FR2981659A1 - PROCESS FOR CONVERTING PETROLEUM LOADS COMPRISING A BOILING BED HYDROCONVERSION STEP AND A FIXED BED HYDROTREATMENT STEP FOR THE PRODUCTION OF LOW SULFUR CONTENT - Google Patents

Abstract

Process for the conversion of petroleum feedstock for the production of low sulfur fuel oil comprising the following steps: a step of hydroconversion of the boiling bed feed in the presence of a supported catalyst, a separation step making it possible to obtain a residual fraction; - a fixed bed hydrotreating step of the residual fraction using upstream a system of reactive reactors.

Description

The present invention relates to the refining and the conversion of heavy hydrocarbon fractions containing, inter alia, sulfur-containing impurities. It relates more particularly to a process for converting heavy petroleum feedstocks for the production of vacuum distillate type oil bases, atmospheric residue and vacuum residue, in particular bunker oil bases, with a low sulfur content. The process according to the invention also makes it possible to produce atmospheric distillates (naphtha, kerosene and diesel), vacuum distillates and light gases (C1 to C4).

While the onshore industry was subject to severe regulation of sulfur levels in fuel bases (gasoline, diesel) in recent decades, the sulfur content in marine fuels has so far been non-burdensome. In fact, the fuels currently on the market contain up to 4.5% by weight of sulfur. As a result, ships have become the main source of sulfur dioxide (SO2) emissions. In order to reduce its emissions, the International Maritime Organization has submitted recommendations in terms of specifications for marine fuels. These recommendations are presented in the 2010 version of ISO 8217 (Annex VI of the MARPOL Convention). The sulfur specification now focuses on SO emissions, and results in a recommendation for sulfur content equivalent to less than or equal to 0.5% by weight. Another very restrictive recommendation is the sediment content after aging according to ISO 10307-2 which must be less than or equal to 0.1%.

The present invention makes it possible to produce oil bases, in particular bunker fuel bases, which comply with the recommendations of the MARPOL convention. US Pat. No. 6,447,671 describes a process for converting heavy petroleum fractions comprising a first boiling bed hydroconversion stage, a stage for removing the catalyst particles contained in the hydroconversion effluent, and then a bed hydrotreatment stage. fixed. This process aims to obtain fuel bases (gasoline and diesel) having in particular a low sulfur content. This process also makes it possible to obtain a heavy fuel oil with nevertheless higher sulfur contents than the new recommendations. The present invention adapts and improves the conversion method described by the Applicant in US Pat. No. 6,447,671 for the production of fuel oil bases, incorporating in this process a system of permutable reactors (or guard zones) operating in fixed beds in the reactor. hydrotreatment stage. 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 comprising the following steps: a) a step of hydroconversion in the presence of hydrogen in at least one reactor containing a catalyst supported in bubbling bed, b) a step of separating the effluent obtained at the end of step a) into at least a light fraction of hydrocarbon base fuels and a heavy fraction containing predominantly compounds boiling at least 350 ° C, c) a step of hydrotreating in a fixed bed of at least a portion of the heavy fraction resulting from step b) in which the heavy hydrogen fraction is passed under hydrotreatment conditions over a catalyst of hydrotreatment and in the hydrotreatment stage comprises one or more hydrotreatment zones in fixed beds preceded by at least two hydrotreatment guard zones also in fixed beds, arranged in series for cyclic use consisting of the successive repetition steps c ") and cm) defined below: c ') a step, in which the guard zones are used together for a time at most equal to the time of deactivation and / or clogging of one of between them, c ") a step, during which the deactivated and / or clogged guard zone is short-circuited and the catalyst contained therein is regenerated and / or replaced by fresh catalyst, and during which the other one or others guard area (s) are used, and of) a step, during which the guard zones are used together, the guard zone whose catalyst has been regenerated in the previous step being reconnected and said eta pe being continued for a duration at most equal to the time of deactivation and / or clogging of one of the guard zones. The system of permutable reactors is known from patents FR2681871, FR2784687 and EP1343857. It is conventionally used to increase the operating cycle of a hydrotreatment unit by allowing replacement of the deactivated and / or clogged catalyst in the reactive reactors without stopping the entire unit. The present invention relates to the production of oil bases complying with the recommendations of the International Maritime Organization as well as atmospheric distillates and / or vacuum distillates. The hydroconversion step partially converts the heavy load 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 produces by its nature catalyst fines and sediments that must be removed before subsequent treatments in a fixed bed to avoid clogging. or catalytic bed (s). The fines come mainly from the attrition of the catalyst in the bubbling bed. The sediments may be precipitated asphaltenes. Initially in the load, the conditions of hydroconversion and in particular the temperature make that they undergo reactions (dealkylation, polymerization ...) leading to their precipitation. The reactive reactors in the process according to the invention make it possible to solve the problem of fines and sediments at the same time as the problem of the sulfur content without, however, pushing the operating conditions in the hydrotreating step excessively.

In fact, the permutable reactors receiving the heavy fraction of the hydroconversion limit the content of fines and sediments by their filter function (fixed bed). In order to be able to wait for the recommendation of a sulfur content of less than or equal to 0.5% by weight, the operating conditions of the hydrotreatment section must be severe, which typically results in an increase in the temperature in the fixed beds. Nevertheless, this increase in temperature favors the deposition of coke accelerating the clogging and deactivation processes. The permutable reactors have the function of protecting the hydrotreatment section and thus make it possible to provide sufficient relief to the main hydrotreating reactors in order to carry out the necessarily thorough desulfurization of the heavy fraction obtained after the hydroconversion without the operating conditions being excessively hardened. In other words, the integration of the reactive reactors into a series of hydroconversion into a bubbling bed and then hydrotreatment into a fixed bed makes it possible to obtain fuel bases that meet the future specifications. The oil bases produced by the process according to the invention have 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%. In addition, if the base fuel consists of vacuum distillate from the process, the sulfur content may be less than or equal to 0.1% by weight. Another important point of the process is the partial conversion of the feedstock which makes it possible to produce low-sulfur distillates (naphtha, kerosene and diesel) by bubbling bed hydroconversion. In the context of the present invention, the conversion of the filler into lighter fractions is usually between 10 and 90% and most often between 25 and 60% or even limited to about 50%. The conversion rate mentioned above is defined as the mass fraction of organic compounds having a boiling point greater than 350 ° C at the inlet of the reaction section minus the mass fraction of organic compounds having a boiling point. greater than 350 ° C at the outlet of the reaction section, all divided by the mass fraction of organic compounds having a boiling point above 350 ° C at the inlet of the reaction section. In order to constitute the fuel oil that meets the viscosity recommendations, the oil bases obtained by the present process can be mixed with fluxing bases so as to achieve the target viscosity of the desired fuel grade. The viscosity of a bunker oil must be less than or equal to 380 cSt (50 ° C). According to a variant of the process, the effluent obtained after hydrotreatment can be subjected to a separation step (step d) from which at least one fraction of fuel bases (naphtha, kerosene, gas oil) and heavy fractions such as vacuum distillate or vacuum residue. According to a variant of the process, part of at least one of these heavy fractions can be sent to a catalytic cracking section (step e) in which it is treated under conditions making it possible, inter alia, to produce a light cutting oil (LCO or "light cycle oil" according to the English terminology) and a heavy cutting oil (HCO or "heavy cycle oil" in the English terminology)). These oils can be used as a fluxing agent to be mixed with the oil bases resulting from the process according to the invention to form the fuel oil so as to reach the targeted viscosity.

