fuel

Abstract

To provide crude oil-derived fuel that is friendly to fuel costs and the environment. All ISO RMA10 (ISO2817-10) specifications except for flash point A fuel that meets or exceeds the initial boiling point of naphtha and a solvent suitable for solvent separation. The highest boiling point of the hydrocarbons soluble in the (a) 0.50% m / m (weight %) or less, preferably 0.05 to 0.20 m / m ( % by weight of sulfur, (b) 5.0 mg / Kg (ppm by weight) or less, preferably 1. 0 mg / Kg (1.0 ppm by weight) or less of metals, (c) flash point less than 60°C without treatment The fuel has a flash point.

Description

Technical Field

[0001] The present invention relates to a method and an apparatus for producing a fuel having a very low sulfur content from crude oil, refined residual oil, and other contaminated liquid feeds. The fuel having a very low sulfur content produced by the present invention is particularly cost-effective for use on board large marine transport vessels and for large onshore combustion gas turbines on land.

Background Art

[0002] The present invention targets the fact that when "offshore" ships, which have long been known but have hitherto unsolved major environmental problems, burn inexpensive low-grade heavy bunker oil and other heavy residues containing a lot of sulfur, nitrogen and metals, oxides of sulfur, nitrogen and metals are carried into the natural environment. Such emissions are on a global scale and spread regardless of national geographical boundaries.

[0003] According to various third-party reports, certain global emissions resulting from burning heavy fuels for such waterborne transportation are many times higher than the combined emissions of all vehicles burning gasoline and all diesel vehicles on land worldwide. Such combustion at sea emits SOx, NOx, CO <o000026> soot and harmful metals. Land vehicles include automobiles,

[0004] The introduction of certain important regulations mandating the use of cleaner combustion marine fuels for ships is one such example. It is conditional on a sufficient supply of usable eel fuel, both technically and economically. Solutions are still needed to avoid ordering things that are neither possible nor practical.

[0005] For example, the International Maritime Organization (IMO), a division of the United Nations, issues rules concerning international shipping. The IMO is taking action, while acknowledging the technical limitations, to tighten the sulfur restrictions on marine fuels. Emissions have been reduced by doing so. The IMO has been working to reduce emissions from the open ocean since 2011 (for example) For example, fuel outside of emission control areas (ECAs), including 200 nautical miles from the coasts of the United States, Europe, and other countries. Ship fuel burned by incineration must have a sulfur content not exceeding 3.50% m / m. This is what is required of the fuel. In 2015, the IMO amended the regulations, and within the ECA For commercial vessels, the sulfur content of marine fuel was generally restricted to less than 0.1%.

[0006] However, the IMO has again significantly lowered the sulfur limit in the open ocean for 2020 and beyond. , set at 0.50 m / m. However, the IMO stated that such aggressive reductions in 2020 The review of the availability of required fuel oil, scheduled to be completed by 2018, is titled "Review of the availability of required fuel oil, scheduled to be completed by 2018." It depends on the "results" and if the required fuel is unavailable, such reductions will be 20 This suggests the possibility of a postponement to 2025. Regarding regulations on air pollution in the marine industry, See Annex VI of the International Convention for the Prevention of Pollution from Ships (MARPOL).

[0007] Therefore, the lack of availability of low-sulfur marine fuel and the need to achieve such supply Regarding the lack of technical expertise, there is a realistic and significant possibility that problems will arise. For example, 201 A five-year industry publication stated that "fuel emissions are below the

[2014] levels required in emission control zones." Plans are being made to reduce the permissible sulfur content inside... but this is not possible with current technology. It was stated that this would take many years because the costs would be exorbitant for many shipping companies. Such publications also have the potential for "extra costs and mechanical problems." Therefore, these regulations will be continuously re-evaluated, and a phased approach will be adopted for their implementation. This means that "many marine engines use much leaner fuel oil than heavy fuel oil, and the heavy fuel oil is less moist." This is because it is not designed to handle low-sulfur diesel fuel, which does not have lubricating properties. Each company, Cooling the fuel to increase its viscosity, injecting additional lubricants into specific parts of the engine, etc. They stated, "We are taking various workarounds and striving to make it work" (Non-Patent Document 1).

[0008] Another example is the 2015 IMO regulation that required designated commercial vessels within the ECA to... Regarding this, the sulfur content of marine fuels has been reduced to a maximum of 0.1% sulfur. Before entering, the ship was using high-sulfur heavy bunker fuel oil, which is burned in the open ocean and is inexpensive but contains a lot of sulfur. Therefore, it will have to be changed to an expensive low-sulfur fuel similar to highway diesel fuel. From January 1, 2015, the amount of fuel sulfur in the ECA will be 1.00% m / m (July 1, 2010) The subsequent reduction to 0.10 m / m has created supply and pricing challenges in the market. It was done. The manufacture and supply of marine fuels to comply with IMO-related regulations is for highways and Competing with the demand for distilled fuels for other onshore diesel applications, and with available preferred raw materials The flow, and existing refining equipment and feed supply networks, for diesel and other low-sulfur distillates. Keep it away from use. Also, other technical problems occur on board.

[0009] Regarding the 2015 IMO reduction of sulfur content in ECAs, the US Coast Guard has stated that "ships using higher sulfur-containing fuels must switch to ultra-low sulfur (ULS) fuel oil to meet the new regulations." Ships using higher sulfur-containing fuels must switch to ultra-low sulfur (ULS) fuel oil to meet the new regulations. Ships must use ULS fuel oil at all times during voyages to and from their home countries, while in dock, and within ECAs. Therefore, ships using high sulfur-containing fuel oil need to develop and implement switching procedures to switch between residual fuel and distillate fuel before entering an ECA. The Coast Guard further warns that "there are many other important technical issues related to the use of ultra-low sulfur fuel oil and fuel oil switching mentioned in documents prepared by classification societies, insurance companies, engine manufacturers, and industry groups," and that "the energy content per unit volume of ULS fuel oil may be different from that of residual fuel, such as when existing throttle settings do not provide the desired propeller shaft RPM or generator load." (Non-Patent Document 2) As a stark reality, refineries are costly, and even relatively minor changes to fuel products or manufacturing equipment and the addition of unit operations require significant capital investment. In 2003, an evaluation study of refineries in Europe was conducted in view of the need to reduce pollutants in ship fuels and the requirements and capabilities for producing such fuels. For example, see Non-Patent Document 3. Regarding the 2015 IMO reduction of sulfur content in ECAs, the US Coast Guard has stated that "ships using higher sulfur-containing fuels must switch to ultra-low sulfur (ULS) fuel oil to meet the new regulations." Ships using higher sulfur-containing fuels must switch to ultra-low sulfur (ULS) fuel oil to meet the new regulations. Ships must use ULS fuel oil at all times during voyages to and from their home countries, while in dock, and within ECAs.

[0010] As a stark reality, refineries are costly, and even relatively minor changes to fuel products or manufacturing equipment and the addition of unit operations require significant capital investment. In 2003, an evaluation study of refineries in Europe was conducted in view of the need to reduce pollutants in ship fuels and the requirements and capabilities for producing such fuels. For example, see Non-Patent Document 3. Regarding the 2015 IMO reduction of sulfur content in ECAs, the US Coast Guard has stated that "ships using higher sulfur-containing fuels must switch to ultra-low sulfur (ULS) fuel oil to meet the new regulations." Ships using higher sulfur-containing fuels must switch to ultra-low sulfur (ULS) fuel oil to meet the new regulations.

[0011] Such reports are helpful when many countries try to produce the necessary amount of marine fuel. In addition to increased strikes and decreased refinery utilization efficiency, in some cases major ports If there are no local facilities nearby to manufacture and supply such marine fuel, Furthermore, it raises major challenges such as the lack of technology and equipment to produce such fuels. Ta.

[0012] The cited report identified only three options: "Recombination options" (heavy fuel Blending oil with low-sulfur fuel is the lowest cost option for manufacturing low-sulfur bunkers. It was considered, but because it does not incur significant costs but can only process a minimum amount of material, it is not suitable. It wasn't a choice. This option involves different types of heavy fuels currently produced in European refineries. While the logistics for recombining the categories were relatively low-cost, it failed in terms of volume.

[0013] A second option, which is more expensive, is reported to contain 1.8% sulfur. High-sulfur crude oil such as Lavian Light is converted to low-sulfur crude oil, for example, 0.14% by weight of sulfur. By replacing it with African crude oil such as Bonnie Light, which has been reported to contain... This involves processing low-sulfur crude oil. The estimated incremental cost of offshore bunkers incurred by this option. It was deemed an excessive burden for the reasons stated in the report.

[0014] This old report finally describes the use of vacuum residue desulfurization (VRDS) for low-sulfur marine grade fuels. This presents a third and most expensive option for production, according to the report's conclusions. However, in contrast to the degree of desulfurization required for gasoline or diesel, the bottom of the barrel The hydrogenation treatment (residual oil desulfurization) of the department is combined with some form of conversion from residual oil to a lighter product. Unless otherwise specified, the process is what the refiner is currently planning to implement. It is important to realize that it is not the same thing. Nevertheless, VRDS is decreasing If pursued solely for the purpose of desulfurizing the pressure residue, the cost of this option is This is about twice as expensive as the second option, and therefore even more unacceptable.

[0015] Prior art has been developed to meet IMO requirements, allowing ship operators to use high-sulfur content for marine applications. It is possible to load both fuel oil containing sulfur and low-sulfur content fuel oil for use within the ECA, but this selection The selection is based on engine technology, lubrication, and differences in optimal operation and fuel switching mechanisms. Regarding the potential needs that may arise with a fuel injection system, problems may be encountered. The ship's operator must maintain the highest level of performance, which involves relatively large, expensive, and complex post-combustion exhaust systems. A smoke treatment system can be added. In some cases, liquefied natural gas (LNG) can be used for marine purposes. It could be used as fuel. In that case, for example, an LNG carrier would use it as fuel. While it is possible to choose to use "evaporative gases," this LNG engine concept is entirely... To expand to cargo ships, it is necessary to have a wide range of very expensive LNG refueling stations. Ports in rural areas that do not have local natural gas production and supply facilities or liquefaction facilities will incur additional costs. This will incur costs. However, in all cases, if you use LNG instead of liquid... Leaks due to ventilation during refueling or incomplete combustion, or during operation and maintenance A real risk arises: methane release. Such methane releases cause methane to be released into the environment. It is thought by some to have several times the impact of sulfur dioxide as a greenhouse gas on the environment. Therefore, this is a cause for concern. From a similar perspective, emission reductions in marine applications are also a concern during shipping. Alternatively, by burning natural gas while docked at a port equipped with a gas supply docking station. Therefore, some argue that it can be achieved. However, from one technical standpoint, natural gas It has a methane leak problem, and although burning natural gas reduces CO2 emissions, It's not because it emits less CO2, but rather, when compared to LNG, natural gas is used. To avoid CO2 emissions generated during the liquefaction process and to ignite the power plants supplying power to ships docked in port... This is because it reduces CO2 emissions during coal recovery and exchange. LNG is used as fuel for ships. Alternatively, development activities that promote the replacement of natural gas with liquid gas should be considered, globally. When gas infrastructure is lacking and new refueling infrastructure is needed, practical cost-effectiveness It does not provide highly effective offshore solutions. The gas supply infrastructure is located locally. Ports in countries where production and supply are not already underway face significant challenges in terms of equipment and capital investment.

[0016] Patent document 8 (2009) by Lenglet describes the production of two non-asphaltenic oils. Pre-production method for crude oil and pre-distillation, vacuum distillation, and solvent de-asphaltene distillation of asphaltene oil. For the production of multiple products having altification, hydrogenation, hydrocracking, and residual hydrogenation. This is described. Non-patent document 4 describes how to remove sulfur by hydrogenation and produce highly active Ni / M Unit design for producing products with sulfur content below 8 ppm using catalysts. The selection of the medium, hydrogen consumption, and other operating conditions are described. Non-Patent Document 5, page 6, Advanced Purification The technology, Catalagram's specific edition publication No. 113 / 2013, also includes highly active CoM. Using a catalyst, sterically hindrance-free sulfur is removed, and remaining sterically hindrance-removed sulfur is removed by a highly active NiMo catalyst. The description includes a hydrogenation treatment to remove yellow pigment and reduce its concentration to 10 ppm.

[0017] However, effective fuel production technologies face a shortage of low-cost, large-volume supply of ultra-low-sulfur marine fuel. A gap has long existed that gives rise to this problem. The need to fill this gap remains.

