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    • 专利摘要:
    The invention relates to a process for converting a hydrocarbon feedstock, said process comprising the following steps: a) a step of hydrocracking the feedstock in the presence of hydrogen, b) a step of separating the effluent obtained at the outcome of step a), c) a sediment precipitation step in which the heavy fraction resulting from separation step b) is brought into contact with a distillate cut of which at least 20% by weight has a temperature boiling point greater than or equal to 100 ° C, for a period of less than 500 minutes, at a temperature of between 25 and 350 ° C, and a pressure of less than 20 MPa, d) a stage of physical separation of the sediments from the fraction heavy step from step c), e) a step of recovering a heavy fraction having a sediment content, measured according to the ISO 10307-2 method, less than or equal to 0.1% by weight.
    公开号:FR3036703A1
    申请号:FR1554962
    申请日:2015-06-01
    公开日:2016-12-02
    发明作者:Wilfried Weiss；Isabelle Merdrignac；Jeremie Barbier；Ann Forret
    申请人:IFP Energies Nouvelles IFPEN；
    IPC主号:
    专利说明:

    [0001] The present invention relates to the refining and conversion of heavy hydrocarbon fractions containing, inter alia, sulfur impurities. It relates more particularly to a process for converting heavy petroleum feeds of the atmospheric residue type and / or vacuum residue for the production of heavy fractions that can be used as fuel bases, in particular bunker oil bases, with a low sediment content. The process according to the invention also makes it possible to produce atmospheric distillates (naphtha, kerosene and diesel), vacuum distillates and light gases (Cl to C4). The quality requirements for marine fuels are described in ISO 8217. The sulfur specification now addresses SO emissions (Annex VI of the MARPOL Convention of the International Maritime Organization) and results in a recommendation for sulfur content not exceeding 0.5% by weight outside the Sulfur Emission Control Areas (ZCES or Emissions Control Areas / ECA) by 2020-2025 and less than or equal to 0,1% in ZCES. According to Annex VI of the MARPOL Convention, the sulfur contents mentioned above are equivalent contents leading to SOx emissions. A ship will therefore be able to use a sulfur fuel oil if the vessel is equipped with a flue gas treatment system that reduces sulfur oxide emissions. Another very restrictive recommendation is the sediment content after aging according to ISO 10307-2 (also known as IP390) which must be less than or equal to 0.1%. The sediment content after aging is a measurement carried out according to the method described in the ISO 10307-2 standard (also known to those skilled in the art under the name of IP390). In the rest of the text will therefore read "sediment content after aging", the sediment content measured according to the ISO 10307-2 method. The reference to IP390 will also indicate that the measurement of the sediment content after aging is performed according to the ISO 10307-2 method. The sediment content according to ISO 10307-1 (also known as IP375) is different from the sediment content after aging according to ISO 10307-2 (also known as IP390). The sediment content after aging according to 180 10307-2 is a much more stringent specification and corresponds to the specification for bunker fuels.
    [0002] On the other hand, terrestrial fuel oils, in particular fuel oils that can be used for producing heat and / or electricity, may also be subject to stability specifications, in particular maximum sediment contents, the thresholds of which vary according to the locations because there is no international harmonization as in the case of maritime transport. There is, however, an interest in reducing the sediment content of terrestrial fuel oils. Residue hydrocracking processes convert low value residues to higher value added distillates. The resultant heavy fraction corresponding to the unconverted residual cut is generally unstable. It contains sediments that are mainly precipitated asphaltenes. This unstable residual cut can not therefore be valorized as fuel oil, especially as bunker oil without a specific treatment since the hydrocracking is operated under severe conditions leading to a high conversion rate. US Pat. No. 6,447,671 describes a process for the conversion of heavy petroleum fractions comprising a first bubbling bed hydrocracking step, a step of removing the catalyst particles contained in the hydrocracking effluent, and then a step of hydrotreating into fixed bed. The US2014 / 0034549 application describes a residue conversion process using a bubbling bed hydrocracking step and a step with an upflow reactor associated with a so-called "stripper" reactor. The sediment content of the final effluent is reduced relative to the effluent of the bubbling bed stage. However, the sediment content after aging is not less than 0.1% by weight, as required for marketing as a residual type marine fuel. FR 2981659 discloses a process for converting heavy petroleum fractions comprising a first bubbling bed hydrocracking step and a fixed bed hydrotreating step comprising permutable reactors. The hydrocracking process partially converts heavy feeds to produce atmospheric distillates and / or vacuum distillates. Although ebullated bed technology is known to be suitable for heavy loads loaded with impurities, the bubbling bed inherently produces catalyst fines and sediments which must be removed to satisfy product quality such as fuel oil. of 3036703 3 hold. The fines come mainly from the attrition of the catalyst in the bubbling bed. The sediments may be precipitated asphaltenes. Initially in the feedstock, the hydrocracking conditions and in particular the temperature cause them to undergo reactions (dealkylation, polycondensation, etc.) leading to their precipitation. These phenomena generally occur during implementation of severe conditions giving rise to conversion rates (for compounds boiling above 540 ° C: 540 + ° C), for example greater than 30, 40 or 50% depending of the nature of the charge. The Applicant's research has developed a novel method incorporating a step of precipitation and physical separation of sediments downstream of a hydrocracking step. Surprisingly, it has been found that such a method makes it possible to obtain heavy fractions having a low sediment content after aging, said heavy fractions being advantageously able to be used wholly or partly as fuel oil or as a fuel oil base, especially as bunker oil or bunker oil base meeting the specifications, namely and a sediment content after aging (measured according to the ISO 10307-2 method) less than or equal to 0.1% by weight. An advantage of the method according to the invention is to avoid in particular the risk of clogging of boat engines. Another advantage of the process of the invention is to avoid the risk of fouling, in the case of possible processing steps carried out downstream of the hydrocracking step of avoiding clogging of the bed or beds (s) catalytic (s) implemented. More particularly, the invention relates to a process for converting a hydrocarbon feedstock containing at least one hydrocarbon fraction having a sulfur content of at least 0.1% by weight, an initial boiling temperature of at least 340 ° C and a final boiling temperature of at least 440 ° C, said process comprising the following steps: a) a step of hydrocracking the feedstock in the presence of hydrogen in at least one reactor containing a supported catalyst; bubbling bed, b) a step of separating the effluent obtained at the end of step a) into at least a light fraction of hydrocarbons containing fuels bases and a heavy fraction containing compounds boiling at least 350 ° C, 3036703 4 c) a sediment precipitation step in which the heavy fraction resulting from the separation step b) is brought into contact with a distillate cut of which at least 20% by weight has a boiling temperature above less than or equal to 100 ° C, for a period of less than 500 minutes, at a temperature between 25 and 350 ° C, and a pressure of less than 20 MPa, d) a step of physically separating the sediments of the heavy fraction from step c) of precipitation to obtain a heavy fraction separated from the sediments, e) a step of recovering a heavy fraction having a sediment content, measured according to the ISO 10307-2 method, less than or equal to 0.1% by weight of separating the heavy fraction from step d) of the distillate cut introduced in step c). In order to form the fuel oil that meets the viscosity and sediment content requirements after aging, the heavy fractions obtained by the present process can be mixed with fluxing bases so as to achieve the target viscosity of the desired fuel grade as well as specification in sediment content after aging. Another point of interest of the process is the partial conversion of the feedstock making it possible to produce, especially by hydrocracking, atmospheric distillates or vacuum distillates (naphtha, kerosene, diesel, vacuum distillate), which can be upgraded as b2ses in 20 fuels pools directly or after passing through another vitrification process such as hydrotreating, reforming, isomerization, hydrocracking or catalytic cracking. FIG. 1 illustrates a schematic view of the process according to the invention showing a hydrocracking zone, a separation zone, a precipitation zone, a physical separation zone of the sediments and a zone of recovery of the fraction of water. 