The feedstock treated in the process according to the invention are advantageously chosen from atmospheric residues, vacuum residues from straight-run distillation, crude oils, crude head 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, whether 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 which may come from the distillation, gas oil fractions including those obtained by atmospheric or vacuum distillation, such as vacuum gas oil. The heavy charges can also advantageously comprise cuts from the liquefaction process of coal or biomass, aromatic extracts, or any other hydrocarbon cuts or non-petroleum fillers such as pyrolysis oil. Said heavy charges generally have a sulfur content of at least 0.1% by weight, an initial boiling point of at least 340 ° C and a final boiling point of at least 440 ° C. According to the present invention, the charges which are treated are preferably atmospheric residues or residues under vacuum, or mixtures of these residues. Hydroconversion in a bubbling bed (step a) The feedstock is subjected according to the present invention to a hydroconversion step which is carried out in at least one reactor containing (s) a catalyst supported in a bubbling bed and operating (s) with an upward flow of liquid. and gas. The main purpose of hydroconversion is to convert the heavy fraction into lighter cuts while partially refining the charge.

The ebullated bed technology being widely known, only the main operating conditions will be repeated here. Bubbling bed technologies use supported catalysts in the form of extrudates whose diameter 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. It is therefore not necessary to stop the unit to change the spent catalyst, nor to increase the reaction temperatures along the cycle to compensate for the 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. The conditions of step a) of treating the feedstock in the presence of hydrogen are usually conventional bubbling bed hydroconversion conditions of a liquid hydrocarbon fraction. It is usually carried out under an absolute pressure of 2.5 to 35 MPa, often 5 to 25 MPa and most often 6 to 20 MPa at a temperature of 330 to 550 ° C and often 350 to 500 ° 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 is defined as the volumetric flow rate of the feed divided by the total volume of the reactor and is generally in a range of from 0.1 hr -1 to 10 hr -1 and preferably from 0.2 hr -1 to 5 h-1. The quantity of hydrogen mixed with the feedstock is usually 50 to 5000 normal cubic meters (Nm3) per cubic meter (m3) of liquid feed and most often 100 to 1000 Nm3 / m3 and preferably 200 to 500 Nm3 / m3. It is possible to use a conventional granular hydroconversion catalyst comprising, on an amorphous support, at least one metal or metal compound having a hydro-dehydrogenating function. 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 molybdenum of preferably from 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 a support of alumina doped with phosphorus and possibly boron. When phosphorus pentoxide P2O5 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 metal oxides of groups VI 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 Group VI on metal (or metals) of group VIII is in general 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 catalyst reactor fresh or new 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 replacement are performed using devices for the continuous operation of this hydroconversion 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 eliminated before it is reinjected in the hydroconversion stage a). Most often this hydroconversion stage a) is carried out under the conditions of the H-OILO process as described for example in US Pat. The ebullated bed hydroconversion can be carried out in a single reactor or in several reactors (usually two) arranged in series. The use of at least two ebullated bed reactors in series results in higher quality and better yielding products, thus limiting energy and hydrogen requirements in possible post-treatments. In addition, the hydroconversion 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 10 ° 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 is necessary. The different operating conditions in terms of temperature in the two hydroconversion 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 hydroconversion stage is subjected to a separation of the light fraction and at least a portion, preferably all, of the residual effluent is treated in the second stage of hydroconversion. This separation is advantageously made in an inter-stage separator described in US Pat. No. 6,270,654 and makes it possible in particular to avoid overcracking of the light fraction in the second hydroconversion reactor. It is also possible to transfer in whole or in part the spent catalyst withdrawn from the reactor of the first hydroconversion stage, operating at a lower temperature, directly to the reactor of the second stage, operating at a higher temperature or transferring in full or in part the used catalyst withdrawn from the reactor of the second stage directly to the reactor of the first stage. This cascade system is described in US4816841. Separation of the Hydroconversion Effluent (Stage b) The effluent obtained at the end of the ebullated bed hydroconversion undergoes at least one separation stage, optionally supplemented by further additional separation steps, making it possible to separate minus a light hydrocarbon fraction containing fuel bases and a heavy fraction containing predominantly boiling compounds 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, and / or liquid / liquid extraction steps, and / or solid / liquid separation steps and / or centrifugation steps. 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.

According to a first embodiment, the effluent resulting from the hydroconversion undergoes a decompression separation stage between bubbling bed hydroconversion and fixed bed hydrotreating. This configuration can be qualified as a non-integrated schema.

According to the non-integrated scheme, the separation is preferably carried out in a fractionation section which may firstly comprise a high temperature high pressure separator (HPHT), and optionally a low temperature high pressure separator (HPBT), and / or a distillation atmospheric and / or vacuum distillation. 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 separation is not made according to a precise cutting point, it is more like a flash. If we had to speak in terms of cutting point, we could say that it is between 200 and 400 ° C. Preferably, the so-called heavy fraction is then fractionated by atmospheric distillation into at least one atmospheric distillate fraction containing at least a light fraction of naphtha, kerosene and / or diesel-type hydrocarbons and an atmospheric residue fraction. At least a part of the atmospheric residue fraction can be sent to the hydrotreatment. 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 is advantageously sent at least partly in the hydrotreating step c). Part of the vacuum residue can also be recycled in the hydroconversion step a).

