EP1312661A1 - Procédé de conversion de fractions lourdes petrolieres incluant un lit bouillonnant pour produire des distillats moyens de faible teneur en soufre - Google Patents
Procédé de conversion de fractions lourdes petrolieres incluant un lit bouillonnant pour produire des distillats moyens de faible teneur en soufre Download PDFInfo
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- EP1312661A1 EP1312661A1 EP02290433A EP02290433A EP1312661A1 EP 1312661 A1 EP1312661 A1 EP 1312661A1 EP 02290433 A EP02290433 A EP 02290433A EP 02290433 A EP02290433 A EP 02290433A EP 1312661 A1 EP1312661 A1 EP 1312661A1
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- hydrogen
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- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G49/00—Treatment of hydrocarbon oils, in the presence of hydrogen or hydrogen-generating compounds, not provided for in a single one of groups C10G45/02, C10G45/32, C10G45/44, C10G45/58 or C10G47/00
- C10G49/007—Treatment of hydrocarbon oils, in the presence of hydrogen or hydrogen-generating compounds, not provided for in a single one of groups C10G45/02, C10G45/32, C10G45/44, C10G45/58 or C10G47/00 in the presence of hydrogen from a special source or of a special composition or having been purified by a special treatment
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- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
- C10G2400/06—Gasoil
Definitions
- the present invention relates to a method and an installation for the treatment of charges heavy hydrocarbons containing sulfur impurities. It concerns a process making it possible to at least partially convert such a charge of hydrocarbons, for example a vacuum distillate obtained by direct distillation of crude oil, in diesel fuel meeting the 2005 sulfur specifications i.e. having less than 50 ppm sulfur, and a product heavier which can advantageously be used as a filler for catalytic cracking (such as catalytic cracking in a fluid bed).
- the treated charges are heavy, that is to say that 80% by weight boils above 340 ° C.
- Their initial boiling point is usually at least 340 ° C, often at least 370 ° C see at least 400 ° C.
- the method makes it possible to treat charges having a final boiling temperature of at least 450 ° C and which can even go beyond 700 ° C.
- the sulfur content is at least 0.05% wt, often at least 1% and very often at least minus 2% or even at least 2.5% wt. Loads of 3% or more sulfur are suitable well in this process.
- the fillers which can be treated in the context of the present invention are distillates under direct distillation vacuum, vacuum distillates from conversion process such as example those from coking, from hydroconversion in a fixed bed (such as those from HYVAHL® processes for treating heavy products developed by the applicant) or hydrotreating processes for heavy in a bubbling bed (such as those from the H-OIL® processes), or deasphalted oils with solvent (for example with propane, butane, or with pentane) coming from the deasphalting of residue under direct distillation vacuum, or of residues from the HYVAHL® and H-OIL® processes.
- the charges can also be formed by mixture of these various fractions.
- the fillers which are treated are preferably vacuum distillates, fillers DAO type, i.e. containing metals and / or asphalenes, for example more than 10 ppm of metals and more than 1000 ppm of asphaltenes.
- Hydroconversion stage a where the charge described below is treated in a bubbling bed reactor.
- Said hydrocarbon feedstock is treated in a treatment section in the presence of hydrogen said section comprising at least one three-phase reactor, containing at least a hydroconversion catalyst, the mineral support of which is at least partly amorphous, in bubbling bed, operating with an upward flow of liquid and gas, said reactor comprising at least one means for withdrawing the catalyst from said reactor located at proximity to the bottom of the reactor and at least one means of adding fresh catalyst to said reactor located near the top of said reactor.
- VVH hourly space velocity
- the amount of hydrogen mixed with the feed is usually about 50 to about 5000 normal cubic meters (Nm 3 ) per cubic meter (m 3 ) of liquid feed and most often about 100 to about 1500 Nm 3 / m 3 and preferably from about 200 to about 500 Nm 3 / m 3 .
- the conversion of the charge into fractions lighter than 360 ° C is usually between 10-80% w / w, most often 25-60%.
- a conventional granular hydroconversion catalyst can be used comprising, on an amorphous support, at least one metal or metal compound having a hydrodehydrogenating function.
- This catalyst can be a catalyst comprising metals from group VIII, for example nickel and / or cobalt, most often in combination with at least one metal from group VIB, for example molybdenum and / or tungsten.
- One can for example use 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 can also contain other compounds and for example oxides chosen from the group formed by boron oxide, zirconia, titanium oxide, phosphoric anhydride. Most often an alumina support is used and very often an alumina support doped with phosphorus and possibly boron.
