50 ° C. of less than 10 mm ² / s
(In ISO 3104, 1 mm ² / s = 1 cSt), (b) ISO 103
The carbon residue by 70 is 0.32 to 1.5, (c) the real gum by ISO 6246 is less than 5, and (d) the oxidation stability by ASTM D2272 is about 0.5.
(E) The acid value according to ASTM D664 is 0.05 mgKOH / g. For use as a marine fuel, refer to the test or calculation method specified in ISO 2817-10.

Accordingly, the present invention is widely applicable to the production of low level fuels with reduced sulfur and other contaminants, and the use of such fuels. Certain features may be modified without departing from the spirit or scope of the invention. Therefore, the present invention is not limited to the above-mentioned specific embodiment or embodiment, but is defined only in the appended claims or equivalents.

Claims (3)

Light tight oils (1) and (ii) light tight oils having a sulfur content in the range of zero (0)% to 0.2% by weight and (ii) API (degrees) densities in the range of 38 to 57 degrees. b) The feedstock oil is the liquid effluent (411) hydroconverted by the residue hydroconversion (401), and the feedstock oil is (i) high sulfur fuel oil (41) and (ii) said. Obtained by treating the unhydrogenated conversion oil (409) from the residue hydrogenation conversion reactor (401) that was not hydroconverted in the residue hydrogenation conversion reactor (401) by solvent separation (301). Recycling (311) of the soluble oil effluent from the solvent separation (301) into the residue hydroconversion reactor (401) is included, but the unhydrogenated conversion oil (409) is solvent-separated (49). It does not contain the insoluble unconverted oil (351) from the solvent separation (301) obtained by the treatment in 301), where the residue hydroconversion reactor (401) of the soluble oil effluent. Recycling to (311) is a hydroconverted liquid effluent (411) soluble in propane, butane, pentane, heptane or other paraffinic solvents.
A fuel (600) containing the liquid hydrocarbon component of
The fuel (600) comprises the entire range of hydrocarbons from the lowest boiling point component of the light tight oil to the highest boiling point component of the hydrogenated liquid effluent (411).
A fuel (600) characterized by that. The lowest boiling point component of the fuel is
It is a liquid hydrocarbon component that is the initial distillate of the liquefied petroleum gas range component in the light tight oil.
The fuel according to claim 1. The highest boiling point component is the highest boiling point component of (311) recycling of the soluble oil effluent soluble in propane, butane, pentane, heptane or other paraffinic solvents into the residue hydrogenation conversion reactor (401). There, said recycling (311) is followed by the first residual hydrogenation conversion (401) with hydrogen in the presence of a catalyst, followed by further (x) hydrogenation conversion only, or (y) hydrogenation conversion and then next. Hydrogenated to
The fuel according to claim 1.

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