'interest. DETAILED DESCRIPTION The feedstocks treated in the process according to the invention are advantageously chosen from atmospheric residues, vacuum residues from direct distillation, crude oils, crude oils, deasphalted oils, deasphalting resins, asphalts or deasphalting pitches, residues resulting from conversion processes, aromatic extracts from lubricant base production lines, oil sands or their derivatives, oil shales or their derivatives, taken alone or as a mixture. These fillers can advantageously be used as they are or else diluted by a hydrocarbon fraction or a mixture of hydrocarbon fractions which may be chosen from products resulting from a fluid catalytic cracking process (FCC according to the initials of the English name of "Fluid Catalytic Cracking"), a light cutting oil (LCO), a heavy cutting oil (HCO), a decanted oil (OD according to the initials of the English name "Decanted Oil"), a residue of FCC, or possibly derived from distillation, gas oil fractions including those obtained by atmospheric or vacuum distillation, such as vacuum gas oil. The heavy feeds may also advantageously comprise cuts resulting from the liquefaction process of coal or biomass, aromatic extracts, or any other hydrocarbon cuts, or else non-petroleum feedstocks such as pyrolysis oil from lignocellulosic biomasses. The fillers according to the invention generally have a sulfur content of at least 0.1 wt%, an initial boiling temperature of at least 340 ° C and a final boiling temperature of at least 440 ° C, preferably a final boiling temperature of at least 540 ° C. Advantageously, the feedstock may contain at least 1% C7 asphaltenes and at least 5 ppm metals, preferably at least 2% C7 asphaltenes and at least 25 ppm metals. The fillers according to the invention are preferably atmospheric residues or residues under vacuum, or mixtures of these residues. The filler according to the invention is subjected to a hydrocracking step which is carried out in at least one reactor containing a catalyst supported in a bubbling bed and preferably operating with an upward flow of water. liquid and gas. The objective of the hydrocracking step is to convert the heavy fraction into lighter cuts while partially refining the charge.
    [0003] 3036703 6 The ebullated bed technology being widely known, only the main operating conditions will be repeated here. Bubbling bed technologies use extruded bed catalysts supported in the form of extrudates, the diameter of which is generally of the order of 1 mm or less than 1 mm. The catalysts remain inside the reactors and are not evacuated with the products. The temperature levels are high in order to obtain high conversions while minimizing the amounts of catalysts used. The catalytic activity can be kept constant by replacing the catalyst in line. There is therefore no need to stop the unit to change the spent catalyst, nor to increase the reaction temperatures along the cycle to compensate for deactivation. In addition, operating at constant operating conditions provides consistent yields and product qualities along the cycle. Also, because the catalyst is kept agitated by a large recycling of liquid, the pressure drop on the reactor remains low and constant.
    [0004] The conditions of hydrocracking step a) in the presence of hydrogen are usually conventional bubbling bed hydrocracking conditions of a liquid hydrocarbon fraction. It is advantageously carried out under a hydrogen partial pressure of 5 to 35 MPa, often 8 to 25 MPa and usually 12 to 20 MPa at a temperature of 330 to 500 ° C and often 350 to 450 ° C. The hourly space velocity (VVH) and the hydrogen partial pressure are important factors that are chosen according to the characteristics of the product to be treated and the desired conversion. The VVH, defined as the volumetric flow rate of the feed divided by the total volume of the reactor, is generally in a range of from 0.05 hr -1 to 5 hr -1, preferably from 0.1 hr -1 to 2 h -1 and more preferably 0.2 h -1 to 1 h -1. The amount of hydrogen mixed with the feed is usually 50 to 5000 Nm 3 / m 3 (normal cubic meters (Nm 3) per cubic meter (m 3) of liquid feed) and most often 100 to 1000 Nrin 3 / m 3 and preferably from 200 to 500 Nrn3 / m3. A conventional hydrocracking granular catalyst comprising, on an amorphous support, at least one metal or metal compound having a hydro-dehydrogenating function can be used. This catalyst may be a catalyst comprising Group VIII metals, for example nickel and / or cobalt, most often in combination with at least one Group VIB metal, for example molybdenum and / or tungsten. For example, a catalyst comprising from 0.5 to 10% by weight of nickel and preferably from 1 to 5% by weight of nickel (expressed as nickel oxide NiO) and from 1 to 30% by weight of nickel may be used. molybdenum preferably 5 to 20% by weight of molybdenum (expressed as molybdenum oxide MoO 3) on an amorphous mineral support. This support will for example be chosen from the group formed by alumina, silica, silica-aluminas, magnesia, clays and mixtures of at least two of these minerals. This support may also contain other compounds and for example oxides chosen from the group formed by boron oxide, zirconia, titanium oxide and phosphoric anhydride. Most often, an alumina support is used and very often an alumina support doped with phosphorus and optionally boron. When phosphorus pentoxide P205 is present, its concentration is usually less than 20% by weight and most often less than 10% by weight. The concentration of boron trioxide B 2 O 3 is usually from 0 to 10% by weight. The alumina used is usually a gamma or eta alumina. This catalyst is most often in the form of extrudates. The total content of Group VI and VIII metal oxides is often from 5 to 40% by weight and generally from 7 to 30% by weight and the weight ratio of metal oxide (or metals) to group VI on metal (or metals) of group VIII is generally from 20 to 1 and most often from 10 to 2. The used catalyst is partly replaced by fresh catalyst, generally by withdrawal at the bottom of the reactor and introduction at the top of the reactor fresh or new catalyst at regular time interval, that is to say for example by puff or almost continuously. The catalyst can also be introduced from below and withdrawn from the top of the reactor. For example, fresh catalyst can be introduced every day. The replacement rate of spent catalyst with fresh catalyst may be, for example, from about 0.05 kilograms to about 10 kilograms per cubic meter of charge. This withdrawal and this replacement are carried out using devices allowing the continuous operation of this hydrocracking step. The unit usually comprises a recirculation pump for maintaining the bubbling bed catalyst by continuously recycling at least a portion of the liquid withdrawn at the top of the reactor and reinjected at the bottom of the reactor. It is also possible to send the spent catalyst withdrawn from the reactor into a regeneration zone in which the carbon and the sulfur contained therein are removed before being reinjected in the hydrocracking step a). Most often the hydrocracking step a) is carried out under the conditions of the H-OILO process as described for example in US Pat.