- the concentration of phosphoric anhydride P 2 O 5 is usually less than about 20% by weight and most often less than about 10% by weight. This P 2 O 5 concentration is usually at least 0.001% by weight.
- the concentration of boron trioxide B 2 O 3 is usually about 0 to about 10% by weight.
- the alumina used is usually a ⁇ or ⁇ alumina. This catalyst is most often in the form of an extrudate.
- the total content of group VI and VIII metal oxides is often from about 5 to about 40% by weight and in general from about 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 generally from about 20 to about 1 and most often from about 10 to about 2.
- the used catalyst is partly replaced by fresh catalyst by drawing off at the bottom of the reactor and introduction of fresh or new catalyst at the top of the reactor at intervals of regular time, that is to say for example by puff or almost continuously.
- the replacement rate of the catalyst spent by fresh catalyst can be for example about 0.05 kilogram to about 10 kilograms per cubic meter of load.
- This racking and replacement are carried out using devices allowing the continuous operation of this stage hydroconversion.
- the unit usually has a recirculation pump allowing the catalyst to be maintained in a bubbling bed by continuous recycling of at least part of the liquid withdrawn from step a) and reinjected into the bottom of the zone in step a). he it is also possible to send the spent catalyst withdrawn from the reactor to a zone of regeneration in which we remove the carbon and the sulfur it contains and then return this regenerated catalyst in step b) of hydroconversion.
- Step b) in which said hydroconverted effluent is subjected at least in part, and preferably in whole, to one or more separations.
- this step is to separate the gases from the liquid, and in particular to recover the hydrogen and most of the hydrogen sulfide H 2 S formed in step a), then obtain a liquid effluent free of H 2 S dissolved.
- the liquid effluent devoid of H 2 S and optionally added with stabilized naphtha is distilled to obtain at least one distillate fraction including a diesel fraction, and at least one fraction heavier than diesel.
- the distillate cut can be a diesel cut or a diesel cut mixed with naphtha. She feeds step c).
- the heavier liquid fraction than the diesel type fraction can optionally be sent in a catalytic cracking process in which it is advantageously treated under conditions making it possible to produce a gaseous fraction, a petrol fraction, a diesel fraction and a heavier fraction than the diesel fraction often called the skilled tradesman fraction slurry.
- this liquid fraction heavier than the diesel fraction can be used as a low sulfur industrial fuel or as a thermal cracking charge.
- the naphtha When the naphtha is not sent to the mixture with the diesel in step c), it is distilled.
- the the naphtha fraction obtained can advantageously be separated into heavy gasoline, which preferably a charge for a reforming process, and in light gasoline which, from preferably will be subjected to a process for isomerization of paraffins.
- the diesel cut most often has a sulfur content between 100 and 500 ppm weight and the gasoline cut most often has a content in sulfur of at most 200 ppm by weight.
- the diesel cut therefore does not respond to 2005 sulfur specifications.
- the other characteristics of diesel are also at a low level; for example, cetane is around 45 and the aromatics content is higher at 20% wt.
- the conditions are generally chosen so that the point initial boiling of the heavy fraction is from about 340 ° C to about 400 ° C and preferably from about 350 ° C to about 380 ° C and for example about 360 ° C.
- the final boiling point is between about 120 ° C and 180 ° C.
- Diesel is located between naphtha and the heavy fraction.
- Step c) in which at least a part, and preferably the whole of the distillate fraction, undergoes hydrotreatment in order to reduce the sulfur content below 50 ppm by weight, and most often below 10 ppm.
- This fraction of hydrocarbons can for example be chosen from the group formed by LCO (Light cycle oil from catalytic cracking in a fluidized bed).
- the temperature in this step is usually from about 300 to about 500 ° C, often from about 300 ° C to about 450 ° C and very often from about 350 to about 420 ° C. This temperature is usually adjusted as a function of the desired level of hydrodesulfurization and / or saturation of the aromatics and must be compatible with the desired cycle time.
- the hourly space velocity (VVH) and the partial pressure of hydrogen are chosen according to the characteristics of the product to be treated and the desired conversion. Most often the VVH is in a range from about 0.1 h -1 to about 10 h -1 and preferably 0.1 h -1 - 5 h -1 and advantageously from 0.2 h -1 to about 2 h - 1 .