According to a second embodiment, the effluent resulting from the bubbling bed hydroconversion undergoes a separation step without decompression between the hydroconversion and the hydrotreating. This configuration can be described as an integrated schema. According to the integrated scheme, the effluent obtained after step a) is separated (usually in an HPHT separator) into a light fraction and a heavy fraction containing predominantly boiling compounds at least 350 ° C. The separation is not made according to a precise cutting point, it is more like a flash. If we had to speak in terms of cutting point, we could say that it is between 200 and 400 ° C. Preferably, the heavy fraction is then sent to the hydrotreating step. The light fraction may undergo further separation steps, possibly in the presence of the light fraction from the inter-stage separator between the two hydroconversion reactors. Advantageously, it is subjected to an atmospheric distillation which makes it possible to obtain a gaseous fraction, at least a light fraction of hydrocarbons of the naphtha, kerosene and / or diesel type and a vacuum distillate fraction, the latter being able to be sent at least in part in the hydrotreatment step c). Another part of the vacuum distillate may be a part of a fuel oil as a fluxing agent. Another part of the vacuum distillate can still be upgraded by hydrocracking and / or catalytic cracking in a fluidized bed. The separation according to the integrated scheme allows a better thermal integration and results in a saving of energy and equipment. Similarly, this scheme has technical and economic advantages since the high pressure streams will not require an increase in pressure for their subsequent hydrotreatment. This embodiment also makes it possible, by means of its simplified intermediate splitting, to reduce the consumption of utilities and thus the investment cost. The gaseous fractions from the separation step (whether by the integrated or non-integrated scheme) preferably undergo a purification treatment to recover the hydrogen and recycle it to the hydroconversion and / or hydrotreating reactors. It is the same for gaseous effluents from hydrotreating. The gas phase from the optional inter-stage separator can also be added.

The separation step according to the non-integrated diagram or the integrated diagram makes it possible to have two independent hydrogen circuits, one connected to the hydroconversion and the other to the hydrotreatment, and which, if necessary, can be connected to one another.

The addition of hydrogen may be to either or both of the reaction sections, the recycle gas may supply one or the other or both of the reaction sections. The compressor may possibly be in common to both sections. The fact of being able to connect the two hydrogen circuits makes it possible to optimize the management of hydrogen and to limit the investments in terms of compressors and / or purification units of the gaseous effluents. The various embodiments of the hydrogen management that can be used in the present invention are described in the application FR 2957607. The valorization of the various fuel base cuts (LPG, naphtha, kerosene, diesel and / or vacuum gas oil) obtained according to non-integrated or integrated scheme is not the subject of the present invention and these methods are well known to those skilled in the art. The products obtained can be integrated in fuel tanks (also called "pools" fuels 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. Advantageously, the vacuum distillate leaving the bubbling bed after separation can be hydrotreated. This hydrotreated vacuum distillate may be used as a fluxing agent for the fuel oil pool having a sulfur content of less than or equal to 0.5% by weight or may be used directly as fuel with a sulfur content of less than or equal to 0.1% by weight. Part of the atmospheric residue, vacuum distillate and / or vacuum residue may undergo further refining steps, such as hydrocracking, or fluidized catalytic cracking.