    [0005] Hydrocracking can be carried out in a single reactor or in a plurality of reactors (usually two) arranged in series. The use of at least two ebullated bed reactors in series makes it possible to obtain products of better quality and with a better yield, thus limiting the energy and hydrogen needs in possible post-treatments. In addition, the hydrocracking into two reactors makes it possible to have improved operability in terms of the flexibility of the operating conditions and of the catalytic system. Generally, the temperature of the second reactor is preferably at least 5 ° C higher than that of the first bubbling bed reactor. The pressure of the second reactor is 0.1 to 1 MPa lower than for the first reactor to allow the flow of at least a portion of the effluent from the first step without pumping being necessary. The different operating conditions in terms of temperature in the two hydrocracking reactors are selected to be able to control the hydrogenation and the conversion of the feedstock into the desired products in each reactor. Optionally, the effluent obtained at the end of the first hydrocracking reactor is separated from the light fraction and at least a portion, preferably all, of the residual effluent is treated in the second reactor. hydrocracking. This separation can be carried out in an inter-ethanol separator, as described in US Pat. No. 6,270,654, and in particular makes it possible to avoid excessive hydrocracking of the light fraction in the second hydrocracking reactor.
    [0006] It is also possible to transfer all or part of the used catalyst withdrawn from the first lower temperature hydrocracking reactor directly into the hydrolysis reactor, operating at a higher temperature, or to transfer all or part of the hydrocracking reactor. in part the used catalyst withdrawn from the second hydrocracking reactor directly to the first hydrocracking reactor. This cascade system is described in US4816841. The hydrocracking step may also be carried out in at least one reactor operating in a hybrid bed mode, that is to say operating in a bubbling bed with a supported catalyst associated with a dispersed catalyst consisting of very fine catalyst particles. forming a suspension with the charge to be treated.
    [0007] A hybrid bed has two populations of catalyst, a population of bubbling bed catalyst to which is added a population of "dispersed" type catalyst. The term "dispersed" refers to an implementation of the reactor in which the catalyst is in the form of very fine particles, that is to say generally a size of between 1 nanometer (ie 10-9 m) and 150 microns, of preferably between 0.1 and 100 microns, and even more preferably between 10 and 80 microns. In a first variant, the hydrocracking step may comprise a first bubbling-bed type reactor followed by a second hybrid bed-type reactor (that is to say of the bubbling bed type with "dispersed" type catalyst injection). ). In a second variant, the hydrocracking step may comprise a first hybrid bed type reactor followed by a second hybrid type reactor. In a third variant, the hydrocracking step may comprise a single hybrid bed type reactor. The "disperse" catalyst used in the hybrid bed reactor may be a sulfide catalyst preferably containing at least one member selected from the group consisting of Mo, Fe, Ni, W, Co, V, Ru. These catalysts are generally monometallic or bimetallic (by combining, for example, a non-noble group VIIIB element (Co, Ni, Fe) and a group VIB element (Mo, W) .The catalysts used may be heterogeneous solid powders (such as natural ores, iron sulphate, etc.), dispersed catalysts derived from water-soluble precursors such as phosphomolybdic acid, ammonium molybdate, or a Mo oxide mixture or Neither with aqueous ammonia The catalysts used are preferably derived from soluble precursors in an organic phase (oil-soluble catalysts) .The precursors are generally organometallic compounds such as the naphthenates of Mo, Co, Fe, or Ni, or the Mo octoates, or multicarbonyl compounds of these metals, for example 2-ethyl hexanoates of Mo or Ni, acetylacetonates of Mo or Ni, C7-C12 fatty acid salts of Mo or W , etc. They can be ut in the presence of a surfactant to improve the dispersion of the metals, when the catalyst is bimetallic. The catalysts are in the form of dispersed particles, colloidal or otherwise depending on the nature of the catalyst. Such precursors and catalysts that can be used in the process according to the invention are widely described in the literature. In general, the catalysts are prepared before being injected into the feed. The process of preparation is adapted according to the state in which the precursor is located and of its nature. In all cases, the precursor is sulfided (ex-situ or in-situ) to form the catalyst dispersed in the feedstock. For the case of so-called oil-soluble catalysts, the precursor is advantageously mixed with a carbonaceous feedstock (which may be a part of the feedstock to be treated, an external feedstock, a recycled fraction, etc.), the mixture is then sulphurized by adding a sulfur compound (preferred hydrogen sulphide or optionally an organic sulphide such as DMDS in the presence of hydrogen) and heated. The preparations of these catalysts are described in the literature. The "dispersed" catalyst particles as defined above (powders of metallic mineral compounds or of precursors soluble in water or in oil) generally have a size of between 1 nanometer and 150 microns, preferably between 0.1 and 100 microns, and even more preferably between 10 and 80 microns. The content of catalytic compounds (expressed as weight percentage of metal elements of group VIII and / or of group VIB) is between 0 and 10% by weight, preferably between 0 and 1% by weight.
    [0008] Additives may be added during the preparation of the catalyst or the "dispersed" catalyst before it is injected into the reactor. These additives are described in the literature. The preferred solid additives are inorganic oxides such as alumina, silica, mixed Al / Si oxides, supported spent catalysts (for example, on alumina and / or silica) containing at least one group VIII element (such as Ni, Co) and / or at least one Group VIB element (such as Mo, W). For example, the catalysts described in the application US2008 / 177124. Carbonaceous solids with a low hydrogen content (for example 4% hydrogen), such as coke or ground activated carbon, optionally pretreated, can also be used. Mixtures of such additives can also be used. The particle size of the additive is generally between 10 and 750 microns, preferably between 100 and 600 microns. The content of any solid additive present at the inlet of the reaction zone of the "dispersed" hydrocracking process. is between 0 and 10% by weight, preferably between 1 and 3% by weight, and the content of catalytic compounds (expressed as weight percentage of Group VIII and / or Group VIB metal elements) is between 0 and 10% by weight preferably between 0 and 1% by weight.
    [0009] The hybrid bed reactor (s) used in the hydrocracking zone are thus constituted by two populations of catalysts, a first population using supported catalysts in the form of extrudates, the diameter of which is advantageously between 0.8 and 0.3. , 2 mm, generally equal to 0.9 mm or 1.1 mm and a second population of "dispersed" type catalyst which has been mentioned above. The fluidization of the catalyst particles in the bubbling bed is enabled by the use of a boiling pump which permits liquid recycle, generally within the reactor. The flow rate of liquid recycled by the boiling pump is adjusted so that the supported catalyst particles are fluidized but not transported, so that these particles remain in the bubbling bed reactor (with the exception of catalyst fines that can be formed by attrition and entrained with the liquid since these fines are small). In the case of a hybrid bed, the "dispersed" type catalyst is also entrained with the liquid since the "dispersed" type catalyst consists of very small particles. The effluent obtained at the end of the hydrocracking step a) undergoes at least one separation step, optionally supplemented by further additional separation steps. for separating at least a light fraction of hydrocarbons containing fuels bases and a heavy fraction containing boiling compounds at at least 350 ° C. The separation step may advantageously be carried out by any method known to those skilled in the art such as, for example, the combination of one or more high and / or low pressure separators, and / or distillation stages and / or or high and / or low pressure stripping. Preferably, the separation step b) makes it possible to obtain a gaseous phase, at least a light fraction of hydrocarbons of the naphtha, kerosene and / or diesel type, a vacuum distillate fraction and a vacuum residue fraction and / or a fraction of atmospheric residue. In such a case, the heavy fraction sent in the precipitation step c) corresponds at least in part to an atmospheric residue fraction.