- the total amount of hydrogen mixed with the charge is usually about 200 to about 5,000 normal cubic meters (Nm 3 ) per cubic meter (m 3 ) of liquid charge and most often about 250 to 2,000 Nm 3 / m 3 and preferably around 300 to 1500 Nm 3 / m 3 .
- the partial pressure of hydrogen sulfide is preferably less than 0.05 MPa, preferably at 0.03 MPa, even better at 0.01 MPa.
- the ideal catalyst In the hydrodesulfurization zone, the ideal catalyst must have a strong hydrogenating power so as to achieve a deep refining of the products and to obtain a significant reduction in the sulfur.
- the hydrotreating zone operates at temperature relatively low which goes in the direction of a deep hydrogenation therefore of a improvement in the aromatic content of the product and its cetane and a limitation of the coking. It would not go beyond the scope of the present invention to use in the area hydrotreating simultaneously or successively a single catalyst or several different catalysts. Usually this step is carried out industrially in one or more reactors with one or more catalytic beds and downdraft of liquid.
- At least one fixed bed of hydrotreatment catalyst comprising a hydrodehydrogenating function and an amorphous support.
- a catalyst whose support is for example chosen from the group formed by alumina, silica, silica-aluminas, magnesia, clays and mixtures of at least two of these minerals.
- This support can also contain other compounds and by example of the oxides chosen from the group formed by boron oxide, zirconia, titanium, phosphoric anhydride. Most often we use an alumina support and better alumina n or ⁇ .
- the hydrogenating function is provided by at least one metal from group VIII and / or group VIB.
- the total content of metal oxides of groups VI and VIII is often from about 5 to about 40% by weight and generally from about 7 to 30% by weight and the weight ratio expressed as metal oxide between metal (metals) of group VI on metal (or metals) of group VIII is generally about 20 to about 1 and most often from about 10 to about 2.
- the ideal catalyst must have a strong hydrogenating power in order to achieve a deep refining of the products and to obtain a significant reduction in sulfur.
- This catalyst can be a catalyst comprising metals from group VIII, for example nickel and / or cobalt, most often in combination with at least one metal from group VIB, for example molybdenum and / or tungsten.
- a catalyst based on NiMo will be used.
- the desulfurization of a NiMo-based catalyst is greater than that of a CoMo catalyst because the shows a more important hydrogenating function than the second.
- a catalyst comprising from 0.5 to 10% by weight of Nickel and preferably 1 to 5% by weight of Nickel (expressed as nickel oxide NiO) and from 1 to 30% by weight of molybdenum and preferably 5 20% by weight of molybdenum (expressed as molybdenum oxide (MoO 3 ) on an amorphous mineral support.
- the catalyst can also contain an element such as phosphorus and / or boron. This element may have been introduced into the matrix or may have been deposited on the support. We can also deposit silicon on the support, alone or with phosphorus and / or boron.
- the concentration of said element is usually less than about 20% by weight (calculated oxide) and most often less than about 10% by weight and it is usually at least 0.001% by weight.
- concentration of boron trioxide B 2 O 3 is usually about 0 to about 10% by weight.
- Preferred catalysts contain silicon deposited on a support (such as alumina), optionally with P and / or B also deposited, and also containing at least one metal of GVIII (Ni, Co) and at least one metal of GVIB (W, Mo).
- a support such as alumina
- P and / or B also deposited, and also containing at least one metal of GVIII (Ni, Co) and at least one metal of GVIB (W, Mo).
- the gasolines and the gas oils resulting from the conversion process are very refractory to hydrotreatment if they are compared to gas oils produced directly from the atmospheric distillation of crudes.
- the critical point is the conversion of species the most refractory, particularly the di and trialkylated dibenzothiophenes or more for which the access of the sulfur atom to the catalyst is limited by the alkyl groups.
- the way of hydrogenation of an aromatic cycle before the desulfurization by breaking the Csp3-S bond is faster than direct desulfurization by rupture of the Csp2-S bond.
- Conversion gas oils therefore require very severe operating conditions to meet future sulfur specifications. If we want to hydrotreat these diesel fuels conversion under operating conditions allowing investment to be maintained moderate with a reasonable cycle time of the hydrotreatment catalyst, a optimization of the integration of process equipment is necessary.
- the amount of make-up hydrogen introduced in this step c) is greater than the chemical consumption of hydrogen necessary to obtain the performances fixed in the operating conditions set for this step c).