Hydrotreatment (step c) The heavy fraction containing compounds boiling at least 350 ° C from the separation step b) is then sent to the hydrotreatment step comprising one or more hydrotreating zones in fixed beds preceded by at least two hydrotreatment guard zones also in fixed beds. Hydroprocessing (HDT) is understood to mean, in particular, hydrodesulphurization (HDS) reactions, hydrodenitrogenation (HDN) reactions and hydrodemetallation (HDM) reactions, but also hydrogenation, hydrodeoxygenation, hydrodearomatization, hydroisomerization, hydrodealkylation, hydrocracking, hydro-deasphalting and Conradson carbon reduction. According to a preferred variant, the hydrotreatment stage comprises a first hydrodemetallation stage comprising one or more hydrodemetallation zones in fixed beds preceded by at least two of said hydrotreatment guard zones, and a second subsequent stage of hydrotreating. hydrodesulphurization comprising one or more hydrodesulphurization zones in fixed beds and in which during the first hydrodemetallization stage, the hydrocarbon and hydrogen feedstock is passed under hydrodemetallation conditions over a hydrodemetallization catalyst. During the second subsequent step, the effluent from the first step is hydrodesulphurized under hydrodesulfurization conditions over a hydrodesulfurization catalyst. This process, known as HYVAHL-FTM is 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. The catalytic beds of the fixed bed reactors, in particular the upper parts of the catalytic beds, and more particularly the upper parts of the first catalytic bed in contact with the charge, are liable to clog rather rapidly, because of the asphaltenes and sediments contained in the charge, which is expressed initially by an increase in the pressure drop and sooner or later requires a stoppage of the hydrotreating unit for the replacement of the catalyst in the main hydrotreatment reactors. The function of the permutable reactors is to filter the sediments and catalyst fines from the hydroconversion step which avoids clogging in the main reactors. Another problem conventionally encountered when using fixed beds is the deactivation of the catalyst because of the large metal deposition that occurs during the hydrotreatment reactions. To compensate for this deactivation, the reactor temperature is then increased. Nevertheless, this increase in temperature favors the deposition of coke. To the deposition of the impurities is added that of the coke, the assembly then tends to deactivate and quickly plug the catalytic system. These phenomena lead to shutdowns of the hydrotreatment units for the replacement of the catalysts and overconsumption of catalysts which the person skilled in the art wishes to minimize. The function of reactive reactors is to protect downstream main hydrotreating reactors by avoiding clogging and / or deactivation. The switchable reactors are thus used to increase the operating cycle of the hydrotreating unit by allowing the deactivated and / or clogged catalyst to be replaced only in cyclically operating swithable reactors without stopping the entire unit for a certain period of time. time. According to the process according to the invention, a high hydrotreatment of the heavy fraction thus becomes possible in order to obtain oil bases with a low sulfur content in particular. The operation of the guard zones in the HDM section is described in FIG. 1 comprising two guard zones (or permutable reactors) Ra and Rb. This hydrotreatment process comprises a series of cycles each comprising four successive stages: a first stage (stage c ') during which the charge successively passes through the reactor Ra and then the reactor Rb; a second stage (stage c); ") during which the charge passes only through the reactor Rb, the reactor Ra being short-circuited for regeneration and / or replacement of the catalyst, - a third step (step cm) during which the charge passes successively through the reactor Rb and then the reactor Ra, a fourth step (step c "") in which the feed passes only through the reactor Ra, the reactor Rb being short-circuited for regeneration and / or replacement of the catalyst. regeneration and / or replacement of the catalyst of a reactor, this reactor is reconnected downstream of the reactor in operation.In step c ') of the process, the effluent leaving the stage of h The boiling-bed conversion is introduced through line (96) and the line (98) having an open valve V1 to the line (100) and the guard reactor Ra enclosing a fixed catalyst bed A. During this period valves V3, V4 and V5 are closed. The effluent from the reactor Ra is sent through the pipe (102), the pipe (104) having an open valve V2 and the pipe (106) into the guard reactor Rb containing a fixed bed B of catalyst. The effluent from the reactor Rb is sent through lines (108) and (110) having an open valve V6 and line (112) to the main hydrotreatment section which will be described later. During step c ") of the method the valves V1, V2, V4 and V5 are closed and the charge is introduced via the line (96) and the line (114) comprising a valve V3 open towards the line (106) and during this period, the reactor effluent Rb is fed through the lines (108) and (110) having an open valve V6 and the line (112) to the main hydrotreatment section. In step c, the valves V1, V2 and V6 are closed and the valves V3, V4 and V5 are open. The charge is introduced via the line (96) and the lines (114) and (116) to the reactor Rb. The reactor effluent Rb is fed through the line (108), the line (116) having an open valve V4 and the line (100) into the guard reactor Ra. The effluent from the reactor Ra is fed through the lines (102) and (118) having an open valve V5 and the line (112) to the main hydrotreatment section. During step c "the valves V2, V3, V4 and V6 are closed and the valves V1 and V5 are open. The charge is introduced via the line (96) and the lines (98) and (100) to the reactor Ra. During this period the effluent from the reactor Ra is sent through the lines (102) and (118) having an open valve V5 and the line (112) to the main hydrotreatment section. The cycle then starts again. The deactivation and / or clogging time varies depending on the feedstock, the operating conditions of the hydroconversion stage, the operating conditions of the hydrotreating step and the catalyst (s) used. It is generally expressed by a fall in the catalytic performance (an increase in the concentration of metals and / or other impurities in the effluent), an increase in the temperature necessary for the maintenance of an activity. of the catalyst or, in the specific case of a clogging, by a significant increase in the pressure drop. The pressure drop yp, expressing a degree of clogging, is continuously measured throughout the cycle on each of the zones and can be defined by a pressure increase resulting from the partially blocked passage of the flow through the zone. Similarly, the temperature is measured continuously throughout the cycle on each of the two zones. In order to define a deactivation and / or clogging time, a person skilled in the art firstly defines a maximum tolerable value of the pressure drop Ap and / or of the temperature as a function of the charge to be treated, of the operating conditions and catalysts. chosen, and from which to proceed with the disconnection of the guard zone. The deactivation and / or clogging time is thus defined as the time when the limit value of the pressure drop and / or the temperature is reached. In the case of a process for the hydrotreatment of heavy fractions, the limit value of the pressure drop is generally between 0.3 and 1 MPa (3 and 10 bar), preferably between 0.5 and 0.8 MPa (5 and 8 bar). . The limit value of the temperature is generally between 400 ° C and 430 ° C, the corresponding temperature, here and in the following text, the measured average temperature of the catalyst bed.

In a preferred embodiment, a catalyst conditioning section is used which allows these guard zones to be turned on, that is to say without stopping the operation of the unit: firstly, a system that functions at moderate pressure (from 10 to 50 bar, but preferably from 15 to 25 bar) makes it possible to perform the following operations on the disconnected guard reactor: washing, stripping, cooling, before discharging the spent catalyst; then heating and sulfurization after loading the fresh catalyst; then another pressurization / depressurization system and gate valves of appropriate technology can effectively switch these guard zones without stopping the unit, that is to say without affecting the operating factor, since all the washing operations, stripping, unloading spent catalyst, reloading fresh catalyst, heating, sulphurization are done on the reactor or guard zone disconnected. Alternatively, a pre-sulphide catalyst can be used in the conditioning section to simplify the permutation procedure while running.

The effluent leaving the reactive reactors is then sent to the main hydrotreating reactors. Each hydrotreatment zone or hydrotreating guard zone contains at least one catalytic bed (for example 1, 2, 3, 4, or 5 catalytic beds). Preferably, each guard zone contains a catalytic bed. Each catalyst bed contains at least one catalytic layer containing one or more catalysts, optionally preceded by at least one inert layer, for example alumina or ceramic in the form of extrudates, balls or pellets. The catalysts used in the catalytic bed (s) may be identical or different.

According to another variant, the heavy fraction obtained in step b) can be subjected, before being sent to the hydrotreatment step, to a separation of sediments and catalyst fines using or less than a rotary filter or at least one basket filter or a centrifuge system such as a hydrocyclone associated with filters or in-line decantation. According to another variant, the heavy fraction obtained in step b) passes through the inlet of each guard zone a filter plate located upstream of the catalytic bed (s) (s) contained in the guard zone. This filter plate, described in patent FR2889973, makes it possible to trap the clogging particles contained in the charge by means of a specific distributor plate comprising a filtering medium.