    [0010] The separation may be carried out in a fractionation section which may first comprise a high temperature high pressure separator (HPHT), and optionally a low temperature high pressure separator (HPBT), and / or atmospheric distillation and / or distillation. under vacuum. The effluent obtained at the end of step a) is separated (generally in an HPHT separator) into a light fraction and a heavy fraction containing predominantly boiling compounds at least 350 ° C. The cutting point of the separation is advantageously between 200 and 400 ° C.
    [0011] In a variant of the method of the invention, during step b), the effluent from the hydrocracking may also undergo a succession of flash comprising at least one high temperature high pressure balloon (HPHT) and a balloon. low-pressure high-temperature (BPHT) for separating a heavy fraction which is sent in a steam stripping step for removing from said heavy fraction at least one light fraction rich in hydrogen sulfide. The heavy fraction recovered at the bottom of the stripping column contains compounds boiling at least 350 ° C. but also atmospheric distillates. According to the process of the invention, said heavy fraction separated from the light fraction rich in hydrogen sulphide is then sent to the precipitation step c) and then to the sediment separation step d). In a variant, at least a portion of the so-called heavy fraction from step b) is fractionated by atmospheric distillation into at least one atmospheric distillate fraction containing at least one light fraction of naphtha, kerosene and / or diesel type hydrocarbons. and an atmospheric residue fraction. At least a part of the atmospheric residue fraction, corresponding at least in part to the heavy fraction resulting from step b), can be sent to the precipitation step c) and then to the step d) of physical separation of the sediments. The atmospheric residue may also be at least partially fractionated by vacuum distillation into a vacuum distillate fraction containing vacuum gas oil and a vacuum residue fraction. Said fraction vacuum residue, corresponding at least in part to the heavy fraction from step b), is advantageously sent at least partly in the precipitation step c) and then in step d) of physical separation of the sediments d). At least a portion of the vacuum distillate and / or the vacuum residue may also be recycled to the hydrocracking step a).
    [0012] Whatever the method of separation used, the light fraction (s) obtained may be subjected to other separation steps, possibly in the presence of the light fraction resulting from the inter separator. stage between the two hydrocracking reactors. Advantageously, it (s) is (are) subjected to atmospheric distillation to obtain a gaseous fraction, at least a light fraction of naphtha, kerosene and / or diesel type hydrocarbons and a vacuum distillate fraction. .
    [0013] Part of the atmospheric distillate and / or the vacuum distillate from the separation step b) may constitute part of a fuel oil as a fluxing agent. These cuts may also constitute marine fuels with low viscosity (MGO or MGO, Marine Diesel Oil or Marine Gas Oil according to the English terminology). Another part of the vacuum distillate can still be upgraded by hydrocracking and / or catalytic cracking in a fluidized bed. The gaseous fractions resulting from the separation step preferably undergo a purification treatment to recover the hydrogen and recycle it to the hydrocracking reactors (step a)). Part of the purified hydrogen can be used during the precipitation step. The recovery of different fuel base cuts (LPG, naphtha, kerosene, diesel and / or vacuum gas oil) obtained from the present invention is well known to those skilled in the art. The products obtained can be integrated into fuel tanks (also called "fuel pools" according to the English terminology) or undergo additional refining steps. The fraction (s) naphtha, kerosene, gas oil and vacuum gas oil may be subjected to one or more treatments (hydrotreatment, hydrocracking, alkylation, isomerization, catalytic reforming, catalytic cracking or thermal or other) to bring them to the specifications. required (sulfur content, smoke point, octane, cetane, etc ...) separately or in mixture.
    [0014] Advantageously, the vacuum distillate leaving the bubbling bed after separation can be hydrotreated. This hydrotreated vacuum distillate can be used as a fluxing agent at the oil pool having a sulfur content of less than or equal to 0.5% by weight or can be directly recovered as fuel having a sulfur content of less than or equal to 0.1% w / w. . Part of the atmospheric residue, vacuum distillate and / or vacuum residue may be further further refined, such as hydrotreating, hydrocracking, or catalytic cracking in a fluidized bed. loe cl: 1 ');' The heavy fraction obtained at the end of the separation step b) contains organic sediments which result from the hydrocracking conditions and the catalyst residues. A portion of the sediments consist of asphaltenes precipitated under hydrocracking conditions and are analyzed as existing sediments (IP375).
    [0015] Depending on the hydrocracking conditions, the sediment content in the heavy fraction varies. From an analytical point of view, existing sediments (IP375) and sediments after aging (measured according to the ISO 10307-2 method) are distinguished from potential sediments. However, high hydrocracking conditions, that is to say when the conversion rate is for example greater than 30, 40 or 50% depending on the load, cause the formation of existing sediments and potential sediments. In order to obtain a fuel oil or a base of reduced sediment fuel oil, in particular a bunker oil or a bunker oil base meeting the recommendations for a sediment content after aging (measured according to the ISO 10307-2 method) less than or equal to 0.1%, the method according to the invention comprises a precipitation step making it possible to improve the sediment separation efficiency and thus to obtain stable fuel oils or bases; to say a sediment content after aging less than or equal to 0.1% by weight. The precipitation step according to the invention makes it possible to form all the existing and potential sediments (by converting the potential sediments into existing sediments) so as to separate them more effectively and thus respect the sediment content after aging (measured according to the ISO 10307-2 method) of 0.1% maximum weight. The precipitation step according to the invention comprises bringing the heavy fraction resulting from the separation step b) into contact with a distillate cut of which at least 20% by weight has a boiling point greater than or equal to 100. ° C, preferably greater than or equal to 120 ° C, more preferably greater than or equal to 150 ° C. In a variant according to the invention, the distillate cut is characterized in that it comprises at least 25% by weight having a boiling point greater than or equal to 100 ° C., preferably greater than or equal to 120 ° C. more preferably greater than or equal to 150 ° C. Advantageously, at least 5% by weight or even 10% by weight of the distillate cut according to the invention has a boiling point of at least 252 ° C. More advantageously, at least 5 wt.% Or even 10 wt.% Of the distillate cut according to the invention has a boiling point of at least 255 ° C.