- the amount of make-up hydrogen is at least equal to the difference in the material balance, the difference found corresponds approximately to the chemical consumption hydrogen.
- a suitable means of measuring the hydrogen content in the feed or the liquid effluent is the 1 H NMR measurement.
- chromatographic analysis is suitable for the gaseous effluent.
- step c) all of the makeup hydrogen necessary for the process is introduced in step c). Consequently, the quantity supplied will also take account of the chemical consumption of hydrogen in stage a) so as to supply the hydrogen necessary for the hydrogenation sought in stage a) also.
- Another consequence is that it is possible to optimize the hydrogen supply in the step c) according to the refractory level of the gas oils to be treated.
- This advantageous arrangement of the invention thus makes it possible to significantly improve the performance of the hydrotreatment catalyst and in particular hydrodesulfurization for given temperature and total pressure conditions which correspond to industrially practicable values.
- it makes it possible to maximize the hydrogen partial pressure, therefore the performance, on step c), while maintaining a total pressure of steps a) and c) (and therefore their investment cost) almost identical.
- the residual sulfur content of diesel fuel can be reduced by around 30% compared to to a process where all the additional hydrogen would be brought in step a) or else the hydrogen make-up brought to step c) would be just equal to the chemical consumption of hydrogen in step c).
- the hydrogen is separated from the effluent. It contains small amounts of hydrogen sulfide and usually does not require treatment.
- the hydrogen sulphide is also separated from the liquid effluent and thus a gas oil with at most 50 ppm by weight of sulfur is obtained, and most often with less than 10 ppm by weight of sulfur. Naphtha is also generally obtained.
- the hydrogen-containing gas which has been separated in step b) is, if necessary, at least partially treated to reduce its H 2 S content (preferably by washing with at least one amine) before recycling it to step a) and possibly in step c).
- the recycling gas preferably contains an amount of H2S greater than 0% and up to 1% mol.
- this amount is at least 15 ppm, preferably at least 0.1%, or at least 0.2% mol.
- At least part of the gaseous fraction can be sent to an amine washing section where the H 2 S is completely removed; the other party can bypass the amine washing section and be sent directly for recycling after compression.
- H 2 S is useful for maintaining the catalysts in the sulfurized state in steps a) and c) but an excess of H 2 S could reduce the hydrodesulfurization.
- step d To the hydrogen resulting from stage b) possibly purified, is added the separated hydrogen in step d). The mixture is re-compressed then recycled to step a) and optionally towards step c).
- step c it is recycled to step c) may not be necessary, especially when all of the makeup hydrogen is introduced in step c).
- recycle hydrogen can be introduced with the charge entering step a) and / or in the form of a quench between the catalyst beds.
- the diesel oil obtained has a sulfur content of less than 50 ppm by weight, generally less than 20 ppm, and most often less than 10 ppm. Furthermore, the cetane has been improved by 1 to 12 points, generally from 1 to 7, or even from 1 to 5 points compared to the diesel entering hydrotreatment. Its total amount of aromatics has also been reduced by at least 10%, the reduction can even go up to 90%. The quantity of polyaromatics in the final diesel is at most 11% by weight.
- FIG. 1 illustrates a preferred embodiment of the invention.
- the charge to be treated enters via a line (1) into a hydroconversion zone (I) in a bubbling bed of a hydroconversion catalyst.
- the effluent obtained in line (2) is sent to the separation zone (II).
- the zone (I) also comprises at least one line (31) for withdrawing the catalyst and at least one line (32) for supplying fresh catalyst.
- the effluent first passes through a separator (3) separating on the one hand a gas containing hydrogen (gas phase) in line (4) and secondly a liquid effluent in the driving (5).
- a separator (3) separating on the one hand a gas containing hydrogen (gas phase) in line (4) and secondly a liquid effluent in the driving (5).
- Part of the liquid effluent obtained can advantageously be extracted to be recycled by the line (33) at the bottom of the bubbling bed of step a) in order to maintain the catalyst in the bed bubbly.
- the liquid effluent is sent to a separator (6), which is preferably a stripper at the steam, to separate the hydrogen sulfide from the hydrocarbon effluent. At the same time, at least part of the naphtha fraction can be separated with hydrogen sulfide.
- the hydrogen sulfide with said naphtha exits through line (7) while the effluent hydrocarbon is obtained in line (8).
- the hydrocarbon effluent then passes through a distillation column (9) and it is separated at least a distillate cut including a diesel fraction and being found in the pipe (11), it is also separated a fraction heavier than diesel and ending up in the pipe (10).