Alternatively, a co-charge may be introduced with the residual fraction in the hydrotreating step. This co-charge can be chosen from atmospheric residues, vacuum residues from direct distillation, deasphalted oils, aromatic extracts from lubricant base production lines, hydrocarbon fractions or a mixture of hydrocarbon fractions that can be chosen. Among the products resulting from a process of fluid 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 an absolute pressure advantageously between 2 MPa and 35 MPa, preferably between 10 and 35 MPa. and 20 MPa. The temperature is usually adjusted according to the desired level of hydrotreatment. Most often the overall WH is in the range of 0.1 hr-1 to hr-1 and preferably 0.1 hr-1 to hr-1. . The amount of hydrogen mixed with the feed is usually 100 to 5000 normal cubic meters (Nm3) per cubic meter (m3) of liquid feed and most often 200 to 2000 Nm3 / m3 and preferably 300 to 1500 Nm3 / m3. Usually, the hydrotreating step is carried out industrially in one or more liquid downflow reactors. The operating conditions of the reactive reactors are generally identical to those of the main hydrotreating reactors. The value of the VVH of each switchable reactor in operation is preferably from 0.25 to 4 h -1 and most often from 1 to 2 h -1. The global WH value of the permutable reactors and that of each reactor is chosen so as to achieve the maximum of HDM while controlling the reaction temperature (limitation of exothermicity).

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, 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 chosen 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 concentration of phosphorus pentoxide P205 is usually between 0 or 0.1% and 10% by weight. The concentration of boron trioxide B205 is usually from 0 to 0.1% to 10% by weight. The alumina used is usually alumina or 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 Group VIB on metal (or metals) of the group VIII is generally from 20 to 1 and most often from 10 to 2. In the case of a hydrotreatment step including a step of HDM then a step of HDS, the most used is often specific catalysts adapted to each step.

Catalysts that can be used in the HDM step are, for example, indicated in patents EP113297, EP113284, US5221656, US5827421, US7119045, US5622616 and US5089463. HDM catalysts are preferably used in the reactive reactors. Catalysts usable in the HDS step 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 HDM and HDS for both the HDM section and the HDS section as described in patent FR2940143. Prior to the injection of the feed, the catalysts used in the process according to the present invention are preferably subjected to a sulfurization treatment (in-situ or ex-situ). Separation of the hydrotreatment effluent (stage d) In a current embodiment of the invention, the effluent obtained in stage c) is at least partly, and often entirely, sent to a stage of separation d), comprising atmospheric distillation and vacuum distillation. The effluent of the hydrotreatment stage 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 constitute in part at least the bases of low-sulfur fuel oils having a sulfur content of less than or equal to 0.5% wt. in sediment after aging less than or equal to 0.1%. The vacuum distillate fraction may constitute a fuel oil base having a sulfur content of less than or equal to 0.1% by weight. Part of the vacuum residue can also be recycled in the hydroconversion step a).

The step of separating step b) according to the integrated scheme, according to which the heavy fraction is recovered for the hydrotreatment and a light fraction, may be distinct from the separation step d), but preferably the fraction light obtained without decompression in the separation step b) is sent in the separation step d). Although the oil bases produced according to the present process contain very little sediment, an additional filtration step may be provided.

Catalytic cracking (step e) According to one variant, at least part of the vacuum distillate fraction and / or the vacuum residue fraction resulting from step d) is / are sent to a section of catalytic cracking, referred to as step e), in which it is / are treated under conditions making it possible to produce a gaseous fraction, a gasoline fraction, a diesel fraction and a residual fraction. In one embodiment of the invention, at least a portion of the residual fraction obtained in the catalytic cracking step e), often referred to as a slurry fraction by a person skilled in the art, is recycled at the inlet of the step e) and / or a) and / or c). The residual fraction can also be at least partly or even entirely sent to the heavy fuel storage area of the refinery. In a particular embodiment of the invention, part of the gas oil fraction (or LCO) and / or part of the residual fraction (containing the HCO) obtained during this step e) can be used to form fluxing bases. which will be mixed with the fuel bases obtained by the present process. The catalytic cracking step e) is most often a catalytic cracking step in a fluidized bed, for example according to the process developed by the Applicant called R2R. This step can be carried out in a conventional manner known to those skilled in the art under the appropriate cracking conditions in order to produce lower molecular weight hydrocarbon products. This step may use heat exchange processes and devices, in particular solid particles, in order to reduce the temperature of the catalyst at the inlet of the reaction zone. Descriptions of operation and catalysts for use in fluidized bed cracking in this step e) are described, for example, in US-A-4695370, EP-B-184517, US-A-4959334, B-323297, US-A-4965232, US-A-5120691, US-A-5344554, US-A-5449496, EP-A-485259, US-A-5286690, US-A-5324696, EP-B-542604 and US Pat. EP-A-699224 whose descriptions are considered incorporated herein by the mere fact of this mention. The fluidized bed catalytic cracking reactor is operable with upflow or downflow. Although this is not a preferred embodiment of the present invention, it is also conceivable to perform catalytic cracking in a moving bed reactor. Particularly preferred catalytic cracking catalysts are those which contain at least one zeolite usually in admixture with a suitable matrix such as, for example, alumina, silica, silica-alumina. In order to constitute the fuel oil which meets the viscosity recommendations which must be less than or equal to 380 cSt (50 ° C.), the oil bases obtained by the present process can be mixed, if necessary, with fluxing bases in a controlled manner. to achieve the target viscosity of the desired fuel grade. The fluxing bases may be chosen from catalytic cracking light cutting oils (LCO), catalytic cracking heavy-cutting oils (HCO), catalytic cracking residue, kerosene, gas oil, vacuum distillate, and / or or a decanted oil (DO). Preferably, kerosene, gas oil and / or vacuum distillate obtained in the separation step b) of the process after hydroconversion or gas oil and / or a fraction of the residual fraction obtained will be used ( s) in the catalytic cracking step e). DESCRIPTION OF THE FIGURES The following figures show advantageous embodiments according to the invention. The installation and the method according to the invention are essentially described. We will not repeat the operating conditions described above. FIG. 2 describes the process according to the invention with intermediate separation with decompression (non-integrated scheme). In FIG. 2, the charge (10), preheated in the chamber (12), mixed with recycled hydrogen (14) heated in the enclosure (16), and introduced via the pipe (18) at the bottom of the first bubbling bed reactor (20) operating at an upward flow of liquid and gas and containing at least one hydroconversion catalyst. The reactor (20) usually comprises a recirculation pump (22) for maintaining the bubbling bed catalyst by continuously recycling at least a portion of the liquid withdrawn into the upper part of the reactor and reinjected at the bottom of the reactor. The hydrogen can also be introduced into the furnace (12) thus eliminating the enclosure (16). The hydrogen supply is carried out by recycled hydrogen from the process (64), supplemented with makeup hydrogen (24). The addition of fresh catalyst can be done from the top of the reactor (not shown). The catalyst supply can be carried out periodically or continuously. The spent catalyst can be withdrawn from the bottom of the reactor (not shown) to either be removed or regenerated to remove carbon and sulfur prior to reinjection from the top of the reactor. The catalyst withdrawn from the bottom of the first partially used reactor can also be transferred directly to the top of the second hydroconversion reactor (40) (cascading) (not shown). Optionally, the converted effluent (26) from the reactor (20) may be separated from the light fraction (28) in an inter-stage separator (30). All or part of the effluent (32) from the first hydroconversion reactor (20) is advantageously mixed with additional hydrogen (34), if necessary preheated (not shown). This mixture is then injected via the pipe (36) into a second bubbling bed hydroconversion reactor (40) operating with an upward flow of liquid and gas containing at least one hydroconversion catalyst. The operating conditions, in particular the temperature, in this reactor are chosen to reach the desired conversion level, as previously described. Addition and removal of the catalyst is carried out in the same manner as described for the first reactor. The reactor (40) usually comprises a recirculation pump (38) for maintaining the bubbling bed catalyst by continuously recycling at least a portion of the liquid withdrawn into the upper part of the reactor and reinjected at the bottom of the reactor.