[0018] The International Energy Agency's (EIA) Petroleum Industry and Markets Division is responsible for the production of petroleum used in fuel production. Official documents describing the process and equipment configuration, and the configuration, products, and margins of conventional refineries. This document is published. Terms used herein are defined or expressly changed as otherwise provided. Unless otherwise specified, it has the meaning set forth in Non-Patent Document 4 and is used herein for all purposes. It is incorporated. EIA publications process crude oil and use each barrel of crude oil feedstock in different ways. This paper defines and discusses configurations for splitting a process into multiple products for intermediate or downstream processing.

[0019] The genetics of traditional refinery development and growth are somewhat rooted in the evolution of societal product demand. It is a basic kerosene grade distillate for lighting, and gasoline for automobiles and and diesel, then aviation-grade fuel, and further raw materials for many downstream chemical applications, etc. The development has progressed to multiple products. All of the refinery's technological development is for multiple products with various end uses. While maintaining production, typically, the amount obtained from each barrel of crude oil for a particular market segment To maximize the amount of the given fraction, or to adapt the various flows of the refinery to the downstream chemical products. It appears that they were guided to adapt to either one of these conditions and evolved gradually.

[0020] Thus, atmospheric pressure crude oil and / or vacuum distillation units, solvent separation, hydrogenation, gas In prior art refinery designs using chemical and many other unit operations, each of the crude oil supply raw materials is used The reel is divided into multiple products with different specifications for different applications or downstream processes.

[0021] In conventional refining, the raw material is separated into different unit effluents, and then the effluents are separated. Putting everything back together is counterintuitive. For example, the above EI Reference A is conventional or typical atmospheric pressure crude oil distillation, vacuum distillation, and fuel solvent deasphalt. This document defines and describes hydrogenation, catalytic hydrogenation, and integrated gasification combined cycle technologies, but the original Regarding the configuration of the process that converts virtually all of the oil supply raw materials into a single liquid fuel: It doesn't explain that.

[0022] Within the scope of conventional refining processes, there are steps such as "upgrading," "topping," or "water." There is a "crude skimming" facility. Regarding crude oil upgraders, the primary purpose is typically, Processing very heavy, viscous, or solid-containing substances versus lightweight, fluid substances. Existing conventional methods to produce the entire range of fuel products, chemical raw materials and / or petroleum coke The goal is to convert it so that it can be reprocessed at a refinery. The upgrader simply does that. Conventional refined sulfur treatment systems are individually designed to process sulfur in order to meet the specifications of their respective downstream products. It is simply a matter of converting heavier crude oil to lighter crude oil for supply to the mill, and sulfur Reduction or removal of metal is not the primary objective of an upgrader. The goal is to reduce the typical metal content. This involves modifying raw materials that have a much higher density compared to low-density crude oil raw materials. Heavy materials are removed or separated from the supplied material, resulting in a modified product material. The density of the material approaches that of crude oil processed by existing conventional refining facility configurations. As for refineries or "mini" refineries, they are often located in remote areas or in locations that take advantage of the opportunity to access crude oil sources. It is located. Topping refineries are typically, in some limited cases, gasoline Naphtha modification for octane enhancement and multiple distillates for producing various products Gasoline production without or with minimal subsequent processing, excluding the hydrogenation process. Instead, each barrel of crude oil raw material targeting naphtha is split into multiple direct distillates. Typical example. The purpose of a typical topping refinery is to produce a wide range of fuel oils such as gasoline, kerosene, diesel, and fuel oil. The goal is to produce readily usable fuel for consumption in the local market. Some desirable If toppings are added in a manner that does not contain any residue, or if the topping product is used, or if residue remains... If things are not dealt with properly, harmful emissions to the environment will increase rather than decrease. Hydrogen skimming refineries transform crude oil into multiple products, similar to topping refineries. It is converted, however, typically consumed by the hydrogenation treatment equipment in diesel production. The amount of heavy naphtha added to the reforming unit, which also generates hydrogen, is limited. Unlike a single product, such as the Ping refinery, which typically produces a wide range of gasoline and lamps, We produce oil, diesel, and fuel oil for local consumption.

[0023] Independent series or parallel hydrogenation reactor zones or integrated hydrogenation reactor zones Various embodiments for adapting the hydrogenation treatment, including having a ne, are in the art. It is publicly known. Cash et al.'s Patent Document 1 and the references cited therein differ. The company discloses an integrated hydrogenation treatment of the supply, in which water from separate hydrogenation zones is used. The element-containing and liquid-containing flows are distributed or combined by the disclosed method. De-asphaltized oil is extracted from the pitch in the solid residue stream, and the de-asphaltized oil is subjected to hydrogenation treatment. Various aspects of using solvent separation for use as a raw material generate multiple product flows. When used for such purposes, it is publicly known in the art. For example, Brierley Patent Document 2 describes propane or other paraphrases such as heptane or pentane. Cracking or decomposition of feed by separation based on solubility in liquid solvents such as ion-based solvents. This document describes solvent deasphaltization for the production of deasphaltized oil, without the use of solvents. It is present. The residual pitch contains high levels of metal and sulfur. De-asphaltized oil This relates to the production of several products, including naphtha, kerosene, diesel, and residual substances. As described in the references, to remove sulfur, nitrogen, carbon and metals It can be subjected to hydrogenation treatment.

[0024] In the global market, offshore or with little or no natural gas resources, power generation In land-based locations using low-sulfur content fuel oil or unrefined crude oil, global environmental problems arise. To address this, large quantities of fuel with low sulfur and nitrogen content and essentially free of metallic contaminants It needs to be available.

[0025] Fuel producers are using a different method than conventional refining, which is used to produce multiple product slates. A design is required. In order to keep costs low, the design is a way to reduce capital investment. Only the equipment necessary to produce large quantities of clean fuel in a highly cost-effective and thermally efficient manner. It must be equipped with the above design. The ratio of each barrel of crude oil for marine fuel Rather than extracting a relatively small amount of the fraction and using the majority of the barrel for other purposes, it is primarily for marine use. The goal should be to produce fuel.

[0026] What the world needs is an economical way for marine applications (British thermal energy (BTU)) Large ratios (in an efficient form to avoid wasting energy, expressed in such a short form) A "game change" that provides solutions to the technical problems of how to produce relatively clean liquid fuels. This is a new, innovative process. Such processes are new basic facilities for LNG. Instead of building a new one, we can use existing liquid marine fuel refueling stations that are spread all over the world (for example, high-sulfur fuel oil (HSFO) can be used for fuel distribution, so the necessary facilities and associated Capital and operating costs will be minimized. Seth also uses liquid BTU in ultra-low sulfur diesel (UL), which is mainly manufactured for automobiles and trucks. There is a need to move in a direction that supports creating it in a way that is more cost-effective compared to SD. Such available diesels are widely available, but there are cost issues, and U Lubrication problems that arise when LSDs are used in many existing marine diesel engines. Therefore, it is not widely used at sea by large maritime carriers. [Prior art documents] [Patent Documents]

[0027] [Patent Document 1] International application PCT / US1999 / 00478 [Patent Document 2] U.S. Patent No. 7,686,941 [Patent Document 3] U.S. Patent No. 8,088,184 [Patent Document 4] U.S. Patent Publication No. 20140221713 [Non-patent literature]

[0028] [Non-Patent Document 1] Josiah Toepfer, U.S. Coast Guard ship inspector / auditor and accident investigator, "Is it true that the 15 biggest ships in the world produce more pollution than all the cars?" - an online article published by Quora. [Non-Patent Document 2] U.S. Coast Guard, U.S. Homeland Security Inspectorate, Compliance Division, "Ultra Low Sulfur Fuel Oil & Compliance with MARPOL Requirements Before Entering and While Operating within Mission Control Areas," March 3, 2015, Safety Recommendation 2-15, Washington, D.C. [Non-Patent Document 3] European Commission Directorate-General for the Environment, "Advice on Marine Fuel: Potential price premium for 0.5% S marine fuel; particular issues facing fuel producers in different parts of the EU; and commentary on marine fuels market," final draft report, contract number ENV.C1 / SER / 2001 / 0063, Order Slip n°C1 / 3 / 2003, October 2003. [Non-Patent Document 4] U.S. Energy Information Administration, "Glossary," October 2016. [Non-Patent Document 5] Wright et al., Lloyd's Register FOBAS, "Marine Distillate Oil Fuels Issues and implications associated with the harmonization of the minimum flashpoint requirement for marine distillate oil fuels with that of other users," authored for the Danish Shipowners' Association, 2012. [Non-Patent Document 6] Rall et al., "Sulfur Compounds in Cru de Oil," Washington, D.C., UNT [Non-Patent Document 7] JPWauquier “Petroleum Refining: Crude Oil.Petroleum Products.Process Flowsheets”, 1995, Institut Francais du Petrole. [Non-Patent Document 8] Ackerson et al., “Revamping Diesel Hy drotreaters For Ultra-Low Sulfur Using IsoTherming Technology” [Non-Patent Document 9] Shiflet et al., "Optimizing Hydroprocessing Catalyst Systems for Hydrocrack ing and Diesel Hydrotreating Applications, Flexibility Through Catalyst", p. 6, A advanced Refining Technologies Catalagr am, Special Edition Issue, No. 113 / 2013 [Overview of the Initiative] [Problems that the invention aims to solve]

[0029] This invention provides a fuel with very low sulfur, nitrogen, and substantially no metals, produced in large quantities at low cost. This enables supply via fuel and fills a gap in effective fuel production technology. This fuel can be used not only for large-scale onshore applications such as combustion gas turbines for power generation, but also for offshore applications. This is also particularly useful. The term "essentially non-metallic" as used herein and in the claims. The term "zero metal" refers to metals that are between zero and less than 100 weight ppb (parts per billion). Metal content within a range that is difficult to reliably measure with conventional online instruments It means an extremely low content.

[0030] In conventional refining, crude oil is extracted into many parts, and each part goes to a separate downstream market. It is sent to the road. In contrast, the inventors have developed a process utility for conversion and capture. - Except for the crude oil portion that provides the flow, it captures pollutants such as sulfur, nitrogen, and heavy metals. Furthermore, they discovered that the maximum amount of crude oil raw materials in each barrel can be converted into a single ultra-clean fuel. The present invention provides a minimum number of parts of crude oil supply material necessary for capturing and controlling pollutants. It is then extracted as a single component, and subsequently reassembled to form a single fuel product. [Means for solving the problem]

[0031] Therefore, the present invention relates to the production of gasoline, diesel, fuel oil, or chemical products downstream. Alternatively, to meet the needs of multiple markets, such as supplying raw materials for various applications, each of the crude oil supply materials Unlike conventional refining methods that divide fuel, the method of the present invention primarily produces clean fuel products. The aim is to produce a low-cost refinement for unrefined and residual oils. We provide a polishing system, which is used in commercial transport ships and power plant combustion systems. To produce large quantities of clean fuel on a commercial scale to replace sulfur bunker fuel and other heavy residues. This is necessary for the purpose of producing such fuel and a method for producing the fuel. We provide solutions to reduce sulfur in a cost-effective manner.

[0032] These new processes reduce the sulfur content of the final product to the target sulfur level in a remarkably effective way. This invention reduces manufacturing costs by using counterintuitive steps while keeping the process under control. During fuel production, contaminating sulfur, nitrogen, and harmful metals are simultaneously captured, while each component of the crude oil supply... This provides a novel method for converting the maximum amount of fuel into a single ultra-clean fuel.

[0033] In many variations of the present invention, essentially all of each barrel of feed is, in a particular variation Then, an amount characterized as 90% or more of the volume is converted to a single fuel, and such modifications Therefore, only a minimum amount, less than about 10% of each barrel of crude oil, is used for the conversion and capture of pollutants. It is consumed for process utilities and flow. The process of the present invention is Hydrogen balance, local demand for asphalt, coke and other residual products, overall Production economics, as well as the local availability of alternative low-cost process fuels and electricity. For other operational considerations, such as the allocation of raw materials to fuel production Process utilities and flows for the conversion and capture of contaminants as well as other pollutants. Allows for adjustment of allocated raw materials. In a modified example, a small amount of each barrel of crude oil supply At least 70% by volume is converted to a liquid fraction and subjected to subsequent processing, or remains unprocessed. When combined, it produces sulfur that does not exceed the target sulfur content, rather than multiple hydrocarbon products. Forming substantially one liquid fuel product having the content of each barrel of the crude oil feed The remaining portion is present in the residue or other vapors or products.