- the naphtha separated at the separator (6) is stabilized (H 2 S eliminated).
- the stabilized naphtha is injected into the effluent entering the column (9).
- the naphtha can be separated in an additional pipe not shown in Figure 1.
- column (9) separates a diesel fraction mixed with naphtha in the line (11).
- the fraction of the pipe (10) is advantageously sent to the zone (V) catalytic cracking.
- the naphtha obtained separately, optionally added with the naphtha separated in the zone (IV) is advantageously separated into heavy and light gasoline, the heavy gasoline being sent to a reforming area and light petrol in an area where isomerization of the paraffins.
- the distillate cut is then sent (alone or possibly with a cut) naphtha and / or diesel fuel external to the process) in a hydrotreating zone (III) provided with minus a fixed bed of a hydrotreating catalyst.
- the hydrotreated effluent obtained leaves via line (12) to be sent to zone (IV) of separation shown in dashed lines in FIG. 1.
- separator preferably a cold separator, where a gas phase leaving via line (14) and liquid phase leaving via line (15).
- the liquid phase is sent to a separator (16) preferably a stripper, to remove the hydrogen sulfide leaving in the line (17), most often in mixture with naphtha.
- a diesel fraction is drawn off via line (18), a fraction which complies with the specifications for sulfur, ie having less than 50 ppm by weight of sulfur is generally less than 10 ppm.
- the H 2 S -naphta mixture is then optionally treated to recover the purified naphtha fraction.
- the method and the installation according to the invention also advantageously include a hydrogen recycling loop for the 2 zones (I) and (II) and which is now described in from figure 1.
- the gas containing hydrogen (gas phase of the pipe (4) separated in the zone (II)) is treated to reduce its sulfur content and possibly remove hydrocarbon compounds who may have passed during the separation.
- the gas phase of the pipe (4) is sent to an air cooler (19) after having been washed with the water injected through the pipe (20) and partly condensed by a hydrocarbon fraction sent by the line (21).
- the effluent from the air cooler is sent to a separation zone (22) where the water which is drawn off through the line (23), a hydrocarbon fraction through the line (21) and a gaseous phase through the line are separated. 24).
- Part of the hydrocarbon fraction of the pipe (21) is sent to the separation zone (II), and advantageously in the pipe (5).
- the gaseous phase obtained in line (24) free of hydrocarbon compounds is, if necessary, sent to a treatment unit (25) to reduce the sulfur content.
- it is a treatment with at least one amine.
- the hydrogen gas thus possibly purified is then re-compressed in the compressor (27).
- the separated hydrogen is added to the pipe (14).
- the compressed mixture is then partially recycled to the hydrotreating zone (III) (Step c) and partly to the hydroconversion zone (I) (step a) via the pipes (28) respectively and (29).
- FIG. 1 it is shown that the recycling hydrogen is introduced at the entrance to the zones reaction with the liquid charge. We can also introduce some of the hydrogen between the catalytic beds in order to control the inlet temperature of the bed ("quench").
- all of the makeup hydrogen is introduced by the pipe (30) at the level of the zone (II). In this realization, there is no driving bringing make-up hydrogen to zone level (I).
- An advantageous embodiment comprises, for the additional hydrogen, a pipe at the level of the zone (I) and a pipe at the level of the zone (II).
- a preferred mode for bringing hydrogen to zone (III) consists in provide a line for recycling and a line for topping up.
- the invention operating at moderate pressures, investments are reduced.
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Abstract
Description
Le déposant a donc recherché un procédé permettant d'atteindre ce but. Ce faisant, il a constaté que le but a été largement dépassé puisque des teneurs inférieures à 20 ppm et même à 10 ppm ont été généralement obtenues.
La conversion de la charge en fractions plus légères que 360°C est habituellement comprise entre 10-80% pds, le plus souvent de 25-60%.
Dès lors, la quantité amenée tiendra également compte de la consommation chimique d'hydrogène sur l'étape a) de façon à amener l'hydrogène nécessaire pour l'hydrogénation recherchée dans l'étape a) également.
- au niveau de l'étape c) uniquement (disposition avantageuse et préférée)
- au niveau des étapes a et c) avec de préférence une quantité dans l'étape c) qui corresponde au critère décrit ci-dessus (disposition avantageuse).
En effet, elle permet de maximiser la pression partielle hydrogène, donc la performance, sur l'étape c), tout en maintenant une pression totale des étapes a) et c) (et donc leur coût en investissement) quasiment identique.