The effluent treated in the reactor (40) is sent via line (42) into a high temperature high pressure separator (HPHT) (44) from which a gaseous fraction (46) and a liquid fraction (48) are recovered. The cutting point is usually between 200 and 400 ° C. The gaseous fraction (46) is sent, optionally mixed with the light fraction (28) from the optional inter-stage separator (30) between the two hydroconversion reactors, generally via an exchanger (not shown) or an air cooler (50). ) for cooling to a low temperature high pressure separator (HPBT) (52) from which a gaseous fraction (54) containing the gases (H2, H2S, NH3, C1-C4 hydrocarbons, ...) and a liquid fraction is recovered. (56). The gaseous fraction (54) of the low temperature high pressure separator (HPBT) (52) is treated in the hydrogen purification unit (58) from which hydrogen (60) is recovered for recycling via the compressor. (62) and the line (64) to the reactors (20) and / or (40). Gases containing undesirable nitrogen and sulfur compounds are removed from the plant (stream (66)). The liquid fraction (56) of the low temperature high pressure separator (HPBT) (52) is expanded in the device (68) and sent to the fractionation system (70). Optionally, a medium pressure separator (not shown) after the expander (68) can be installed to recover a gaseous fraction that is sent to the purification unit (58) and a liquid phase that is supplied to the fractionation section (70). ). The liquid fraction (48) from the high temperature high pressure separation (HPHT) (44) is expanded in the device (72) and sent to the fractionation system (70). Of course, the fractions (56) and (48) can be sent together, after expansion, to the system (70). According to a variant not shown, the fractionations (70) and (172) may be common and treated all the light fractions including that coming from the inter-stage separator. The fractionation system (70) comprises an atmospheric distillation system for producing a gaseous effluent (74), at least a so-called light fraction (76) and in particular containing naphtha, kerosene and diesel and an atmospheric residue fraction (78) . Part of the atmospheric residue fraction may be sent via line (80) into the hydrotreatment reactors. All or part of the atmospheric residue fraction (78) is sent to a vacuum distillation column (82) to recover a fraction (84) containing the vacuum residue containing the fines and sediments and a vacuum distillate phase (86) containing vacuum gas oil.

The vacuum residue fraction (84), optionally mixed with a portion of the atmospheric residue fraction (80), is mixed with recycled hydrogen (88) optionally supplemented with makeup hydrogen (90). It optionally passes through an oven (92) and a filter (94). Optionally, a co-charge (198) may be introduced. The effluent thus heated and filtered is introduced via the line (96) at the top of the system of the reactive reactors of the hydrotreating step. The operation of the permutable reactors has been described in FIG. 1. The effluent leaving the guard reactor (s) is optionally remixed with hydrogen (91) arriving via the line (112) in a main HDM reactor (120). ) which contains a fixed bed (122) of catalyst. For reasons of readability, a single HDM and HDS reactor is shown in the figure, but the HDM and HDS section conventionally comprises several reactors of HDM and HDS in series. If necessary, the recycled and / or auxiliary hydrogen can also be introduced into the hydrotreating reactors between the different catalytic beds (quench) (not shown). The effluent from the HDM reactor is withdrawn through line (124) and sent to the first HDS reactor (130) where it passes through a fixed bed (132) of catalyst. The effluent is sent via line (134) into a high temperature high pressure (HPHT) separator (136) from which a gaseous fraction (138) and a liquid fraction (140) are recovered. The gaseous fraction (138) is sent generally via an exchanger (not shown) or an air cooler (142) for cooling to a low temperature high pressure separator (HPBT) (144) from which a gaseous fraction (146) containing the gases (H2, H2S, NH3, C1-C4 hydrocarbons, ...) and a liquid fraction (148).

The gaseous fraction (146) of the low temperature high pressure separator (HPBT) (144) is treated in the hydrogen purification unit (150) from which hydrogen (152) is recovered for recycling via the compressor. (154) and the line (156) to the hydrotreatment section. Gases containing undesirable nitrogen and sulfur compounds are removed from the plant (stream (158)).