[0034] Unlike conventional refining, which divides crude oil into many parts and sends them to separate market channels... The present invention divides a crude oil supply into the minimum number of parts necessary for capturing and controlling pollutants. The extracted parts are then reassembled to produce a substance with very low levels of sulfur and nitrogen, and essential The method and apparatus configuration of the present invention are large-scale Large quantities of low-sulfur fuel necessary for regulatory compliance in offshore and onshore turbine applications, at low cost. These new fuel deployments enable efficient and rapid production. It has substantially lower capital and operating costs compared to crude oil refining, and as a result it is extremely efficient. A fuel that is efficient in use, has very low sulfur and nitrogen content, and is essentially metal-free. These new processes enable mass production of oil, marine engines, or onshore power plants. This enables a highly cost-effective means of simplifying the energy supply chain to [the system].

[0035] For the shipping industry, the novel configuration of this invention is intended to achieve global targets for reducing marine sulfur. To provide the required amount of low-cost, low-sulfur marine fuel. The novel fuel production method of the present invention and The equipment configuration has substantially lower capital and operating costs than conventional crude oil refining, As a result, a large number of ships have very low sulfur content, are essentially metal-free, and have very low nitrogen content. To produce fuel using an extremely cost-effective method.

[0036] The fuel of the present invention replaces low-grade heavy bunker oil, which is high in sulfur and metals, with SO2. x, NOx, CO 2、 Significantly reduce emissions of soot and harmful metals into the open ocean. In the implementation of this invention, instead of sulfur and metals being carried into the environment during the combustion of oil, Sulfur, nitrogen, and metals are captured and removed during combustion manufacturing in an environmentally friendly manner. In one embodiment, the present invention provides a specific low-sulfur alternative fuel at a lower cost than diesel. These fuels provide sufficient lubrication to avoid excessive wear on the marine engines. These novel fuels possess properties that, compared to other alternative fuels, do not heat up the fuel to maintain its fluidity. Since existing bunkering fuel infrastructure can be used without having to do anything else, onshore and This can reduce the energy consumed to heat the fuel in the tanks on board the ship. .

[0037] In one variation, the fuel of the present invention also generates, for example, electricity and desalinated water. Large-scale onshore combustion deployed in facilities such as single-cycle or combined-cycle power plants. This invention provides an alternative to burning crude oil or heavy residue in turbines. The turbines that burn fuel emit NOx, SOx, and CO 2、 Soot, harmful metals and other combustion The turbine exhaust gas emissions from combustion by-products are remarkably low, and depending on the source, contaminated heavy minerals may be present. When burning oil or refined residue, contamination under high-temperature zone corrosion or ash formation conditions is also reduced. stomach.

[0038] The present invention relates to a composite hydrocarbon supply material for marine engines, combustion gas turbines or combustion systems. This project concerns the concentrated conversion to single-fuel products for use in combustion applications such as heaters. In the basic embodiment of the Ming, crude oil enters from the front, is controlled to low sulfur levels, and nitrogen is reduced. Then, a single, ultra-clean product fuel, from which metals have been removed, is returned. In a modified form, the fuel for distillation is used. The feed is combined with one or more high-sulfur fuel oils or other heavier residues. One or more crude oils, which have been subjected to vacuum distillation, solvent separation, hydrogenation, or gasification. Lighttight oil or This can be crude oil with high sulfur content, or a combination of both.

[0039] In other applications in the art, the term "high-sulfur fuel oil" or "HSFO" is used. In various technical articles, patents, and laws, there are different, often dissimilar, and contradictory statements. This item has been assigned meanings that cause confusion, some of which change over time. As used in this book and in the claims, “high sulfur fuel oil” or “HSFO” means 0.50 Any substance used as fuel having a sulfur content exceeding %m / m (0.5 wt%) This means the terms "heavy oil," "heavy residual oil," "residue," and "residue" used in this specification. The term "other heavier oils" refers to oils with a sulfur content of 0.50% m / m (0.5% by weight). Contains petroleum-derived hydrocarbons exceeding ) the target sulfur content. The term "high sulfur" is used under the target sulfur content regulations. This means a value exceeding the lower of the limit or, if applicable, the statutory sulfur limit.

[0040] In a preferred embodiment, the sulfur content of the final product fuel is determined by the flow having different sulfur content. It is controlled by a combination of these. In the modified example, each of these combined flows is single By adjusting the operating conditions and flow rate, it is possible to add a very low amount of sulfur to the flow. This can be achieved by reducing the amount removed or by blending feeds with different sulfur content. This is formed to a provisional target sulfur content. Modifications of the present invention are selected as needed. The crude oil is mixed with (i) other crude oil, (ii) bunker fuel, (iii) high-sulfur fuel oil or (iv) Other distillates, or (iv) other high-sulfur or metallic contaminating residues from other sources. This specification includes controlling the sulfur level of the product by supplying one or more sulfurous materials. and the terms “essentially metal-free” or “zero metal” as used in the claims The term refers to a metal content of zero to less than 100 ppb (parts per billion) by weight or conventionally. This means the content is so low that it is difficult to reliably measure it using online instruments.

[0041] The inventors have addressed the sulfur content distribution of different crude oil feedstocks to achieve low sulfur fuel consumption. We discovered that we could optimize the production of the material.

[0042] The present inventors have identified (i) a basic H2S or RSH thiol type containing only a relatively small amount of sulfur. (ii) when present in a basic form in a particular fraction, and (ii) when a relatively large portion of sulfur is more complex It can be dealt with when it exists in a rough organic structural form, and at that time the sulfur content is good Compared to lower fraction levels, it begins to increase more rapidly, and in some cases exponentially. Furthermore, based on the predicted delimiter fractions at higher or higher levels, the process The flow rate and operating conditions can be adjusted.

[0043] The inventors have enabled bypass processing of a specific flow and maximized that bypass, and base To avoid or reduce the processing of flows containing sulfur forms with low complexity, and to avoid more complex forms In order to enable the flow containing the process to be processed in different ways, the process and We found that it is possible to configure the equipment. This allows for the hydrogenation and desulfurization of a specific flow. Selectively exclude from one flow, and for the other flows, supply the same to different hydrogenation treatment devices. Adjusting different hydrogenation unit conditions, or solvents and / or reactive chemicals. The removal process can be adjusted by the base treatment. In this case, one or more removal units can be used. The treatment is performed with multiple solvents or other removers within the set, and each of the removers within each unit The ratio is determined by the amount of sulfur in each unit to selectively remove sulfur-containing molecules with low or high complexity. This may include adjusting based on the yellow distribution.

[0044] The terms "kerosene" and "light distillates" are often used interchangeably across different references. , although used with the same, overlapping, or different meanings, uniformly within a temperature range (for example) Only at the fraction boundary point of an atmospheric distillation column at 190°C to 250°C or 180°C to 230°C. It is defined based on, not based on sulfur content. Instead, The appropriate sulfur content measurement is determined by the fraction boundary temperature, which is determined by the specifications of each product from the conventional refinery. It is performed and reported based on a degree range. The inventors found this to be not the best. did.

[0045] The inventors believe that by changing the basic method of operating a crude oil distillation column, the cost of low-sulfur combustion production can be reduced. We discovered that we can optimize the reduction of certain distillates. The inventors have found that by extracting specific distillates, kerosene, Standard product temperature range for long-standing use downstream of jet fuel, diesel, etc. Rather than focusing on specifications, we should consider the analysis of the sulfur content of the crude oil raw materials or feed mixtures supplied to the distillation column. We found that this should be done taking into account the sulfur content of the bystream.

[0046] The inventors have discovered how to define a "delimiter," and a delimiter is... The change in sulfur content per unit volume in the product (slope of the graph) is no longer substantial. This refers to the fact that it is not perfectly flat, and instead, at the dividing point, the amount extracted is small As the sulfur content increases, the slope of the graph per unit volume begins to change significantly. It begins to increase rapidly or exponentially, as in the example above. Also, beyond the dividing point, the original Depending on the type of oil supply raw material, typically the type and composition of sulfur-containing compounds, as well as their complexity, vary. The delimiter is the flow that requires desulfurization, where desulfurization can be minimized or eliminated. This is an indicator derived from the separation of the flow portion.

[0047] The inventors directly extract the maximum amount of a substance having a sulfur content below a certain threshold and To accumulate and avoid or reduce the cost of treatment for reducing or removing sulfur downstream. If the goal is to maximize the total amount of liquid produced that has a sulfur content in the extract below the dividing point, We found that the capital and manufacturing costs of low-sulfur fuels can be minimized.

[0048] The inventors believe that such substances, in relatively large quantities below a certain threshold, and in certain crude oils, In the case of the narrow, specific zone above the dividing point, the sulfur removal treatment has already been carried out. When combined with the extracted material, treatment for sulfur removal or subsequent important treatment is required. We discovered that it is not necessary. The inventors mainly focused on the feed or tower temperature profile. The rise not only pushes forward atmospheric distillation conditions, but also reduces or eliminates reflux, or crude oil The supply crude oil is mixed to reduce the supply rate or maximize the extraction amount up to near the threshold. Alternatively, by changing the composition of crude oil hydrocarbons or sulfur through dilution, To maximize the production of untreated material and reduce the cost of desulfurization or other treatment operations throughout the entire flow. The dividing line is determined from the standpoint of standard industry classifications or regulations that set the temperature range for extraction. It is not something that can be defined.

[0049] In this specification and claims, the inventors define a “breakpoint” as the analysis of crude oil. Alternatively, in relation to other measurement methods, the x-axis can be plotted with the mass percentage or volume of crude oil, and the y-axis with the sulfur content. When considering lots, sulfur exhibits a large change in the slope of the graph per unit volume. This is the point at which the content begins to increase sharply or exponentially from a horizontal or near-horizontal position. This is defined as follows: The difference in the x-axis direction is the change in the unit volume of the fraction, and the difference in the y-axis direction is the sulfur content. The change per unit volume of a quantity is represented by the gradient, which is the slope of the graph. The gradient moves rapidly from zero or near horizontal to over 0.2, and then rapidly It moves towards a somewhat exponential increase in sulfur content, exceeding 1, and the interval The distillation point changes based on the crude oil or other raw materials supplied to the distillation column. Therefore, the "division" "Point extraction" or "sulfur delimiter point extraction" refers to the endpoint of the naphtha range, for example, stabilization. As described above, the amount of unprocessed, natural straight-run naphtha exceeds the end of the range per unit volume. The point where the slope of the graph changes significantly indicates that the sulfur content begins to increase rapidly or exponentially. The present invention provides a means for determining the separation of a hydrocarbon-containing liquid into a boiling liquid below a certain threshold.

[0050] In this specification and in the claims, the inventors refer to the base "delimiter extraction" or base The bottom "sulfur delimiter extraction" is used in relation to the sulfur content of the fraction, in an unstabilized natural manner. This refers to hydrocarbon-containing liquids that boil above the endpoint but below the boundary point of the straight-run naphtha range. It is defined as the fuel product flow being a combination of all untreated flows below the dividing point. All flows of the delimiter points selected to be added to the combination If the delimiter is selected so as to be formed, the actual sulfur of the combined fuel The content does not exceed the target sulfur content. In the modified example, the target sulfur content is the sulfur boundary point. Fuel can be manufactured according to the sulfur boundary, or if it is higher or lower than the sulfur boundary. The combination of flows used to produce the fuel ensures that the actual sulfur content of the fuel does not exceed the sulfur target. Sea urchins are efficiently produced using dividing points as a guide.

[0051] For many crude oils, sulfur delimiter extracts for atmospheric distillation columns are 180°C or Such as those that begin to boil at 190°C (or other kerosene range starting point) (in this technical field) It contains most of the substances in the kerosene range (as defined in various ways), and for simplicity, it is lower It may contain substances in the kerosene range or higher temperature range. However, the temperature and history of substances in the kerosene range may vary. Rather than a historical definition, sulfur content is the determinant of the endpoint of the sulfur delimiter range. The fuel can be formed according to the sulfur boundary point when the target sulfur content is the sulfur boundary point. The combination of flows is designed so that the actual sulfur content of the fuel does not exceed the sulfur target.

[0052] In one embodiment, crude oil feedstock is separated into flows, and one or more such separated flows are formed. A portion of the liquid is treated, while the other portion remains untreated. Then, the treated and untreated liquids are... Most of the flow is recombined, resulting in a liquid whose actual sulfur content is below the target sulfur content. The fuel is formed. The process steps are: (a) crude oil is distilled and solvent separated into one or more components. The step separates the light overhead distillation gas from one or more solvents used for solvent separation. This includes insoluble metal-rich residues, sulfur-containing gases, and liquid fractions above the sulfur boundary. (b) Separation into liquid fractions below the limiting point, and (b) liquid fractions below the sulfur limiting point and insoluble Rather than a residue of the sulfur content, the liquid fraction above the sulfur delimiter is subjected to one or more hydrogenation treatments. One of the products has been treated with TEP, while the rest remains untreated, resulting in a reduced sulfur content. or forming multiple hydrogenation treatment flows, and (c) the above hydrogenation treatment flow dividers Combine the liquid fraction below the sulfur threshold and use the actual sulfur content below the sulfur threshold as the target sulfur content. This includes forming the above-mentioned liquid fuel having the above characteristics.