    [0016] The precipitation step c) according to the invention is advantageously carried out for a residence time of less than 500 minutes, preferably less than 300 minutes, more preferably less than 60 minutes, at a temperature of between 25 and 60 minutes. and 350 ° C, preferably between 50 and 350 ° C, preferably between 65 and 300 ° C and more preferably between 80 and 250 ° C. The pressure of the precipitation step is advantageously less than 20 MPa, preferably less than 10 MPa, more preferably less than 3 MPa and even more preferably less than 1.5 MPa. The distillate cut according to the invention advantageously comprises hydrocarbons having more than 12 carbon atoms, preferably hydrocarbons having more than 13 carbon atoms, more preferably hydrocarbons having between 13 and 40 carbon atoms.
    [0017] Said distillate fraction may partly or even wholly originate from the separation step b) of the invention or from another refining process or another chemical process. Said distillate cut may be used in a mixture with a naphtha-type cut and / or a vacuum-type gas oil cut and / or vacuum residue. Said distillate fraction may be used as a mixture with the light fraction obtained after step b), the atmospheric distillate fraction resulting from step b) and / or the vacuum distillate fraction originating from the stage b) separation. In the case where the distillate cut according to the invention is mixed with another cut, a light fraction and / or a heavy fraction as indicated above, the proportions are chosen so that the resulting mixture respects the characteristics of the the distillate cut according to the invention.
    [0018] The use of the distillate cut according to the invention has the advantage of avoiding the majority use of high value added cuts such as petrochemical cuts, naphtha ... The mass ratio between the distillate cut according to the invention and the heavy fraction obtained at the end of the separation step b) is between 0.01 and 100, preferably between 0.05 and 10, more preferably between 0.1 and 5, and still more preferred between 0.1 and 2. When the distillate cut according to the invention is at least drawn from the process, it is possible to accumulate this cut during a start-up period so as to reach the desired ratio. The precipitation step may be carried out using an exchanger or a heating furnace 30 followed by one or more capacity (s) in series or in parallel such (s) as a horizontal or vertical balloon possibly with a settling function to remove some of the heavier solids, and / or a piston reactor. A stirred and heated tank may also be used, and may be provided with a bottom draw to remove some of the heavier solids. Advantageously, the precipitation step can be carried out online, without buffer capacity, possibly using a static mixer.
    [0019] According to one variant, step c) of precipitation of the heavy fraction resulting from step b) is carried out in the presence of an inert gas and / or an oxidizing gas and / or an oxidizing liquid and / or hydrogen, preferably from the separation steps of the process of the invention, in particular from the separation step b). The precipitation step c) can be carried out in the presence of an inert gas such as nitrogen, or in the presence of an oxidizing gas such as dioxygen, ozone or nitrogen oxides, or presence of a mixture containing an inert gas and an oxidizing gas such as air or air depleted by nitrogen, or in the presence of an oxidizing liquid to accelerate the precipitation process. The term "oxidizing liquid" means an oxygenated compound, for example a peroxide such as hydrogen peroxide, or a mineral oxidizing solution such as a solution of potassium permanganate or a mineral acid such as sulfuric acid. alternatively, the oxidizing liquid is then mixed with the heavy fraction from the separation step b) and the distillate cut according to the invention during the implementation of step c). At the end of the precipitation step c), at least one hydrocarbon fraction with an enriched content of existing sediments is obtained which is sent to step d) of separation of the sediments. Step d) Separation of Segments The process according to the invention further comprises a step d) physically separating the sediments and the catalyst residues.
    [0020] The heavy fraction obtained after step c) of pre-potency contains precipitated asphaltene-type organic sediments which result from hydrocracking and precipitation conditions. This heavy fraction may also contain catalyst fines resulting from the attrition of extruded type catalysts in the implementation of hydrocracking reactor. This heavy fraction may optionally contain "dispersed" catalyst residues in the case of the implementation of a hybrid reactor.
    [0021] Thus, at least a part of the heavy fraction resulting from the precipitation step c) is subjected to a physical separation of the sediments and the catalyst residues, by means of at least one physical separation means chosen from a filter , a separation membrane, a bed of organic or inorganic type filter solids, electrostatic precipitation, a centrifugation system, decantation, auger withdrawal. A combination, in series and / or in parallel, of several separation means of the same type or different type can be used during this step d) separation of sediments and catalyst residues. One of these solid-liquid separation techniques may require the periodic use of a light rinsing fraction, resulting from the process or not, allowing for example the cleaning of a filter and the evacuation of the sediments. At the end of stage d) of physical separation of the sediments, the heavy fraction (with a sediment content after aging of less than or equal to 0.1% by weight) is obtained, comprising a portion of the distillate cut according to US Pat. invention introduced in step c). EteeJ Recovery of the heavy fraction at the end of the stage 15 According to the invention, the mixture resulting from stage d) is advantageously introduced in a stage e) of recovery of the heavy fraction having a sediment content after aging less than or equal to 0.1% by weight, said step of separating the heavy fraction from step d) of the distillate cut introduced in step c). Step e) is a separation step similar to separation step b). Step e) can be carried out by means of separator balloon and / or distillate-type equipment so as to separate on the one hand at least part of the distillate cut introduced during step c). precipitation and on the other hand the heavy fraction having a sediment content after aging less than or equal to 0.1% by weight. Advantageously, a portion of the distillate cut separated from step e) is recycled in step c) of precipitation. Said recovered heavy fraction may advantageously be used as a base of fuel oil or as fuel oil, especially as a base of bunker oil or as bunker oil, having a sediment content after aging less than 0.1% by weight. Advantageously, said heavy fraction is mixed with one or more fluxing bases selected from the group consisting of catalytic cracking light cutting oils, catalytic cracking heavy cutting oils, cracking residue. catalytic, a kerosene, a gas oil, a vacuum distillate and / or a decanted oil. According to a particular embodiment, a part of the distillate cut according to the invention can be left in the sediment-reduced heavy fraction so that the viscosity of the mixture is directly that of a desired fuel grade. for example 180 or 380 cSt at 50 ° C. Optional hydrotreatment step: The sulfur content of the heavy fraction from step d) or e), and predominantly containing compounds boiling at least 350 ° C, is dependent on the operating conditions of step d hydrocracking but also the sulfur content of the original charge. Thus, for low sulfur feeds, generally less than 1.5% by weight, it is possible to directly obtain a heavy fraction with less than 0.5% by weight sulfur as required for vessels without treatment. fumes and operating outside 15 ZCTAs by 2020-2025. For more sulfurous feedstocks, whose sulfur content is generally greater than 1.5% by weight, the sulfur content of the heavy fraction may exceed 0.5% by weight. In such a case, a step f) of hydrotreatment in a fixed bed is made necessary in the case where the refiner wishes to reduce the sulfur content, in particular for a base of bunker fuel oil or a bunker oil intended to be burned on a ship without smoke treatment. Stage f) of hydrotreatment in a fixed bed is carried out on at least a part of the heavy fraction resulting from stage d) or e). The heavy fraction resulting from step f) can advantageously be used as a base for fuel oil or as fuel oil, especially as a bunker oil or bunker oil base, having a sediment content after aging of less than 0.1% by weight. Advantageously, said heavy fraction is mixed with one or more fluxing bases selected from the group consisting of catalytic cracking light cutting oils, catalytic cracking heavy cutting oils, catalytic cracking residue, kerosene, a gas oil, a vacuum distillate and / or a decanted oil.