The liquid fraction (148) of the low temperature high pressure separator (HPBT) (144) is expanded in the device (160) and sent to the fractionation system (172). Optionally, a medium pressure separator (not shown) after the expander (160) can be installed to recover a vapor phase that is sent to the purification unit (150) and a liquid phase that is supplied to the fractionation section (172). ). The liquid fraction (140) from the high temperature high pressure separation (HPHT) (136) is expanded in the device (174) and sent to the fractionation system (172). Of course, the fractions (148) and (140) can be sent together, after expansion, to the system (172). The fractionation system (172) comprises an atmospheric distillation system for producing a gaseous effluent (176), at least a so-called light fraction (178) and containing in particular naphtha, kerosene and diesel and an atmospheric residue fraction (180). ). Part of the atmospheric residue fraction (180) can be withdrawn via line (182) to form the desired oil bases. All or part of the atmospheric residue fraction (180) is sent to a vacuum distillation column (184) to recover a fraction containing the vacuum residue (186) and a vacuum distillate fraction (188) containing vacuum gas oil. . At least a portion of the vacuum residue fraction (186) is preferably recycled via line (190) to the non-hydroconversion stage to increase the yield. FIG. 3 describes the process according to the invention with an intermediate separation without decompression (integrated diagram). In FIG. 3, the differences between the installation and the process (separation step) will be essentially described with respect to the process according to FIG. 2, the hydroconversion, hydrotreatment and separation steps after hydrotreating (and their reference signs) being strictly identical to those of FIG. 2. The effluent treated in the hydroconversion reactors is sent via line (42) into a high temperature high pressure separator (HPHT) (44) from which recovers a lighter fraction (46) and a residual fraction (48). The cutting point is usually between 200 and 400 ° C. The residual fraction (48) is sent directly after a possible passage through a filter (94) in the hydrotreatment section. The lighter fraction (46) is sent, optionally mixed with the gas fraction (28) from the optional inter-stage separator (30) between the two hydroconversion reactors, generally via a heat exchanger (no. shown) or an air cooler (50) for cooling to a low temperature high pressure separator (HPBT) (52) from which a gaseous fraction (54) containing the gases (H2, H2S, NH3, C1-C4 hydrocarbons) is recovered. ..) and a liquid fraction (56). The gaseous fraction (54) of the low temperature high pressure separator (HPBT) (52) is treated in the hydrogen purification unit (58) from which hydrogen (60) is recovered for recycling via the compressor. (156) and lines (88) and (64) to the hydrotreatment section and / or the hydroconversion section. Gases containing undesirable nitrogen, sulfur and oxygen compounds are removed from the plant (stream (66)). In this configuration, only one compressor (156) is used to supply all the reactors requiring hydrogen. The liquid fraction (56) of the low temperature high pressure separator (HPBT) (52) is expanded in the device (68) and sent to the fractionation system (70). Optionally, a medium pressure separator (not shown) after the expander (68) can be installed to recover a gaseous fraction that is sent to the purification unit (58) and a liquid fraction that is supplied to the fractionation section (70). ). The fractionation system (70) comprises an atmospheric distillation system for producing a gaseous effluent (74), at least a so-called light fraction (76) and containing in particular naphtha, kerosene and diesel and an atmospheric residue fraction (192) . Part of the atmospheric residue fraction can be sent via line (192) into the hydrotreating reactors while another part of the atmospheric residue fraction (194) can be sent to another process (hydrocracking or FCC or hydrotreatment) . Example The following example illustrates the invention without limiting its scope. A vacuum residue is treated (RSV Ural), see Table 1. The feedstock is subjected to a hydroconversion stage in two successive bubbling bed reactors. The operating conditions as well as the yield, the sulfur content, the viscosity of the effluent leaving the hydroconversion section are given in Tables 2 and 3.

Table 1: Load characteristics Section RSV Ural 530+ Density 15/4 1.002 Sulfur% mass 2.55 Carbon Conradson 16 Asphaltenes C7 (% mass) 3.8 NI + V ppm 253 Table 2: Operating conditions bubbling bed section NiMo catalyst on Alumina T bubbling bed R1 (° C) 415 T bubbling bed R2 (° C) 417 Pressure, MPa 18 WH * (h-1) 0.243 H2 inlet (Nm3 / m3 feed) 348 Table 3: Yields, sulfur content and viscosity boiling bed section ( % w / w) Products Yield S Viscosity at 50 ° C (wt%) (wt%) (Cst) NH3 0.26 0 H2S 2.11 94.12 C1-C4 (gas) 2.06 0 Naphtha (PI-180 ° C) 7.30 0.05 Diesel ( 180-350 ° C) 19.80 0.11 Vacuum distillates (350-480 ° C) 24.50 0.55 44 Vacuum residue (480 + ° C) 45.60 0.89 5000 Residue (350 ° C +) - Fixed bed load 70.10 0.77 400 with H2 consumed representative 1.63% of the charge The effluent from the hydroconversion is then separated. The heavy fraction (350 ° C + fraction) is then sent to the hydrotreatment section including two permutable reactors. The operating conditions as well as the yield, the sulfur content and the viscosity of the effluent leaving the hydrotreatment section are given in Tables 4 and 5.

Table 4: Operating conditions fixed bed CoMoNi catalyst on Alumina T (° C) 380 Pressure, MPa 15 WH (Sm3 / h intermediate feed / m3 of cata) 0.15 H2 / HC (Nm3 / h H2 / Sm3 intermediate feed) 1000 Table 5 : Yield, sulfur content and viscosity fixed bed section (% w / effluent hydroconversion) Products Yield S Viscosity at (% wt) (wt%) 50 ° C (Cst) NH3 0.48 0 H2S 0.77 94.12 C1-C4 (gas) 1.07 0 Naphtha (Pl-150 ° C) 1.82 0.01 Diesel (150-375 ° C) 6.98 0.02 Vacuum distillates (375-550 ° C) 47.40 0.09 120 Vacuum residue (550 + ° C) 42.68 0.46 7000 with H2 consumed representative 1.20% of Intermediate Load Table 6 summarizes performance performance, sulfur content and viscosity of the effluent over the complete hydroconversion and hydrotreating sequence.

Table 6: Yields, Sulfur Content and Viscosity Complete Sequencing (% w / w) Yield Yield (% wt) S (% wt) Visco 50 ° C (Cst) NH3 0.59 0 H2S 2.65 94.12 C1-C4 (gas) 2.81 0 Naphtha (PI-180 ° C) ex-bubbling bed 7.30 0.05 Naphtha (PI-150 ° C) ex-fixed bed 1.28 0.01 Gas oil (180-350 ° C) ex-bubbling bed 19.80 0.11 Gas oil (150-375 ° C) ) ex-fixed bed 4.89 0.02 Vacuum distillates (375-550 ° C) ex-fixed bed 33.23 0.09 120 Vacuum residue (550 + ° C) ex-fixed bed 29.92 0.46 7000 with H2 consumed representing 2.47% of the load For To obtain a bunker oil meeting specifications, the fuel oil consists of 50% vacuum distillates ex-fixed bed, 48% vacuum residue ex-fixed bed and 2% ex-fixed bed diesel. It has a viscosity of 380 cSt at 50 ° C, a sulfur content of 0.27 wt% and a sediment content of <0.1 wt%. All the vacuum distillate ex-fixed bed is not used and it can constitute directly a fuel 0.1% S. 15 20