[0053] In yet another embodiment, the present invention uses fuel manufactured according to the present invention. This approach is more effective in reducing emissions exceeding IMO specifications from vessels operating in the open ocean, within ECAs, or in ports. The law provides that the fuel, whether at sea, within an ECA, or in a port, Adjusted to be lower than the maximum amount specified by the IMO that may apply at the location of fuel use by ships. It has a sulfur content. In this way, the ship exceeds IMO requirements and general expectations. It is possible.

[0054] In other embodiments, the present invention relates to, for example, the offsetting of offshore or port fuel costs, A method for a ship to sell electricity generated in a bay using the fuel of the present invention to an onshore power distribution network. To provide.

[0055] The inventors have considered and adjusted the flash point in an appropriate manner, while limiting the use of sulfur and metals. They have found that they can produce low-cost, ultra-clean marine fuel, far exceeding the IMO's expectations. did.

[0056] Thus, the inventors have found that (i) minor changes in flash point are possible, and (ii) particularly in large cargo ships Large-scale environmental benefits associated with massive fuel consumption (huge reductions in SOx and NOx) A technical method has been discovered to replace (and essentially eliminate) harmful metals. No one was able to achieve it.

[0057] The International Convention for Safety at Sea (SOLAS) stipulates that the flash point of fuel and on cargo ships It outlines the permissible uses. "For many people, the uses presented in the SOLAS Convention The minimum flash point of 60°C for fuel in general maritime operations may seem like one of the fundamental principles of maritime law. However, this was first introduced in the 1981 revision. The first three SOLAS The treaties (1914, 1929, and 1948) set limits on the flash points of petroleum fuels. There are none, and even the 1960 Convention stipulates that fuels used in internal combustion engines must have a flash point of 43°C or higher. This merely requires that the "new" passenger ship meet certain requirements. Furthermore, this clause is included in the current 1974 Convention. "It was essentially carried over as originally adopted," the above is a quote from Non-Patent Document 5.

[0058] Wright et al. argued that the flash point is not an actual value but an empirical one, and that "the flash point The value is by no means a boundary line between "safe" and "unsafe," and in the past, such a thing has happened. He stated, "It has never been a boundary line." As a result, from the very beginning of the oil industry, storage and As a means of identifying products that require greater control and care in their use, The flash point has been used incorrectly. In reality, in marine applications, petroleum fuel fires are... Rather than vaporization ignition, the fuel is heated above its autoignition temperature due to a leak or pipe damage. It is caused by ignition upon contact with a surface. Nevertheless, the flash point is Even if the limits are sometimes set somewhat arbitrarily, or Taking into consideration the fact that these are experimental values, they were not initially used as safety parameters under the Petroleum Safety Act. It has been used.

[0059] SOLAS has created an exception for cargo ships. SOLAS is for ships with a flash point below 60°C. The regulations stipulate that oil fuels must not be used, but an exception is made for cargo ships, [SOLA S]2.1 has a flash point lower than the flash point specified in Chapter 2.1 (e.g., 60°C), for example The use of fuels such as crude oil means that such fuels are not stored in any engine room. , and may be permitted subject to approval by the authorities." Some countries do not have flash point standards, and It should also be noted that other countries allow relatively low flash points for marine applications.

[0060] The fuel flash point can be adjusted by processing as needed. (Specified and patented) As used in the claims, the term “flash point treatment” refers to the flash point when combined with the material. This refers to a composition that raises the flash point. In one variation, flash point treatment reduces the risk of vapor ignition. To lower the vapor pressure of the added material, one variation is to use a flash point modifier above 60°C. A solid or liquid additive having a flash point, which is added to a low flash point fuel to enhance the fuel's flash point. To raise the ignition point. These can include various types of fine particles and oil. For example, charcoal. High flash point additives for processing basic fuels are disclosed. For example, Hughes et al. Patent Document 3 describes a paraffinic base oil having a flash point of 200°C or higher, and a mixture thereof or This document describes "high flash point diluents" selected from a group of combinations, specifically, Obtained from Calumet Lubricants, Inc. in Indianapolis, Indiana. Possible Calpar100 (FP210℃), Calpar325 (FP240℃) Paraffin with a flash point of Calpar P950 (FP257℃) and 200℃ or higher Examples include corn-based base oils and their mixtures or combinations.

[0061] The inventors of this invention believe that (i) minor changes in flash point, and (ii) large amounts of fuel, particularly from large cargo ships, can be used to reduce the risk of burning. Large-scale environmental benefits associated with consumption (huge reductions in SOx and NOx and harmful emissions) A technical method has been discovered to replace (the essential exclusion of the genus). To date, no one has made such a discovery. It wasn't possible. [Brief explanation of the drawing]

[0062] [Figure 1] A schematic diagram illustrating various actual and hypothetical crude oil sulfur content ranges. [Figure 2] A schematic diagram showing the process layout for processing crude oil to produce a single liquid product useful as fuel according to the present invention. [Modes for carrying out the invention]

[0063] In one embodiment of the present invention, the hydrocarbon feedstock is a small amount of crude oil having sulfur and metals. A method for converting at least a portion of the feed into a single liquid product is (i) one or Multiple distillation and solvent separation steps allow the butane removal column system to be adapted to specific local conditions. Even if it is preferable in terms of costs that should be eliminated in other circumstances, the EIA's terms Light Over - Head distillation gas, one or more solvents used for solvent separation, and metal-rich residue insoluble in them. , sulfur-containing gases, as well as (some feeds that are treated as being within the distillation range) Distillates (containing at least some of the substances in the kerosene range) and carbonized water in the reduced pressure diesel range (ii) Separation into a liquid fraction containing sulfur, (ii) Extraction below the sulfur boundary and not liquid fractions (and preferably any fraction insoluble in the solvent used for solvent separation) (Not even in the fractional portion), selected liquid fractions higher than the sulfur delimiter (and preferred (or only soluble liquid fractions are selected for hydrogenation treatment) one or more hydrogen Hydrogenation treatment is performed in a chemical treatment step to reduce the sulfur content of one or more hydrogenated (iii) forming a processing flow, and combining the above unprocessed fraction with the above processing flow This includes forming a fuel in which the actual sulfur content is less than or equal to the target sulfur content. When used in the documentation, the terms “step” or “zone” refer to the device configuration and / Alternatively, one or more units having one or more divisions of unit operations or subzones. This can refer to a unit operation or area that has a processing operation. An equipment item is one or more Tanks, vessels, distillation columns, separators, reactors or reactor vessels, heaters, exchangers, strips It may have a valve, pipes, pump, compressor and controller. In a preferred modification of the invention, substantially all of the hydrocarbon composition of the feed is separated into fractions. However, they are then combined again to form a single liquid fuel product, which is the fuel. It is a single liquid fuel product containing a range of hydrocarbons from its original supply, liquefied petroleum gas. or, in one variation, includes everything from naphtha to hydrogenated deasphaltized oil. Furthermore, it does not form multiple hydrocarbon products, but (i) light overhead gas of the distillate (ii) within the above-mentioned insoluble residue, and (iii) within the sulfur or metal recovery flow, Hydrocarbon compositions containing hydrocarbons are excluded. Such compositions range from C3 or C5 to C2. This includes substantially the entire range of crude oil-derived hydrocarbons of 0 or more, and these hydrocarbons are incorporated into the fuel. It has an initial boiling point which is the lowest boiling point of any fraction in the combined untreated flow, and is combined with the above fuel. It has the highest boiling point, which is the highest boiling point of the processed flow. Used in this specification and in the claims. The term "untreated" as used refers to water that has been treated to reduce or remove sulfur, nitrogen, or metals. This means that it has not undergone any chemical treatment. In one variation, such fuel is essentially C 3 or C5 to C20 or higher crude oil-derived hydrocarbons, or approximately 35°C to approximately 31°C A range of crude oil-derived hydrocarbons having an initial boiling point within a range of 5°C or higher, preferably deasphalt. A range having the end of the t-fermented oil and the initial boiling point of the deasphaltized residue. It contains substances that do not dissolve in the solvent selected for solvent separation. In a more preferred variation, the fuel of the present invention is the lowest boiling point of the above untreated liquid fraction from atmospheric distillation. A combination of hydrocarbons ranging from the point to the highest boiling point of the hydrogenated soluble product after solvent separation. This includes combinations. Therefore, the preferred fuel of the present invention is taken in a selected partial range. Conventional gasoline, which is produced and does not have a significant content of the maximum range of such hydrocarbons, It is the exact opposite of diesel, kerosene, and fuel oil. Therefore, one embodiment of the present invention is A fuel obtained as a single product by processing crude oil, wherein the fuel is 0.5% by weight or less. Preferably, it has an actual sulfur content of 0.1% by weight or less, and is C3 or C5 to C20 or higher. It comprises substantially the entire range of hydrocarbons derived from crude oil. The hydrocarbons are obtained under atmospheric distillation conditions. It has an initial boiling point which is the lowest boiling point of any fraction of crude oil, and is insoluble in solvents suitable for solvent separation. The crude oil has a maximum boiling point, which is the endpoint of the residual portion. In a modified example, such a fuel is C3 or substantially the entire range of crude oil-derived hydrocarbons from C5 to C20 or higher, and the above hydrocarbons This is the initial boiling point, which is the lowest boiling point of any fraction in the untreated flow combined with the above fuel. And has an endpoint which is the highest boiling point of the processing flow combined in the above fuel. This involves using crude oil to produce light overhead distillation gas and one or more solvents used in solvent separation. Molten metal-rich residue, sulfur-containing gas (including sulfur-containing purge gas), and sulfur It is separated into a liquid fraction containing yellow, and this liquid fraction consists of (i) the liquid fraction below the sulfur boundary point, and (ii) Having a liquid fraction exceeding the sulfur boundary, both are compatible with the solvent used for solvent separation. (b) It is either soluble or insoluble, and is not a liquid fraction or insoluble fraction below the sulfur boundary, but rather sulfur The soluble liquid fraction exceeding the threshold is hydrogenated by one or more hydrogenation steps. Process to form one or more treated streams having a reduced sulfur content, ( c) The untreated fraction is combined with the above processing flow to obtain the target sulfur content. The following fuel is formed:

[0064] In the modified form, such residues are used for power production, as well as hydrogenation and removal. Used to generate at least a portion of hydrogen to capture at least a portion of the metal in a solid in a sintering furnace. For use, it is burned in one or more gasifiers, or the residue is used for power generation and For use in the operation of auxiliary hydrogen generation units to supply hydrogen for hydrogenation processes, flue gas sulfur and burned in one or more boilers that capture metal. Preferably containing sulfur. All gas is sent to one or more common sulfur recovery units.

[0065] By implementing the present invention, the actual sulfur content of the above fuel will meet the target sulfur content limit specification. It can be adjusted to satisfy the following conditions, for example, the untreated combination for forming the fuel. By adjusting the amount of continuous flow in the processing flow, the IMO specifications or combustion of marine fuel can be adjusted. It can meet the sulfur requirements for gas turbines. For example, the target sulfur content of the fuel can be set to EC One or more target IMO specifications, either inside or outside of A, e.g., 3.5% by weight, 0.5% by weight Adjust to meet the specifications selected from the following IMO specifications: % by volume, 0.1% by weight, or other specifications. This can be done. The fuel produced according to the method of the present invention can be used in marine engines, combustion gas turbochargers. It is useful for combustion heaters such as boilers and other applications.

[0066] In one variation, at least one of the hydrogenated flows is 10 ppm by weight or less This is an ultra-low sulfur flow having sulfur below, and increasing the amount of the flow relative to the above combination or By reducing the sulfur content, we can adjust the formation of fuels whose actual sulfur content is below the target sulfur content. It is used for the purpose of. In other variations, at least one of the hydrogenated streams is This is an ultra-low sulfur stream containing 10 ppm by weight or less of sulfur, and the untreated fraction has the target sulfur content. Having a sulfur content exceeding a certain amount, the untreated fraction is used as trim control, and the above combination By reducing or increasing the amount of such untreated fractions relative to the target, the actual sulfur content will be reduced. It forms a fuel with a sulfur content below a certain level. In further variations, the crude oil supply is divided into multiple coals. If converted to essentially a single liquid fuel product rather than a hydrogen-based product, the concentration is less than 10 ppm by weight. A first hydrogenation treatment flow is prepared, which is a reduced sulfur flow having a sulfur content of Second hydrogenated fuel fraction having reduced sulfur flow in the range of 0.12-0.18% by weight A solution is prepared, and the untreated fraction is below the threshold sulfur or above the threshold sulfur, and is Having a sulfur content exceeding the standard sulfur content, the above-mentioned first hydrogenation treatment flow or second hydrogenation treatment The flow, or both, affects the increase or decrease in the amount of such flow for the above combination. Furthermore, it is used as trim control, and fuels whose actual sulfur content is below the target sulfur content. To form.