    [0022] The heavy fraction resulting from step d) or e) is sent to step f) of hydrotreatment comprising one or more hydrotreatment zones in fixed beds. Sending in a fixed bed a heavy fraction free of sediment is an advantage of the present invention since the fixed bed will be less subject to clogging and increased load loss. Hydroprocessing (HDT) is understood to mean, in particular, hydrodesulphurization (HDS) reactions, hydrodenitrogenation (HDN) reactions and hydrodemetallation (HDM) reactions, but also hydrogenation, hydrodeoxygenation, hydrodearomatization, hydrodenetration, hydroisomerization, hydrodealkylation, hydrocracking, hydro-deasphalting and Conradson carbon reduction.
    [0023] Such a method of hydrotreating heavy cuts is widely known and can be related to the process known as HYVAHLFTM described in US5417846. Those skilled in the art readily understand that in the hydrodemetallization step, hydrodemetallation reactions are mainly carried out but also part of the hydrodesulfurization reactions. Similarly, in the hydrodesulfurization step, hydrodesulphurization reactions are mainly carried out but also part of the hydrodemetallation reactions. According to one variant, a co-charge may be introduced with the heavy fraction in the hydrotreatment step f). This co-charge may be chosen from atmospheric residues, vacuum residues resulting from direct distillation, deasphalted oils, aromatic extracts from lubricant base production lines, hydrocarbon fractions or a mixture of hydrocarbon fractions which may be used. selected from the products resulting from a process for catalytic cracking in a fluid bed: a light cutting oil (LCO), a heavy cutting oil (HCO), a decanted oil, or possibly derived from distillation, the gasoil fractions in particular those obtained by atmospheric or vacuum distillation, such as, for example, vacuum gas oil. The hydrotreatment step can advantageously be carried out at a temperature of between 300 and 500 ° C., preferably 350 ° C. to 420 ° C. and under a hydrogen partial pressure advantageously between 2 MPa and 25 MPa, Preferably between 10 and 20 MPa, an overall hourly space velocity (VVH) which is defined as the volumetric flow rate of the feed divided by the total volume of the catalyst, being within a range of 0.1 hr-1. at 5 h -1 and preferably from 0.1 h -1 to 2 h -1, a quantity of hydrogen mixed with the feedstock usually of 100 to 5000 Nm 3 / m3 (normal cubic meters (Nm 3) per cubic meter (m3 ) usually 200 to 2000 Nm3 / nr3 and preferably 300 to 1500 Nm3 / nr3. Usually, the hydrotreatment step is carried out industrially in one or more liquid downflow reactors. The hydrotreatment temperature is generally adjusted according to the desired level of hydrotreatment. The hydrotreatment catalysts used are preferably known catalysts and are generally granular catalysts comprising, on a support, at least one metal or metal compound having a hydrodehydrogenating function. These catalysts are advantageously catalysts comprising at least one Group VIII metal, generally selected from the group consisting of nickel and / or cobalt, and / or at least one Group VIB metal, preferably molybdenum and / or tungsten. . For example, a catalyst comprising from 0.5 to 10% by weight of nickel and preferably from 1 to 5% by weight of nickel (expressed as nickel oxide NiO) and from 1 to 30% by weight of molybdenum will be used. preferably from 5 to 20% by weight of molybdenum (expressed as molybdenum oxide MoO 3) on a mineral support. This support will, for example, be selected from the group formed by alumina, silica, silica-aluminas, magnesia, clays and mixtures of at least two of these minerals. Advantageously, this support contains other doping compounds, in particular oxides selected from the group formed by boron oxide, zirconia, ceria, titanium oxide, phosphoric anhydride and a mixture of these oxides. Most often an alumina support is used and very often a support of alumina doped with phosphorus and possibly boron. The P 2 O 5 phosphoric anhydride concentration is usually in the range of from 0 to 0.1 to 10% by weight. The concentration of boron trioxide B 2 O 5 is usually from 0 to 0.1 to 10% by weight. The alumina used is usually a y or ri alumina. This catalyst is most often in the form of extrudates. The total content of metal oxides of Groups VIB and VIII is often from 5 to 40% by weight and in general from 7 to 30% by weight and the weight ratio expressed as metal oxide between metal (or metals) of the group VIB on metal (or metals) of group VIII is generally from 20 to 1 and most often from 10 to 2. In the case of a hydrotreating step including a hydrodemetallation step (HDM), then a step hydrodesulfurization (HDS), it is most often used specific catalysts adapted to each step.
    [0024] Catalysts that can be used in the hydrodemetallation (HDM) stage are for example indicated in patents EP113297, EP113284, US5221656, US5827421, US7119045, US5622616 and US5089463. Hydrodemetallation (HDM) catalysts are preferably used in the reactive reactors. Catalysts that can be used in the hydrodesulfurization step (HDS) are for example indicated in the patents EP113297, EP113284, US6589908, US4818743 or US6332976. It is also possible to use a mixed catalyst that is active in hydrodemetallization and hydrodesulfurization for both the hydrodemetallation (HDM) section and the hydrodesulfurization (HDS) section as described in patent FR2940143.
    [0025] Prior to injection of the feed, the catalysts used in the process according to the present invention are preferably subjected to an in-situ or ex-situ sulphurization treatment. Step g): Optional hydrotreating separation step The process according to the invention may comprise a step g) of separating the effluents from the hydrotreating step f). The optional separation step g) may advantageously be carried out by any method known to those skilled in the art such as, for example, the combination of one or more high and / or low pressure separators, and / or distillation and / or high and / or low pressure stripping. This optional separation step g) is similar to the separation step b) and will not be further described.