Claims (15)

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 comprising the following steps: a. a step of hydroconversion in the presence of hydrogen in at least one reactor containing a catalyst supported in a bubbling bed, b. a step of separating the effluent obtained at the end of step a) into at least a light fraction of hydrocarbon base fuels and a heavy fraction containing predominantly compounds boiling at least 350 ° C, c. a step of hydrotreating in a fixed bed of at least a portion of the heavy fraction resulting from step b) in which the heavy hydrogen fraction is passed under hydrotreatment conditions over a catalyst of hydrotreatment and wherein the hydrotreatment step comprises one or more hydrotreatment zones in fixed beds preceded by at least two hydrotreatment guard zones also in fixed beds, arranged in series for cyclic use consisting of successive repetition of steps c ") and c" ') defined hereinafter: c') a step, in which the guard zones are used together for a time at most equal to the time of deactivation and / or clogging of the one of them, c ") a step, during which the deactivated and / or clogged guard zone is short-circuited and the catalyst contained therein is regenerated and / or replaced by fresh catalyst, and during which the or the ones the guard zone (s) are used, and c "') a step, during which the guard zones are used together, the guard zone whose catalyst has been regenerated in the previous step being reconnected and said step being continued for a period at most equal to the time of deactivation and / or clogging of one of the guard zones. 2. The method of claim 1 wherein the hydrotreatment step comprises a first hydrodemetallation step comprising one or more fixed bed hydrodemetallation zones preceded by at least two of said hydrotreatment guard zones and a second step. hydrodesulphurization process comprising one or more hydrodesulphurization zones in fixed beds and in which during the first hydrodemetallation stage, the hydrocarbon and hydrogen charge is passed under hydrodemetallation conditions on a hydrodemetallization zone. hydrodemetallization catalyst, and then during the second subsequent step is passed, under hydrodesulphurization conditions, the effluent of the first step on a hydrodesulphurization catalyst. 3. Method according to one of the preceding claims wherein during step a) the treatment in the presence of hydrogen is carried out under an absolute pressure of 2.5 to 35 MPa at a temperature of 330 to 550 ° C. with a space velocity of 0.1 to 10 hours and the amount of hydrogen mixed with the feed is 50 to 5000 Nm 3 / m 3. 4. Method according to one of the preceding claims wherein the step c) of hydrotreating is carried out under an absolute pressure of about 2 to 35 MPa, at a temperature of 300 to 500 ° C with a space velocity of 0 1 to 5 hr and the amount of hydrogen mixed with the feed is 100 to 5000 Nm3 / m3. 5. Method according to one of the preceding claims wherein the hydrocarbon feedstock 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, whether taken alone or as a mixture. 6. Method according to one of the preceding claims wherein the separation step b) is carried out without decompression, the effluent of step a) is sent to a fractionation section having a cutting point between 200 and 400 ° C to obtain a light fraction and said heavy fraction, said heavy fraction being sent to the hydrotreating step while the light fraction is subjected to an atmospheric distillation to obtain a gaseous fraction, at least a light fraction of hydrocarbons of the naphtha, kerosene and / or diesel type and a vacuum distillate fraction, the last being at least partly sent to the hydrotreating step c). 7. Method according to one of claims 1 to 5 wherein the separation step b) is performed with decompression, the effluent of step a) is sent to a fractionation section having a cutting point between 200 and 400 ° C making it possible to obtain a light fraction and said heavy fraction, and in which the heavy fraction is fractionated by atmospheric distillation into at least one atmospheric distillate fraction containing at least a light fraction of hydrocarbons of the naphtha, kerosene and / or diesel and an atmospheric residue fraction, said fraction of the atmospheric residue being at least partially fractionated by vacuum distillation into a vacuum distillate fraction containing vacuum gas oil and a vacuum residue fraction, at least a portion of said atmospheric residue fraction and / or or the vacuum residue fraction being sent to the hydrotreating step c). 8. Method according to one of the preceding claims wherein the heavy fraction obtained in step b) is subjected, before being sent to the hydrotreating step, to a separation of sediments and catalyst fines, in using or less a rotary filter or at least one basket filter or a centrifugal system such as a hydrocyclone associated with filters or in-line decantation, or wherein the heavy fraction obtained in step b) passes through at the entrance of each guard zone a filter plate located upstream of the catalytic bed (s) contained in the guard zone. 2 9 8 16 5 9 34 9. Method according to one of the preceding claims wherein at least a portion of the effluent obtained in step c) is sent in a separation step, called step d), comprising an atmospheric distillation and a vacuum distillation, and wherein the effluent from the hydrotreating step is fractionated by atmospheric distillation into a gaseous fraction, at least one atmospheric distillate fraction containing the fuel bases (naphtha, kerosene and / diesel) and an atmospheric residue fraction, at least a portion of the atmospheric residue is then fractionated by vacuum distillation into a vacuum distillate fraction containing vacuum gas oil and a vacuum residue fraction. 10 10. The method of claim 9 wherein the light fraction obtained without decompression in the separation step b) is sent in the separation step d). 15 11. The method of claim 9 wherein a portion of the vacuum residue fraction is recycled in the hydroconversion step a). The process according to claim 9 wherein at least a portion of the vacuum distillate fraction and / or the vacuum residue fraction is fed to a catalytic cracking section, referred to as step e), wherein it is / are treated under conditions that make it possible to produce a gaseous fraction, a gasoline fraction, a diesel fraction and a residual fraction. The process according to claim 12 wherein at least a portion of the residual fraction obtained in the catalytic cracking step e) is recycled to the input of step e) and / or a) and / or c). . The process according to claim 9 wherein the atmospheric residue and / or the vacuum distillate and / or the vacuum residue are mixed with fluxing bases selected from catalytic cracking light cutting oils, heavy cutting oils. catalytic cracking, catalytic cracking residue, kerosene, gas oil, vacuum distillate, and / or a decanted oil. 15. The method of claim 14 wherein the fluxing base is selected from kerosene, gas oil and / or vacuum distillate obtained in the separation step b) of the process after hydroconversion or diesel and / or a fraction of the residual fraction obtained in the catalytic cracking step e).