[0067] In a more preferred embodiment, one or more crude oil, residual oil and other feeds The sulfur content is selected, or the processing conditions are adjusted, for each barrel of the crude oil supply. At least 70% by volume is converted to a liquid fraction, which is then processed or unprocessed but combined When combined, the sulfur content is below the target sulfur content, rather than being a combination of multiple hydrocarbon products. A fuel having the above is formed, and 30% or less of each barrel of the crude oil supply is other than fuel. It is directed towards the substance. In preferred variations of the present invention, the composition of the feed, the hydrogen balance, and the process In addition to the economics and other factors, carbonized water can be adjusted according to the process operating conditions and flow rate. Of each barrel of the elemental feed, at least 80% by volume of each barrel feed, more preferably Approximately 90% or more are not multiple hydrocarbon products, except for streams with very low sulfur content. It is converted into one liquid fuel product. The flow with very low sulfur increases the trim flow. This reduces the sulfur content of the final fuel product, controlling it to a level that does not exceed the target sulfur content. It is used as a trim. The excess amount of trim flow is used for material balance and inventory management purposes. They can be transferred individually. In such preferred modifications of the present invention, the crude oil supply Approximately 10-30% or less of the volume of each barrel of material is metal after atmospheric and vacuum distillation by solvent extraction. It is captured in the rich residue.

[0068] In other variations, all treated and untreated fractions are combined to form the above fuel. Before or during the mixing process, high-sulfur fuel oil with a sulfur content higher than the target sulfur content Add the above-mentioned high-sulfur fuel oil alone or together with light-tight oil. Distill the above-mentioned distillation step It can be supplied to one or more of the following steps: solvent separation step or hydrogenation step. In one preferred embodiment, the ultra-low sulfur flow has a sulfur content in the range of 10 ppm by weight or less. The untreated fraction has a sulfur content exceeding the target sulfur content, and the untreated fraction is actually sulfur In order to form a product fuel in which the yellow content is less than or equal to the target sulfur content, the combination It is used to adjust the amount of untreated fraction by increasing or decreasing it.

[0069] An apparatus for carrying out the method of the present invention has a typical downstream processing unit, and its equipment area is such that This can reduce the installation area of ​​equipment in conventional refineries to a range of 20% to 30%. Therefore, the capital cost per barrel of processed supply is effectively reduced. For example. In one particular embodiment of the present invention, an auxiliary device necessary for capturing sulfur and metals. Along with, one or more of the following: atmospheric distillation, vacuum distillation, solvent separation, hydrogenation, and gasification. Except for gasification that uses only numbers and requires auxiliary equipment to capture sulfur and metals. Furthermore, there are no hydrocarbon treatment operations downstream of the hydrogenation process.

[0070] Modifications of the process configuration of the present invention provide an integrated metal and sulfur capture means while Island-like structures of facilities that supply hydrogen, steam, and fuel gas, as well as the processes necessary for power generation (U The effective integration of Tility Island provides highly efficient and low-cost operation. Utility islands capture metallic pollutants as components of potential air emissions. To capture and eliminate heavy metal-rich residues, preferably integrated, however Therefore, for sulfur capture, treatment, and removal at a lower capital cost, as a potential source of emissions Using sour gas and acidic gas off-gas treatment from all sources, one or more It has a gasification system. The island configuration of the present invention satisfies process requirements for hydrogenation treatment. Hydrogen for stepping, as well as specific flows for electrical processes and normally waste flows. Steam and fuel gas for electric processes via a highly efficient combined cycle power generation system, To make.

[0071] One modification of this embodiment of the present invention is that the light-tight oil undergoes hydrocarbon treatment and corresponding The bottom fraction contains heavier hydrocarbons sufficient to provide a processing balance for hydrogen production. When it is not contained in the residue, such light crude oil is treated by hydrogenation to remove sulfur and This method makes it possible to reduce metals and decontaminate the light crude oil. All substances, either separately or mixed, are led to atmospheric distillation, vacuum distillation, or solvent separation treatment. The process includes the step of adding it to any or all of the heavier feedstocks.

[0072] In one modified example, vacuum distillation, solvent separation, hydrogenation, and gasification operations are performed downstream of atmospheric distillation. The design of the apparatus for this purpose involves high-sulfur fuel oil or another supply outside the battery limit for the operation. Size such that it has additional or reserve capacity to process additional heavy residue from the source. And, by forming fuel in which the actual sulfur content is below the target fuel sulfur content limit level, additional It captures at least some of the sulfur and metals from heavy residues.

[0073] In another embodiment, the present invention uses the fuel of the present invention while a vessel is anchored in a harbor. In addition to generating electricity and reducing emissions in rural areas, it provides a way to sell it to the onshore power grid. In one modified example, the present invention provides a technical method for reducing emissions in and around ports. (a) the method involves generating land power that is normally supplied to the power grid at or near the port. The amount of sulfur or metals emitted per kilowatt-hour (kWh) by the above power generation equipment (for example) If a ship is connected to such a power distribution network in a port, the use of local power supply is related to this. (b) A technical analysis to confirm the emissions (including those of the same ship) when it is in port at the location of (a) To verify the amount of sulfur or metal emissions per kWh generated by electricity produced on board a ship. This includes a technical analysis comparing (a) and (b), and (b) the amount of electricity generated by ships for power generation. If the emissions are lower than those of the local power source in (a), then reduce emissions on board the ship and reduce emissions on board the ship. Provides all or part of the electricity to the power distribution network. This embodiment assumes that the electricity supplied locally is specific If it is from a type of coal combustion source, or if there are lower emission options for local power generation If it is not available and heavy crude oil or residual oil is burned for power generation, the environmental emissions will be It can be particularly useful in reducing emissions. Without offsetting, the amount of electricity transmitted by ships to the local power grid would be... The reason for providing this service is that the kWh cost of electricity generated on ships exceeds the kWh cost of electricity from the local distribution network. In such cases, or if such provision to the local power grid by ship is paid for by low-emission power generation. Other forms of benefits can be brought to ships, such as offsetting them with emission reduction deductions such as subsidies. If not applicable, it will likely not be done unless there is an offset in the form of port usage fees.

[0074] If it is beneficial for ships to supply power to the local distribution network, ships may use the fuel of the present invention to reach ports. To provide all or part of the electricity generated on board while the ship is docked to the shore-based power distribution network. The increased revenue can offset or reduce fuel costs incurred at sea. The above revenue generated from providing power to the distribution network while the vehicle is anchored may vary depending on the length of time the vehicle is anchored in the port. The fuel costs for sea navigation are reduced, and the actual fuel costs for sea navigation due to these new fuels are reduced. It can be offset to a level that is lower than the cost of high-sulfur fuel oil for the line. .

[0075] Figure 1 shows schematic diagrams of various actual and hypothetical crude oil sulfur content ranges. This is a set. Exemplary crude oil sulfur profiles 4, 5, and 6 were extracted from Non-Patent Document 6. The plot is based on the center point of the actual data. Assumed crude oil sulfur profile 1, Sections 2 and 3 are based in part on actual data taken from various sources, including Non-Patent Document 7. I have obtained it.

[0076] Figure 1 suggests the definition of “breakpoints” for different crude oils for the process configuration of the present invention. The method is shown below. Figure 1 illustrates a dividing point, which is the unit of the extracted product. The change in sulfur content per unit volume change (slope of the graph) is no longer substantially horizontal or flat. That is not the case; instead, at the dividing point, as the amount extracted increases slightly, sulfur The yellow content begins to increase rapidly or exponentially, and the slope of the graph per unit volume becomes large. This brings about significant changes. Furthermore, beyond the dividing point, the sulfur content changes depending on the type of crude oil raw material supplied. The mixture, type, composition, and complexity vary. The dividing line is determined by the cost for operational efficiency. This makes it possible to determine the best way to bypass such intensive hydrogenation processes. And yet it makes it possible to produce fuel that conforms to the target sulfur content limit specifications. The dividing line is the point that is further away from or lower than further downstream processing to reduce the sulfur content. The maximum sulfur content of atmospheric crude oil column fractions is reduced, for example, by moving away from the hydrogenation process. It can be present in large quantities. The fraction above the dividing point is subjected to downstream treatment for reducing the sulfur content. This leads to a situation where fractions below the dividing point are not processed, resulting in substantial savings in operations. In the purification process, extraction is fixed by the temperature range, not by the sulfur content. Target Sulfur content can be used as an example of end-use requirement to determine the selection of boundary points. If the cutoff point is set too high, the excess untreated flow with a higher sulfur content will be absorbed by the water with a lower sulfur content. Because the amount of data processed increases, it cannot be easily offset.

[0077] Figure 2 outlines another embodiment of the present invention, a single liquid suitable for use as fuel. Figure 2 shows a simplified representation of the main components of the process configuration for manufacturing the product. It integrates atmospheric and vacuum distillation, solvent separation, hydrogenation, and gasification to create a single low-sulfur product. This document describes a method for producing fuel products that are essentially free of metals.

[0078] The flow of contaminated crude oil containing sulfur, nitrogen, and metals is preferable to the crude oil for pretreatment such as desalination. After processing, it proceeds through line 2 and enters the main process. In this embodiment, the crude oil supply raw material 2 is a single raw material. Oil, a blend of one or more crude oils, or a blend of crude oil and residual oils such as high-sulfur fuel oil. It can be a substance. The raw material 2 is led to the atmospheric pressure distillation column 100, where the raw material is light The light overhead gas 4 is separated into a high-quality overhead gas 4 and multiple extractables. This includes non-condensable distilled gas 6, which is useful as a process fuel, or captured for other applications. In one preferred modification, a stabilization system for such overhead gas 4 is implemented. Capital expenditures related to the system will be avoided. However, depending on local needs, for example, special It may also include a stabilization system, such as a different marine fuel with a maximum H2S specification. In the application method, multiple extractables have one or more flows within the following range, i.e. ( 1) Unstabilized, as-is straight-run naphtha from line 16 via line 4, (2) (3) Sulfur delimiter extraction from line 18, (4) Light distillate from line 24, (5) Line 26 (5) the intermediate distillate of line 28, and (6) the atmospheric pressure residue of line 30. It includes objects.