    [0026] In an alternative embodiment of the invention, the effluent obtained in step f) may be at least partly, and often in all, sent to a separation step g), comprising an atmospheric distillation and / or vacuum distillation. The effluent from the hydrotreating step is fractionated by atmospheric distillation into a gaseous fraction, at least one atmospheric distillate fraction containing the fuels bases (naphtha, kerosene and / or diesel) and an atmospheric residue fraction. At least a portion of the atmospheric residue can then be fractionated by vacuum distillation into a vacuum distillate fraction containing vacuum gas oil and a vacuum residue fraction. The vacuum residue fraction and / or the vacuum distillate fraction and / or the atmospheric residue fraction may in part constitute at least the bases of low sulfur fuel oils having a sulfur content of less than or equal to 0.5% by weight. and a sediment content after aging less than or equal to 0.1%. The vacuum distillate fraction can constitute a fuel oil base having a sulfur content of less than or equal to 0.1% by weight. Part of the vacuum residue and / or the atmospheric residue can also be recycled to the hydrocracking step a). To obtain a fuel oil, the heavy fractions from steps d) and / or e) and / or f) and / or g) may be mixed with one or more fluxing bases selected from the group consisting of catalytic cracking light cut, catalytic cracked heavy cutting oils, catalytic cracking residue> kerosene, gas oil, vacuum distillate and / or decanted oil, the distillate cut according to the invention. Preferably, kerosene, gas oil and / or vacuum distillate produced in the process of the invention will be used. Advantageously, use will be kerosene, gas oil and / or vacuum distillate obtained (s) in the separation steps b) or g) of the process. Figure 1 schematically depicts an exemplary implementation of the invention without limiting the scope thereof. The hydrocarbon feedstock (1) and hydrogen (2) are contacted in a bubbling bed hydrocracking zone a). The effluent (3) from the hydrocracking zone a) is sent to a separation zone b) to obtain at least one light hydrocarbon fraction (4) and a heavy liquid fraction (5) containing boiling compounds. at least 350 ° C. This heavy fraction (5) is brought into contact with a distillate cut (6) during a precipitation step in zone c). The effluent (7) consisting of a heavy fraction and sediment is treated in a physical separation step in zone d) to remove a fraction comprising sediments (9) and recover a liquid hydrocarbon fraction (8). ) with reduced sediment content. The liquid hydrocarbon fraction (8) is then treated in a recovery step in zone e) firstly of the liquid hydrocarbon fraction (11) having a sediment content after aging less than or equal to 0.1% by weight, and on the other hand a fraction (10) containing at least a portion of the distillate cut introduced during step c).
    [0027] EXAMPLES The following example illustrates the invention without however limiting its scope. A vacuum residue feedstock (RSV Ural) containing 84% by weight of compounds boiling at a temperature above 520 ° C, having a density of 9.5 ° API and a sulfur content of 2.6% by weight is treated. . The feedstock was subjected to a hydrocracking step comprising two successive bubbling bed reactors. The operating conditions of the hydrocracking step are given in Table 1. Tablepl. I Conferences on ection of hydrocracivaae T2 bubbling beds NîMo on alumina (C) lel npérature R2 (° C) Partial fraction H2 (MPa) VVH "reactors" (h-1, Sm3 / h load: raîche / m3 of reactors) vv-r-1 "bubbling bed catalysts" (h-1, Sm3 / h fresh load / m3 boiling bed catalysts) -12 / HC hydrocracking section inlet H2 consumption (Nm3 / m3) The NiMo catalyst on Alumina used is sold by the company Axens under the reference HOC-458. The effluent of the hydrocracking step is then subjected to a separation step for separating a gaseous fraction and a heavy liquid fraction by means of separators. The heavy liquid fraction is then distilled in an atmospheric distillation column to recover distillates and an atmospheric residue. Samples, weighed and analyzed make it possible to establish an overall material balance of bubbling bed hydrocracking. The yields and the sulfur contents of each fraction obtained in the effluent at the outlet of the bubbling bed hydrocracking are given in Table 2 below: Table 2: Pende iRdt) and sulfur content (S) of the effluent "-lvdmr.racluacie (% ads / char ') 2 beds bubbling hydrolysis (430/430 ° C) Products Rdt (`) / opds) S (% wt ) NH3 0.2 H2S 2.3 C1-04 (gas) 4.7 Light Naphtha (PI - 100 ° C) 3.2 0.06 Heavy Naphtha (100-150 ° C) 7.8 Kerosene (150 ° C) -225 ° C) 9.8 0.08 Diesel (225 ° C - 350 ° C) 18.1 0.13 Vacuum distillate (350 ° C - 520 ° C) 36.5 0.51 Vacuum residue (520 ° C) ° C +) 19.2 1.27 The atmospheric residue RA is a 350 ° C + fraction composed of a part of the vacuum distillate (DSV) of the effluent and of the entire vacuum residue (RSV) of the effluent in the proportion 44% by weight of DSV and 56% by weight of RSV.This atmospheric residue has a viscosity of 38 cSt at 100 ° C. This atmospheric residue RA is subjected to a treatment according to several variants A) a variant A (not in accordance with the invention) in which the atmospheric residue RA is filtered by means of a metallic porous filter Pa110. The sediment content after aging is measured on the atmospheric residue recovered after separation of the sediments; B) a variant B in which a precipitation step (in accordance with the invention) is carried out by mixing, with stirring at 80 ° C. for 1 minute, the atmospheric residue RA and a distillate cut according to the invention in a ratio described in Table 3: 50% by weight of atmospheric residue (RA) and 50% by weight of the distillate fraction 5 according to the invention are mixed. The atmospheric residue corresponding to the 350 ° C + fraction of the effluent in the proportion 44% by weight of DSV and 56% by weight of RSV of the hydrocracking step of the invention is characterized by a sediment content ( IP375) of 0.4% w / w and sediment content after aging (IP390) of 0.9% w / w.
    [0028] The distillate fraction characterized by the simulated distillation which reflects the distilled percentage as a function of temperature, contains more than 5% by weight of the compounds which boil at more than 255 ° C. (Table 3). Table 3. Simulated distillation curves of the distillate fraction `) / 0 by distilled weight 5% 10% 20% 30% 40% 50% 60% 70% 80% 90% 95% Boiling temperature (° C) 191 The mixture is then subjected to a step of separating the sediments and catalyst residues by means of a Pall® brand porous metallic filter. This step of physical separation of the sediments is followed by a distillation step of the mixture making it possible to recover, on the one hand, the atmospheric residue with a reduced sediment content, and on the other hand the distillate cut.
    [0029] The sediment content after aging is measured on the atmospheric residue recovered after the distillation step. The set of precipitation and sediment separation data is summarized in Table 4. Table 4: Summary of performance with or without precipitation, sediment separation and heavy fraction recovery No precipitation (non-compliant) Mix, precipitate -7iiori and sediment separation (Invention) Proportions of the Proportions of the mixture (% m / m) melanL, (° / 0 m / m) Proportion of the atmospheric (RA) mixture (`) / 0 m / m) Residue in the Proportion of the distillate fraction in the mixture (`) / 0 m / m) Sediment content of the mixture (measurement according to IP375a m / m) Sediment content of the atmospheric residue RA recovered after physical separation of the sediments (measurement according to IP390 b ° ArnIrn ) The operating conditions of the hydrocracking step coupled to the different treatment variants (separation of sediments with precipitation step (B) according to the invention or without precipitation step (A)) of the atmospheric residue (RA) on t an impact on the stability of the effluents obtained. This is illustrated by the post-aging sediment levels measured in RA atmospheric residues (350 ° C + cut) before and after the sediment precipitation and separation step. Thus, the atmospheric residue obtained according to the invention is an excellent fuel oil base, especially a bunker oil base having a sediment content after aging (IP390) less than 0.1% by weight.