[0079] In various applications in the art, different meanings are assigned to the same or similar extracts in different regions of the world, and those meanings often differ, overlap, conflict, or cause confusion. When used in this specification and the claims, they are used with the following meanings. That is, (a) "naphtha" means a carbon-containing composition ranging from those having at least three carbons C3 like propane to those having an initial boiling point (IBP of about 175 °C (about 350 °F), excluding low-boiling compounds such as methane and below. (b) "Stabilized naphtha" means that, as far as naphtha or other naphtha-range substances used as fuel blend bases are concerned, low-boiling compounds below butane or propane are almost completely removed from the naphtha or fuel. For example, in a conventional refinery , the bottom stream from a naphtha debutanizer is stabilized naphtha. (c) "Unstabilized naphtha " means naphtha from which light components below C4 have not been removed. For example, in a conventional refinery , the feed stream to a naphtha debutanizer is unstabilized naphtha. (d) "Natural straight-run naphtha that has not been stabilized" means a range from those having at least three carbons C3 like propane to those having an initial boiling point (IBP) of about 175 °C (about 350 °F), excluding low-boiling compounds such as methane and below, and may include atmospheric distillation overhead distillation gas, and means a carbon-containing composition recovered from atmospheric distillation. (e) "Natural naphtha" means the unstabilized light fraction of the hydrotreating unit effluent recovered from a distillation column or other separator in a hydrotreating process. In terms of operation, it means the bottom of a separator or other substances heavier than the naphtha portion of the feed to a distillation section, heavy oil range , or other separators, such as substances heavier than the naphtha portion of the feed to a separator or fuel. (b) "Stabilized naphtha" means that, as far as naphtha or other naphtha-range substances used as fuel blend bases are concerned, low-boiling compounds below butane or propane are almost completely removed from the naphtha or fuel. For example, in a conventional refinery , the bottom stream from a naphtha debutanizer is stabilized naphtha. (c) "Unstabilized naphtha " means naphtha from which light components below C4 have not been removed. For example, in a conventional refinery , the feed stream to a naphtha debutanizer is unstabilized naphtha. (d) "Stabilized " means naphtha from which light components below C4 have not been removed. For example, in a conventional refinery " means naphtha from which light components below C4 have not been removed. For example, in a conventional refinery from those having at least three carbons C3 like propane to those having an initial boiling point (IBP) of about 175 °C (about 350 °F), excluding low-boiling compounds such as methane and below, and may include atmospheric distillation overhead distillation gas, and means a carbon-containing composition recovered from atmospheric distillation. (e) "Natural naphtha" means the unstabilized light fraction of the hydrotreating unit effluent recovered from a distillation column or other separator in a hydrotreating process. In terms of operation, it means the bottom of a separator or other substances heavier than the naphtha portion of the feed to a distillation section, heavy oil range or other separators, such as substances heavier than the naphtha portion of the feed to a separator or other separators, such as substances heavier than the naphtha portion of the feed to a separator or other separators, such as substances heavier than the naphtha portion of the feed to a separator range, or other separators, such as substances heavier than the naphtha portion of the feed to a separator is part of a hydrotreating zone that recovers one or more heavy fractions in its vicinity and is not stabilized. (f) "Separator extract" has already been defined in this specification, and an example thereof is shown in FIG. 1. (g) "Light distillate above the separator extraction" or "light distillate" in this specification refers to a fraction having an initial sulfur content higher than the maximum sulfur content of the separator extract, and correspondingly has a boiling point (IBP) higher than the highest endpoint of the separator extract. (h) "Middle distillate" means a fraction between the light distillate and the heavy distillate separated as a preferably withdrawn product based on a distillation column design. For example, the middle distillate withdrawal is excluded and can be combined with either the light distillate or the heavy distillate. (i) "First heavy distillate" means the heaviest fraction of the atmospheric distillation unit, and its sulfur content and boiling point range are determined by one or more operating conditions such as the sulfur composition of the distillation unit feedstock, the severity of crude column operation, and downstream hydrotreating conditions. (<000090​​​​​​​​​​​​​​​​​​​​​​​​​​​​​​​​​​"Volatil", "vacuum residue", "light vacuum diesel fuel", and "heavy vacuum diesel fuel", "Solvent separation," "hydrogenation," and other terms, and variations thereof, refer to the processing of crude oil. This is publicly known to those skilled in the art.

[0080] Preferably, (1) the unstabilized natural straight of line 16 through line 4 The combination of the flow of the distillate naphtha and (2) sulfur delimiter extraction line 18 is 0 Contains sulfur in the range of 0.06% by weight to less than 0.08% by weight, and is a fuel combination for Line 600. If the target sulfur content of the waste is 0.1% by weight or less, then the sulfur content of the treatment flow 70 is 1 It is less than 0 ppm by weight, and at that time, the flow rates of steam 10 and 70 together are the fuel combination Wase 600 is adjusted so that its sulfur content does not exceed the target amount.

[0081] In Figure 2, the atmospheric pressure residue is supplied to the vacuum distillation column 200 via line 30, (1 (2) the second heavy distillate from line 32, (3) the light vacuum diesel from line 36, and (4) the second heavy distillate from line 38. Heavy vacuum diesel and (4) vacuum residue from line 50 are produced. The vacuum residue is produced (1) Deasphaltized oil and Pitch, a metal-rich heavy residue, is produced in line 90.

[0082] Figure 2 shows the two hydrogenation zones, namely the distillate hydrogenation zone 430 and the heavy oil The integrated hydrogenation system 400 includes a hydrogenation zone 460. The elementary processing system is known in the art and is suitable for this application. However, Zo Hydrodesulfurization and hydrodemetallation in both zones 430 and 460 require approximately 117~ A relatively low-pressure, mild hydrogenation treatment within the range of 138 bar (1700-2000 psi). The rational conditions are sufficient.

[0083] The light distillate 24, the intermediate distillate 26, the first heavy distillate 28, and the second heavy distillate 32 are, Preferably, it is supplied to an integrated hydrogenation treatment system 400 and subjected to hydrogenation treatment in the presence of a catalyst. Under these conditions, the material is treated with hydrogen, and the distillate hydrogenation treatment zone 430 forms the flow of the distillate in line 60. The effluent 60 from such a hydrogenation treatment device is a substance within the following range, namely (1) expected The boiling point range is above C5 (composition with 5 carbon atoms) to approximately 175°C (approximately 350°C). (1) Natural naphtha, and (2) preferably with a sulfur content of less than 10 ppm by weight It contains light distillate 24, intermediate distillate 26, first heavy distillate 28, and second heavy distillate 32 Ultra-low sulfur D Contains Zel. By-products of hydrogenation treatment in Zone 430, at least a portion of which are sulfur-free. The waste is detreated and then subjected to distillate hydrogenation zone 430 or heavy oil hydrogenation zone 460, The hydrogen added to both is reused, such as hydrogen sulfide and hydrogen-rich off-gas, which contain sulfur. The gases contained, and typically small amounts of liquefied petroleum gas, may be included in the hydrogenation process. It is publicly known to those skilled in the art.

[0084] Light vacuum gas oil 36, heavy vacuum gas oil 38, and deasphaltized oil 80 are also preferred. It is supplied to the integrated hydrogenation treatment system 400, and under hydrogenation treatment conditions in the presence of a catalyst. The hydrogen treatment forms a heavy vacuum diesel hydrogenation treatment zone 460 and an effluent flow 70. The waste products from the eel hydrogenation treatment system include the following: (1) The expected boiling point range is C5 (composition with 5 carbon atoms). Natural naphtha that is above the substance) to about 175 °C (about 350 °F), and (2) Preferably having a sulfur content of less than 10 weight ppm, light vacuum gas oil 36, heavy vacuum gas oil 38 and the first part of the combined treated distillation steam having deasphalted oil 80, forming The ultra-low sulfur diesel, which is the first reduced sulfur stream in the heavy oil hydrogenation zone, (3) Preferably having a sulfur content in the range of 0.12 to 0.18 weight %, light vacuum gas oil 36, Heavy vacuum gas oil 38 and the second part of the combined treated distillation steam having deasphalted oil 80, forming The second reduced sulfur stream, having substances within the range. In zone 460 At least a part of the by-products of the hydrogenation treatment in the hydrogenation treatment are sulfur-removed, and the distillate hydrogenation treatment Zone 430 or heavy oil hydrogenation zone 460, or both, is reused as hydrogen added to Gas containing sulfur gas such as hydrogen sulfide and hydrogen-rich off-gas, and typically may contain a small amount of liquefied petroleum gas, which is known to those skilled in the art of hydrogenation technology It is known to those skilled in the art of hydrogenation technology.

[0085] The untreated stream 10 and one or more hydrogenation treatment liquid streams are combined via line 60 and line 70 to form a low-sulfur and substantially metal-free fuel product at line 600 Here, "combining" means being formed by mixing, blending, or other close combinations of the streams in the line. In one variant, the unstabilized natural straight-run naphtha via line 4 and line 16 and the sulfur cut point extraction via line 18 are combined within 100 without additional treatment, and then one or more streams from the distillate hydrogenation treatment zone 430 containing natural naphtha and ultra-low sulfur diesel ​​​​​​ Outcomes, as well as natural naphtha, ultra-low sulfur diesel, and heavy oil hydrogenation zones. One of the heavy oil hydrogenation zones 460, which has a second reduced sulfur flow formed at 460. Alternatively, a fuel combination of 600 can be formed by combining multiple spills. In the modified version, the hydrogenation zone 400 combines the effluents from zones 430 and 460. In combination, it appears as if lines 60 and 70 were combined within that zone. A single flow (not shown) is formed in such a modified form in the hydrogenation apparatus 430 and 4 This is useful when it is undesirable to separate the spills of 60. Preferably, vacuum diesel. The hydrogenation treatment section 460 provides overhead system flow and bottom system flow. It contains, and part of its flow consists of diesel boiling point range substances. This is also in zone 430. Compared to the combined diesel offered in the 460 and 600 A small amount is sufficient, and the combined diesel-side hydrogenation treatment section 430 is also block 60 O Barhead system flow and bottom system flow, either individually or as a part thereof. It has a natural naphtha bystream.

[0086] Heavy residue at the bottom of a 300-liter de-asphalter containing asphalt and metal-rich heavy residue 9 0 is heavy residue 90 in the presence of steam and oxygen, and any carbon-containing slurry quench. An integrated gasification combined cycle system including one or more gasifiers for partial oxidation The synthesis gas supplied to Tem 500, at least a portion of which is via line 502 A hydrogenation treatment system including a distillate hydrogenation treatment device 430 and a heavy oil hydrogenation treatment device 460 It is sent to the M400 and converted into hydrogen for use, as well as for process applications and other uses. Gas from the combined cycle power generation unit in the gasification system 500 for power generation within the 504 Synthesis gas is the gas used to burn the turbine, and high-temperature turbine gas and high-temperature gas It further has a heat recovery generator to recover heat from the turbine gas, and generates steam, and additional It is sent via 504 for general power generation, driving steam turbines to generate electricity. Each gasifier It also produces metal-rich soot. The soot may be in the form of particulate solids, and is composed of crude oil and / or The solid contains metal contaminants derived from heavy feedstocks, and this solid is transmitted from each gasifier through line 506. It is supplied for metal removal. The support system includes one or more gas processing units. Whether all sulfur-containing gas flows from all unit operations are sour gases or acidic gases. Regardless of the above, the gas is supplied to the gas treatment unit via 508 for sulfur removal. Preferably, such a sulfur removal system includes a gasification system. It is part of the utility island. More preferably, one or more sulfur-containing The gaseous flow is directed towards industrial sulfur acid production as part of the overall sulfur removal process. Stem 500 typically uses at least one of the raw material synthesis gases produced within the gasification system. An acid gas removal unit optimized in capacity and configuration to generate the necessary hydrogen from a portion of the source. Includes to and sour CO shift systems.

[0087] In a modified example of the integrated hydrogenation treatment system 400 shown in Figure 2, the gasification system 500 is used to... The hydrogen-containing gas 502 for replenishment is the amount required for the hydrogenation process, within the hydrogenation block 400. Along with internally reused hydrogen, selected to achieve the desired level of desulfurization and demetallation. Effective hydrogenation, adjusted based on catalysts and other conditions known in the art. The process involves compressing and heating until the desired temperature, pressure, space velocity, and pressure are reached. The hydrogen 502 (along with recycled hydrogen) is first used in the high-pressure zone, which is the heavy oil hydrogenation zone. Located at 460. Heavy oil hydrogenation zone with hydrogenation liquid and hydrogen-containing gas. The 460 effluents are separated in a high-pressure separator (not shown), during which the liquids are separated into zo The hydrogen-containing liquid collected in line 460 is recovered and passes through line 410 to distillate water. It is sent to the chemical treatment device 430 and used for hydrogenation treatment in the low-pressure zone. Hydrogenation treatment Hydrogenated liquids and purge gases with sour and acidic gases from Zone 430 The oil passes through line 412 and enters heavy oil hydrogenation zone 460, where it is substantially mixed Combined. Hydrogenated treatment liquids 430 and 460 of both zones 430 and 460 0 is separated via lines 60 and 70, balancing sulfur and other substances in the process. Depending on the need, the fuels are either added separately to the combined fuel 600 or to the combined zone 60. It can be added or removed as a trim to control the sulfur level of 0 (Figure) (Not shown). In the illustrated modified integrated hydrogenation process, both zones 430 and 460 The Digas 420 is transmitted via line 420 to the sulfur recovery system and optionally to the gasification or bolus system. It is directed towards utility island 500, which has an iler. (Not shown in Figure 2) However, various auxiliary high, medium and low pressure gas-liquid separators, flow heaters, gas reuse and Purge line, reflux drum for separating gas or light components from liquid, compressor, Cooling systems and other auxiliary applications are available to those skilled in the field of hydrogenation technology. It is publicly known. Also, it is located within the hydrogenation zone, not within the common utility island. If located in the hydrogenation zone 400, sour gas or acid gas treatment is performed within the hydrogenation zone 400. The system may include various amines or other sulfur recovery agents, absorbents, and stripping systems.

[0088] Selection of hydrogenation catalyst and adjustment of process conditions for hydrogenation zone 400 The meter is within the technical scope of those skilled in the art engaged in the petroleum refining industry, and the hydrogenation treatment of the present invention No further explanation is required regarding the implementation of the classification. Distillate hydrogenation treatment apparatus 430 and heavy In the reaction zone of the oil hydrogenation treatment apparatus 460, the hydrogenation catalyst used has a hydrogen content. To increase and / or remove sulfur, nitrogen, oxygen, phosphorus and metallic heteroatomic pollutants Includes any catalyst composition useful for catalyzing the hydrogenation of hydrocarbon feedstocks for removal. The specific type of catalyst used, the various layer configurations, and the selected hydrogenation treatment conditions are , the hydrocarbon product composition of each feedstock processed by each unit, and sulfur and metal content and heavy carbon residue, as well as desired in the product flow from each zone The reduction depends on the sulfur and metal content. Such catalysts are used in the hydrogenation of hydrocarbon feedstocks. Any catalyst useful for the theory can be selected, but the operating conditions are those of a preferred embodiment of the present invention. In this case, the system is adjusted to avoid or minimize ring saturation or hydrogenation. See reference. More specifically incorporated herein, Patent Document 4 by Baldassari et al. describes various suitable In addition to hydrogenation catalysts, this article describes a suitable hydrogenation process that includes various integrated hydrogenation treatment devices. They have revealed that Baldassari et al. further describe various methods for distillation and heavy oil hydrotreatment. This document summarizes the catalyst compositions and condition ranges, and the conditions for hydrocracking and hydrogenation of the residue. This identifies the following. All of these are publicly known to those skilled in the art of hydrogenation. Non-patented. Reference 8 describes removing sulfur by hydrogenation and using a highly active Ni / Mo catalyst to remove sulfur. Unit design, catalyst selection, hydrogen consumption and other processes for producing products with a pH below ppm. Operating conditions are described. Non-patent document 9 by Shiflet et al. also discusses steric hindrance. A highly active CoMo catalyst for removing non-existent sulfur, and for removing residual sterically hindered sulfur. A hydrogenation treatment using a highly active NiMo catalyst to reduce the concentration to 10 ppm or less is described. ru.

[0089] In another variation shown in Figure 2, the sulfur content of the raw material 2 is an exponential function of the sulfur profile. It is measured by analysis that shows the typical dividing points and rate of increase. For example, 0.06 to 0.08 times Amount % (or the relative flow rates of untreated and hydrogenated steam and their respective sulfur content) Based on this, the boundary points and profiles of sulfur content in the range (higher than the amount) Using unstabilized, as-is straight-run naphtha 16 and sulfur delimiter point extraction. The adjustment of atmospheric distillation 100 is controlled to maximize the available amount of 18, and in doing so, the straight-run na The tufts 16 and sulfur delimiter points 18 are combined by fluid mixing or compounding. The product is available in product integration zone 600 without any flow or processing, and if necessary, (1) distillation Light distillates 24, intermediate distillates 26, and first heavy distillates 28 are also sent to the hydrogenation treatment zone 430. Alternatively, the amount of the second heavy distillate 32 flow, or (2) light oil to the heavy oil hydrogenation treatment device 460 The flow rate of vacuum diesel 36, heavy vacuum diesel 38, or deasphaltized oil 80 is measured. These flows are reduced, and these flows are produced in fuels where the actual sulfur content is below the target sulfur content limit. To form product 600, it is subjected to hydrogenation treatment in increased or decreased quantities. In the modified form, the analysis was performed on untreated, unstabilized, and natural straight-run naphtha 16 and untreated The maximum flow rate other than the sulfur delimiter extraction point 18 of the process is controlled, and the flow toward the hydrogenation process is controlled. Determine the amount and form fuel 600 in which the actual sulfur content is below the target sulfur content limit. It can be used for any (1) distillate hydrogenation treatment zone 430 Light distillate 24, intermediate distillate 26, first heavy distillate 28 or second heavy distillate 32 The amount of flow, or (2) light vacuum diesel 36 to the heavy oil hydrogenation treatment device 460, heavy vacuum diesel The amount of oil 38 or deasphaltized oil 80 flowing into the hydrogenation treatment 400 is various The flow rate is 600, and the effluent 60 of the hydrogenation treatment zone 400 is mixed with the untreated flow 10. The sulfur content of 70 or both can be increased or decreased to adjust the sulfur content. ru.

[0090] In one modified example, fuel product 600, whose actual sulfur content is below the target sulfur content limit, The actual final product is formed by adjusting the sulfur level of 600. The adjustment is a combination of Zone 600 may contain sulfur because (a) sulfur removal treatment has not been performed. , unstabilized, natural straight-run naphtha 16 or sulfur delimiter extraction 18, or (b) processed light distillate 24, intermediate distillate 26, first heavy distillate 28, second heavy The flow of distillate hydrogenation treatment equipment 430 such as distillate 32, or (c) treated Heavy oil hydrogenation treatments such as light vacuum diesel 36, heavy vacuum diesel 38, and deasphaltized oil 80 This is done by increasing or decreasing one or more amounts of the flow entering and leaving the apparatus. Here, such adjustments involve sulfur in a combination of 60 or 70 for each flow. It is based on measuring the relative contribution to the content.

[0091] In one embodiment, low metal content and target sulfur content below limit level are used for fuel 600. Light-tight oil or condensate having a sulfur content, or unassociated gas and sheath Combinations of light-tight oils such as aggregates for gas production are as follows, namely ( a) Feed material and distillate hydrogen for atmospheric distillation 100 or vacuum distillation 200, and solvent separation 300. Light distillate 24, intermediate distillate 26, first heavy distillate 28 or the first heavy distillate are added to the chemical treatment apparatus 430. Either of the two heavy distillates 32 can be used as raw materials for supplying the heavy oil hydrotreatment device 460. The raw material for supplying either compressed light oil 36, heavy vacuum light oil 38, or deasphaltized oil 80, (b) Unstabilized, natural straight-run naphtha 16 without any additional processing (c) Natural naphtha (d) Flow formed by a distillate hydrogenation treatment apparatus containing ultra-low sulfur diesel, In a heavy oil hydrogenation treatment system including naphtha, ultra-low sulfur diesel, and second-level reduced sulfur flow The resulting flow is (e) led to the final product fuel 600, combined with the hydrogenation unit. (f) Additions to form the final product fuel, in combination with 400 spills, or (f) Another fuel, which is added inside or outside the enclosure of the equipment that produces such fuel, Combine with one or more.

[0092] In one modified example shown in Figure 2, the sulfur content of fuel product 600 is (a) in combination 600 via line 10, unstabilized, as-is straight-run naphtha 16 and sulfur separators. To supply point extraction 18 without adding any further processing to such a flow, next Next, (b) the actual product with a sulfur level of 600 is sent to (1) the distillate hydrogenation treatment zone 430. The light distillate 24, the intermediate distillate 26, the first heavy distillate 28, or the second heavy distillate 32 Flow, (2) Light vacuum diesel 36, heavy vacuum diesel 38 or This involves increasing the amount of deasphaltized oil 80 in one or more combinations of flows or (c) Reduce and adjust the sulfur content of the actual product 600 for any reason. If it is necessary to raise the sulfur level to the target level, then (1) via line 60 to the combination The mixture consists of light distillate 24, intermediate distillate 26, first heavy distillate 28, or second heavy distillate 3. The flow from the distillate hydrogenation treatment zone 430 formed from 2, via line 70 Formed from light vacuum diesel 36, heavy vacuum diesel 38, and deasphaltized oil 80. , reducing the amount of one or more of the flow from the heavy oil hydrogenation treatment zone 460, (d) For any reason reduce the sulfur content of the actual product 600 to the target sulfur level. If necessary, the distillate hydrogenation treatment zone via (1) line 60 to the combination The above flow from 430, (2) via line 70, from the heavy oil hydrogenation treatment zone 460 By increasing the amount of one or more of the above steps, the target sulfur content limit level can be reached. The following is controlled. Such acceleration allows for, for example, offshore and onshore gas turbines. Fuel supply targeting less than 500 ppm by weight of sulfur, or different target sulfur content Efficiently utilizing multiple sulfur grades, such as various ranges for the same application in different locations. It can be manufactured.

[0093] Sulfur content higher than the target sulfur content limit level for the final fuel in combination 600 In a modified example of the use of high-sulfur fuel oil having one or more different supplies, the high-sulfur fuel oil is used. It is supplied as part of the fuel supply to one or more of the respective unit operations. High-sulfur fuel oil (a) to supply line 2 to atmospheric distillation 100 or line 30 to vacuum distillation 200, or (b) to line 50 to solvent separation 300, or (c) separately, or the above distillate Light distillate 24, intermediate distillate 26, and first heavy distillate 26 to the hydrogenation treatment apparatus 430 The second heavy distillate 32 is combined with one or more of the supply raw materials and subjected to distillate hydrogenation treatment. To line 20 to device 430, or (d) separately, or light vacuum gas oil 36, heavy vacuum gas oil Combined with one or more of compressed light oil 38 and deasphaltized oil 80, heavy oil hydrogen The sulfur is added to line 40 of the chemical treatment device 460, and the actual sulfur content is below the target sulfur content limit. The following fuel combination 600 can be formed. As a raw material for supplying high-sulfur fuel oil. In one or more implementations of these modifications relating to the use and selection of supply points , the properties of the supply of high-sulfur fuel oil, such as its sulfur content and asphaltene content, and Other factors relating to compatibility with co-processed crude oil or other supply materials, container space and Energy consumption, asphaltene content, undissolved component content, gum formation, and other factors. The consideration of efficiency issues is well known to those skilled in the art of purification technology.

[0094] In other modifications, the clean fuel in the 600 zone of the combination is the actual sulfur content of the 600 fuel. To ensure that the amount is below the target sulfur content limit, sulfur content higher than the target sulfur content limit level is used. (a) High-sulfur fuel oil that may have a sulfur content, by the sulfur content of the high-sulfur fuel oil This is unstabilized, natural straight-run naphtha 16, with no further processing added. and the flow 10 formed from the sulfur delimiter extraction 18, or (b) the natural Formed by a distillate hydrogenation treatment apparatus 430 containing fusa and ultra-low sulfur diesel range substances. Flow 60, or (c) natural naphtha, ultra-low sulfur diesel and second-low sulfur Flow 70 or hydrogenation zone formed from the heavy oil hydrogenation treatment device 460, including the yellow flow. Formed by adding one or more of the combined effluents 70 from 400 ru.

[0095] In one preferred modification, in which high-sulfur fuel oil is used to prepare the fuel composition 600, such The sulfur content of the high-sulfur fuel oil is measured, and then the high-sulfur fuel oil is used as part of the raw material 50. It is supplied to the solvent separation unit to form part of the deasphaltized oil flow 80, or to supply As part of the feed material 20, light distillate 24, intermediate distillate 26, first heavy distillate 26 or Combined with one or more distillation streams of the second heavy distillate 32, the distillate hydrogenation treatment The light vacuum gas oil 36, heavy vacuum gas oil 38, and de-asphalt are supplied to the processing device 430, or the light vacuum gas oil 36, heavy vacuum gas oil 38, and de-asphalt. One or more of the heavy oil flows of the phalt oil 80, or both the distillation flow and the heavy oil flow. Combined, depending on the sulfur content of the high-sulfur fuel oil, the distillate hydrogenation treatment device 430 also The heavy oil hydrogenation treatment device 460, or a portion of the raw materials supplied to both, is formed in Zone 43 Optimize the adjustment of hydrogenation conditions at 0 or 460, or adjust both zones to achieve the actual The fuel is formed with a sulfur content below the target sulfur content limit.

[0096] In another embodiment of the present invention, a clean fuel whose specifications are below the sulfur content limit is typically It is atmospheric pressure residue or heavier and is outside the specifications of high-sulfur fuel oil or within standard specifications. Use of heavy residue oils, including high-sulfur fuel oils which may have density or sulfur or metal content. It can be formed by [this]. Due to market considerations, such heavy residue oils They are often available from sources other than the battery limits of the fuel plant. Heavy residues with a sulfur content higher than the target sulfur content limit level for Fuel 600 are subject to the following regulations. Below, that is, (a) a vacuum distillation column 200, which is at atmospheric pressure, either separately or via line 30. The residue is combined with the distillation column 200 and supplied with the second heavy distillate 32, light vacuum gas oil 36, To produce heavy vacuum diesel fuel or vacuum residue 50, or at least a portion of either or all of them. (b) an atmospheric distillation column 200, or (b) a solvent separation 300, which can be used separately or in line 50 Combined with the reduced-pressure residue supplied to the solvent separation 300 via this, deasphaltized oil 80, or gas for gasification, sulfur recovery and other auxiliary treatments Solvent components that form pitch 90 having metal-rich heavy residue that passes into chemical system 500 It is supplied to one or more of the 300. Such heavy residue oil is also a utility. Even when combined with pitch via line 90 as a supply to Island 500 Good. A modified example involves a trimming process to adjust the sulfur content of the fuel 600 of the present invention. Therefore, untreated products with a relatively high sulfur content (exceeding 0.5% by weight) or high metal content are not available. When using high-sulfur fuel oil, such use is a combination of 600 and a target sulfur content. If used without processing to ensure that the quantity limit is not exceeded, relatively small This will be the adjustment amount.