    [0030] The RA atmospheric residue treated according to the mixture of Table 4 has a sediment content after aging of less than 0.1%, a sulfur content of 0.93% w / w and a viscosity of 380 cSt at 50 ° C. This atmospheric residue thus constitutes a quality bunker oil, which can be sold according to the RMG or IFO 380 grade, with low sediment content. For example, it may be burned in the ECA zone or outside the ECA zones by 2020-25 provided that the vessel is equipped with flue-gas scrubbers to cut down the sulfur oxides. 5
    权利要求:
    Claims (7)
    [0001]
    REVENDICATIONS1. A process for converting a hydrocarbon feedstock containing at least one hydrocarbon fraction having a sulfur content of at least 0.1% by weight, an initial boiling temperature of at least 340 ° C and a final temperature of boiling at least 440 ° C, said process comprising the following steps: a) a step of hydrocracking the feedstock in the presence of hydrogen in at least one reactor containing a catalyst supported in a bubbling bed, b) a separation step of the effluent obtained at the end of step a) into at least one light hydrocarbon fraction containing fuel bases and a heavy fraction containing compounds boiling at least 350 ° C, c) a step of precipitation of the sediment in which the heavy fraction resulting from the separation step b) is brought into contact with a distillate cut of which at least 20% by weight has a boiling point greater than or equal to 100 ° C., for a period of less than 500 minutes, at a temperature of between 25 and 350 ° C., and a pressure of less than 20 MPa, d) a step of physically separating the sediments from the heavy fraction resulting from step c) of precipitation to obtain a separate heavy fraction sediment, e) a step of recovering a heavy fraction having a sediment content, measured according to the ISO 10307-2 method, less than or equal to 0.1% by weight of separating the heavy fraction resulting from the step d) the distillate cut introduced during step c).
    [0002]
    2. Method according to claim 1 comprising a f) fixed bed hydrotreating step implemented on at least part of the heavy fraction from step d) or e).
    [0003]
    3. A process according to claim 1 or 2 wherein the distillate cut comprises at least 25 wt.% Having a boiling point greater than or equal to 100 ° C.
    [0004]
    4. Method according to one of the preceding claims wherein at least 5% by weight of the distillate fraction has a boiling temperature of at least 252 ° C.
    [0005]
    5. Method according to one of the preceding claims wherein the distillate cut comprises hydrocarbons having more than 12 carbon atoms. 3036703 29
    [0006]
    6. Method according to one of the preceding claims wherein the distillate cut comes in part, or in whole, of step b) separation or another refining process or another chemical process.
    [0007]
    7. The method according to one of the preceding claims wherein a portion of the distillate cut 5 separated from step e) is recycled to the precipitation step c). Process according to one of the preceding claims, in which the hydrocracking step a) is carried out under a hydrogen partial pressure of 5 to 35 MPa, at a temperature of 330 to 500 ° C., a space velocity of 0, 05 h-1 to 5 h-1 and the amount of hydrogen mixed with the feed is 50 to 5000 Nm3 / m3. 9. The process as claimed in one of the preceding claims, in which the hydrocracking step is carried out in at least one reactor operating in a hybrid bed mode. 10. Method according to one of the preceding claims wherein step c) of precipitation of the heavy fraction from step b) is carried out in the presence of an inert gas and / or an oxidizing gas and / or an oxidizing liquid and / or hydrogen, preferably from the separation step b). 11. Method according to one of the preceding claims wherein the step d) of physical separation is carried out by means of at least one separation means selected from a filter, a separation membrane, a bed of organic-type filtering solids. Or inorganic, electrostatic precipitation, centrifugation system, decantation, auger withdrawal. Process according to one of the preceding claims, in which at least a portion of the so-called heavy fraction from step b) is fractionated by atmospheric distillation into at least one atmospheric distillate fraction containing at least one light hydrocarbon fraction. naphtha, kerosene and / or diesel type and an atmospheric residue fraction. 13. Method according to one of the preceding claims wherein the treated filler is selected from atmospheric residues, vacuum residues from direct distillation, crude oils, crude oils topped, deasphalted oils, deasphalting resins, asphalts or deasphalting pitches, residues resulting from conversion processes, aromatic extracts from lubricant base production lines, oil sands or their derivatives, oil shales or their derivatives, taken singly or in admixture. The process of claim 13 wherein the feedstock contains at least 1% C7 asphaltenes and at least 5 ppm metals. 15. Method according to one of the preceding claims wherein the heavy fractions from steps d) and / or e) and / or f) are mixed with one or more fluxing bases selected from the group consisting of light cutting oils. catalytic cracking, catalytically cracked heavy cutting oils, catalytic cracking residue, kerosene, gas oil, vacuum distillate and / or decanted oil, the distillate cut according to claims 1 to 4; 5 to obtain a fuel oil.
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    KR20180014776A|2018-02-09|
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    法律状态:
    2016-06-07| PLFP| Fee payment|Year of fee payment: 2 |
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    申请号 | 申请日 | 专利标题
    FR1554962A|FR3036703B1|2015-06-01|2015-06-01|METHOD FOR CONVERTING LOADS COMPRISING A HYDROCRACKING STEP, A PRECIPITATION STEP AND A SEDIMENT SEPARATION STEP FOR FIELD PRODUCTION|FR1554962A| FR3036703B1|2015-06-01|2015-06-01|METHOD FOR CONVERTING LOADS COMPRISING A HYDROCRACKING STEP, A PRECIPITATION STEP AND A SEDIMENT SEPARATION STEP FOR FIELD PRODUCTION|
    EP16719813.4A| EP3303522B1|2015-06-01|2016-04-20|Method for converting feedstocks comprising a hydrocracking step, a precipitation step and a sediment separation step, in order to produce fuel oils|
    JP2017562068A| JP6670855B2|2015-06-01|2016-04-20|Method for converting a feedstock for producing fuel oil, comprising a hydrocracking step, a precipitation step and a precipitate separation step|
    ES16719813T| ES2728566T3|2015-06-01|2016-04-20|Load conversion process comprising a hydrocracking stage, a precipitation stage and a sediment separation stage for the production of fuel oils|
    PCT/EP2016/058747| WO2016192892A1|2015-06-01|2016-04-20|Method for converting feedstocks comprising a hydrocracking step, a precipitation step and a sediment separation step, in order to produce fuel oils|
    CN201680032073.6A| CN107849466A|2015-06-01|2016-04-20|Including hydrocracking step, settling step and deposit separating step to produce the raw material method for transformation of fuel oil|
    PT16719813T| PT3303522T|2015-06-01|2016-04-20|Method for converting feedstocks comprising a hydrocracking step, a precipitation step and a sediment separation step, in order to produce fuel oils|
    KR1020177037761A| KR20180014776A|2015-06-01|2016-04-20|Method for converting feedstocks comprising a hydrocracking step, a precipitation step and a sediment separation step, in order to produce fuel oils|
    US15/578,467| US20180134974A1|2015-06-01|2016-04-20|Method for converting feedstocks comprising a hydrocracking step, a precipitation step and a sediment separation step, in order to produce fuel oils|
    TW105117261A| TWI700361B|2015-06-01|2016-06-01|Process for the conversion of feeds, comprising a hydrocracking step, a precipitation step and a step for separating sediments, for the production of fuel oils|
    SA517390453A| SA517390453B1|2015-06-01|2017-11-30|Process for separating sediments, for the production of fuel oils|
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