[0097] The flowsheet in Figure 2, which shows various intermediate individual products, illustrates the efflux of each unit operation depicted. This is for the explanation and understanding of the major products and by-products in a substance. Selected variations in separation or processing by the process include selected crude oil and feedstock, as well as It depends on optimizing the intermediate products produced to manufacture fuel below the target sulfur specification. For example, the ultra-low diesel generated within Zone 430 is not filtered and all hydrogenated When the substances are combined in line 70 as shown in Figure 2, a common gas-liquid separator is used. By using (not shown), the effluent 60 from the hydrogenation treatment apparatus 430 and 460 Both of the 70 can be combined within the hydrogenation treatment zone 400, and only the gas is removed. Alternatively, trim control of the sulfur content of the fuel in the final combination zone 600. This is for the separation or removal of some of the natural naphtha or ultra-low sulfur diesel for other reasons. If removal is for process purposes, the effluent 60 from the hydrogenation treatment equipment 430 and 460 The 70 can remove the fraction of natural naphtha or ultra-low sulfur diesel. They may be sent to a stripper or distillation column separately or in combination.

[0098] Although various embodiments of the present invention have been described, these are merely illustrative and not limiting. This should be understood. For example, if the flash point of the fuel is not taken into consideration, a low metal content is a factor. and untreated lighttight oil or solids having a sulfur content below the target sulfur content. Combinations of shrinkage, or untreated lighttight oil or condensate, are the same as the untreated oil mentioned above. It is added as part of the combination of the fraction and the above processing flow, and the actual sulfur content is the target sulfur. Forms fuel with a content below the specified limit. "Light Tight Oil" or The term "LTO" refers to (i) a sulfur content in the range of 0.1% to 0.2% by weight, and (ii) density in the range of 38 to 57 degrees in API (degrees), and (iii) based on the source. LTO refers to source condensates or shale gas condensates containing a wide range of hydrocarbons. Typically, this is expressed as (a) 5-20% by weight of liquefied petroleum gas relative to the total amount. (b) 10-35% by weight naphtha, (c) 15-30% by weight kerosene, (d) 15-25 (e) diesel by weight %, vacuum diesel, and (f) zero (0%) to 10% by weight heavy residues. The residue has overlapping fractional ranges for the expected distillate extraction.

[0099] In one modified example, the present invention provides (i) for example, that available oil is used in the combustion production plant of the present invention If the production location is outside the battery limit, untreated light tight oil or condensate Crude oil of a certain quality, or a combination of light-tight oil or condensate, and (ii) ) Co-processing with one or more other crude oil supply materials by the method of the present invention, resulting in low metal content To produce low-cost fuel with a sulfur content that is high and below the target sulfur content. Itotite crude oil is highly likely to not contain sufficient heavy hydrocarbons in its bottom fraction (for example) If the residue is 0% or very low (heavy residue), the range of residue is due to desulfurization or other hydrogenation treatments. It does not offer a processing balance, and the corresponding residue is also costly for such light-tight crude oil. Hydrogenate in a cost-effective manner to reduce sulfur and metals and decontaminate, or sufficiently It provides lubrication and supports the hydrogen production process to enable use in certain types of engines. It is not enough.

[0100] Embodiments of the novel fuel of the present invention are based on ISO standards published by the International Organization for Standardization (ISO). It can be better understood by referring to the 8217 standard. ISO 8217 includes onboard... A series of categories and detailed specifications of marine residual fuels for consumption are described. The specifications are based on the fact that crude oil supply, refining methods, and other conditions vary considerably as they form the basis for their development. It is recognized that it moves. Such specifications are related to properties such as sulfur content. This suggests that various international requirements have been taken into consideration. Currently, ISO 82 is the most stringent standard. 17 is RMA10, and the interpretation of the specification and claims should be based on it. Simulated composition of a new fuel (crude oil is divided into fractions, a portion of which is hydrogenated and then separated by solvent). A simulation to remove non-solvent residues and then reconstruct the untreated and treated sections. Based on the ration model, these new fuels, except for their flash point, are different. All ISO RMA10 specifications are met and / or exceeded, and the flash point is as per the cargo The fuel falls under the SOLAS exception for the flash point requirements for ships, and these new fuels are as described above. The inventors have demonstrated that the product has novel features and improvements that distinguish it from marine fuel consisting of residues. To assert.

[0101] In one modification, the inventors have found that all ISO RMA10 (ISO2) standards are met except for the flash point. 817-10) Meets or exceeds the specifications and has the following notable features, namely (a) 0 0.50% m / m (weight%) or less, preferably in the range of 0.05 to 0.20 m / m (weight%) (b) Sulfur content, (b) 5.0 mg / kg (ppm by weight) or less, preferably 1.0 mg / kg (1.0 ppm by weight) or less, for example, 0.2 mg / kg (0.2 ppm by weight) of metal, (c) Flash point below 60°C, and other features superior to other ISO RMA10 specifications, To provide an improved fuel having any or all of the following: In a modified example, these novel fuels Furthermore, it has the following notable characteristics: (a) viscosity of 10 cSt or less, (b) Pour point below 0°C, (c) 820~880 kg / M 3 Density within the range, (d) 80 CCAI of 0 or less, (e) 20 mg / kg or less, preferably 10 mg / kg or less of sodium Having one or more of the above. All of the above are defined by ISO 2817-10. It is measured by the test or calculation method that has been established. Such fuels have an initial boiling point of naphtha and Among the components soluble in solvents suitable for solvent separation such as heptane, the component with the highest boiling point It contains a series of hydrocarbons with the highest boiling point. The metal is adjusted in terms of the composition of the raw materials and the operating conditions. Depending on the method, it can be reduced to 100 ppb by weight.

[0102] The inventors have identified sulfur and metals that fall under the SOLAS exception to the flash point requirements for cargo ships. They discovered that they could produce extremely small quantities of fuel at low cost. For other uses, flash point treatment... If ignition is required, it has a flash point of 60°C or higher, or for such requirements Point processing is well known in the relevant technical field.

[0103] By using the low viscosity, low pour point fuel of the present invention in marine engines, the addition of normal residual oil can be reduced. To avoid or reduce the energy consumption required in relation to heat, and at refueling stations within ports This enables pumping and handling at sea. Heavy residue oil is concentrated and has a relatively high pour point. Due to its high viscosity, all aspects of its storage, pumping, and supply to marine engines are challenging. It needs to be heated and kept at a high temperature, and such heating consumes energy.

[0104] Table 1 below shows two variations of the fuel of the present invention, namely, an extremely low sulfur content of 0.1% by weight. The content is shown as a whole, and also as a further reduced level of 0.05% by weight, according to ISO RM standards. Table 1 below shows the sulfur content compared to A10.

[0105] [Table 1] TIFF0007855333000002.tif111170

[0106] Such fuels of the present invention, having the characteristics shown in Table 1, range from C3 or C5 to C20 or higher. It is further distinguished in that it comprises substantially the entire range of hydrocarbons derived from crude oil, and the hydrocarbons have The initial boiling point is the lowest of the boiling points of any fraction of the above crude oil under atmospheric pressure distillation conditions. The highest boiling point is the endpoint of the residual portion of the crude oil that does not dissolve in the solvent suitable for solvent separation. In contrast, the residue consists of vacuum distillation residue, solvent deasphaltization residue, other cokers, etc. It does not contain a wide range of hydrocarbons like those mentioned above, and is limited to only very heavy substances.

[0107] From the disclosures of this specification and the claims, the present invention relates to current marine reciprocating engines. Not only does it meet or exceed the compliance standards, but it also has advanced combustion gas turbidity suitable for marine applications. It enables the production of ultra-clean fuels that are also compatible with advanced turbine engines. These are currently available, but are typically for land use. Once activated on board, the fuel of this invention burns during the voyage, thereby preventing corrosion. Alternatively, it can have significant efficiency advantages while minimizing ash formation. Also, in ports Depending on the available fuel economy, ships may burn these new fuels in port to generate electricity. By sending electricity to the local power grid and generating revenue, they can gain efficiency advantages. Yes, it is possible. The revenue from such port power generation offsets offshore fuel costs, and the offshore fuel costs for ships The actual total can be reduced to less than that of high-sulfur fuel oil, and therefore the low-sulfur fuel of the present invention Even if the sailing fuel is more expensive, the cost of using it will be offset. The benefits are environmental, and in comparisons of specific normative cases, SOx and NO It is possible to reduce x emissions by more than 95%, potentially reducing the emission of harmful metals during voyages. This can be reduced by more than 99% (almost 100%). Furthermore, the environment will benefit from CO2 reduction. There are two types of benefits, namely (i) the efficiency of the ship's advanced gas turbine engine, and (ii) ) To improve the efficiency of power generation in ports, and to reduce the inefficiency of coal, crude oil, residual oil, or certain other fuels. This type of combustion will be replaced. [Industrial applicability]

[0108] Thus, the present invention relates to the production of fuels with reduced levels of sulfur and other contaminants. It is widely applicable to the use of such fuels. Certain features are from the spirit or scope of the invention. The present invention may be modified without departing from the described specific embodiments. This is not limited to the examples provided, but is substantially equivalent to the claims or the attached claims. It is limited to things that are essentially equivalent.

Claims

1. A liquid fuel, and said fuel (a) Hydrogenation flows of liquid fractions above the sulfur boundary of one or more crude oils alone, or one or more crude oils in combination with one or more high-sulfur fuel oils or other heavy residual oils, or one or more crude oils in combination with light-tight oil; and (b) Untreated liquid fractions below the sulfur boundary of one or more crude oils alone, or one or more crude oils combined with one or more high-sulfur fuel oils or other heavy residual oils, or one or more crude oils combined with light-tight oils, The fuel does not contain any insoluble residues in one or more solvents used for solvent separation, and the highest boiling point of the fuel is the highest boiling point of the hydrogenation treatment flow combined with the fuel. The fuel is characterized in that the aforementioned boundary point is determined by referring to the analysis of the crude oil supply, and at the boundary point, the change in sulfur content with respect to the change in mass percent or volume is in the range of 0.2 to 1.

2. The fuel according to claim 1, comprising a combination of hydrocarbons ranging from the lowest boiling point component of the untreated liquid fraction to the highest boiling point component of the hydrogen-treated deasphalt-soluble product obtained by solvent separation with a liquid solvent containing propane or other paraffinic solvents including butane or pentane, and which range from the lowest boiling point component of the untreated liquid fraction to the highest boiling point component of the deasphalt-soluble product.

3. The fuel according to claim 1, comprising a hydrogenated ultra-low sulfur flow having 10 ppm by weight or less of sulfur.

4. The fuel according to claim 1, comprising a first hydrogenation treatment flow which is a reduced sulfur flow having a sulfur content of less than 10 ppm by weight, and a second hydrogenation treatment fuel fraction which is a reduced sulfur flow having a sulfur content in the range of 0.12 to 0.18% by weight, wherein the untreated fraction has a sulfur content exceeding the target sulfur content, a sulfur content at the target sulfur content, or a sulfur content below the target sulfur content.

5. The fuel according to claim 1, having a target sulfur content of 0.5% by weight or less.

6. The lighttight oil or condensate, or a combination of lighttight oil and condensate, comprises one or more untreated fractions and a hydrotreatment stream, wherein the lighttight oil has a sulfur content in the range of 0.1% to 0.2% by weight and an API (degrees) density in the range of 37 to 67 degrees, and the condensate comprises untreated lighttight oil, or source condensate, unassociated gas and condensate for shale gas production. The fuel according to claim 1, having a distillate fraction range on a weight basis of (a) 5 to 20% by weight of liquefied petroleum gas, (b) 10 to 35% by weight of naphtha, (c) 15 to 30% by weight of kerosene, (d) 15 to 25% by weight of diesel oil, (e) vacuum diesel oil, and (f) zero (0%) to 10% of heavy residue.

7. The fuel according to claim 1, comprising a hydrocarbon having an initial boiling point in the range of about 35°C to about 315°C and a maximum boiling point higher than about 315°C, wherein the maximum boiling point is the endpoint of the deasphaltized oil belonging to the range of the fuel, and is the initial boiling point of the deasphaltized residue that does not dissolve in the solvent selected for solvent separation and does not belong to the range of the fuel.

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