Du naphta est également obtenu en général.
Par ailleurs, le cétane a été amélioré de 1 à 12 points, généralement de 1 à 7, ou encore de 1 à 5 points par rapport au gazole entrant en hydrotraitement.
Sa quantité totale d'aromatiques a été également réduite d'au moins 10 %, la réduction peut aller même jusqu'à 90 %.
La quantité de polyaromatiques dans le gazole final est d'au plus 11 % pds.
La zone (I) comporte également au moins une conduite (31) pour le soutirage du catalyseur et au moins une conduite (32) pour l'apport de catalyseur frais.
Une partie de la fraction hydrocarbonée de la conduite (21) est envoyée dans la zone (II) de séparation, et avantageusement dans la conduite (5).
Claims (18)
- Procédé de traitement de charges pétrolières dont au moins 80 % pds bout au-dessus de 340°C, et contenant au moins 0,05 % pds de soufre, pour produire au moins une coupe gazole à teneur en soufre d'au plus 50 ppm pds, ledit procédé comprenant les étapes suivantes :a) hydroconversion en lit bouillonnant d'un catalyseur d'hydroconversion au moins en partie amorphe fonctionnant à courant ascendant de liquide et de gaz, à une température de 300 - 550°C, une pression de 2-35 MPa, une vitesse spatiale horaire de 0,1 h-1-10 h-1 et en présence de 50-5000 Nm3 d'hydrogène/m3 de charge, la conversion nette en produits bouillant en-dessous de 360°C étant de 10-80 % pds,b) séparation à partir de l'effluent d'un gaz contenant de l'hydrogène, du sulfure d'hydrogène formé dans l'étape a) et d'une fraction plus lourde que le gazole,c) hydrotraitement, par contact avec au moins un catalyseur, d'au moins une coupe distillat obtenue dans l'étape b) et incluant une fraction gazole, à une température de 300-500°C, une pression de 2-12 MPa, une vitesse spatiale horaire de 0,1 - 10 h-1 et en présence de 200 - 5000 Nm3 d'hydrogène/m3 de charge ,d) séparation de l'hydrogène, des gaz et d'au moins une coupe gazole à teneur en soufre inférieure à 50 ppm pds,
- Procédé selon la revendication 1 dans lequel la quantité d'hydrogène d'appoint introduite à l'étape c) est supérieure à la consommation chimique d'hydrogène nécessaire pour obtenir les performances fixées dans les conditions opératoires fixées pour l'étape c).
- Procédé selon l'une des revendications précédentes dans lequel la totalité de l'hydrogène d'appoint nécessaire au procédé est amené à l'étape c).
- Procédé selon l'une des revendications précédentes dans lequel ladite fraction lourde est envoyée dans un procédé de craquage catalytique.
- Procédé selon l'une des revendications précédentes dans lequel la pression partielle H2S en sortie de l'étape c) est inférieure à 0,05 MPa.
- Procédé selon l'une des revendications précédentes dans lequel à l'étape b) on sépare également le naphta et il passe dans l'étape c) une fraction gazole.
- Procédé selon l'une des revendications 1 à 5 dans lequel il passe dans l'étape c) une fraction gazole mélangée au naphta.
- Procédé selon l'une des revendications précédentes dans lequel une partie au moins du gaz contenant de l'hydrogène séparé à l'étape b) est traité pour réduire sa teneur en sulfure d'hydrogène puis recyclé vers l'étape a), le gaz de recyclage contenant du sulfure d'hydrogène et à raison de 1 % mol au plus.
- Procédé selon la revendication 8 dans lequel le traitement est un lavage avec au moins une amine.
- Procédé selon l'une des revendications 8 ou 9 dans lequel le gaz de recyclage contient également l'hydrogène séparé dans l'étape d).
- Procédé selon l'une des revendications 8 à 10 dans lequel l'hydrogène est également recyclé dans l'étape c).
- Procédé selon l'une des revendications précédentes dans lequel les fractions séparées aux étapes b) et d) sont séparées en essences lourde et légère, l'essence lourde étant envoyée en réformage et l'essence légère en isomérisation des paraffines.
- Installation de traitement de charges pétrolières dont au moins 80 % pds bout au-dessus de 340°C et contenant au moins 0,05 % de soufre comprenant :a) une zone (I) d'hydroconversion en lit bouillonnant de catalyseur d'hydroconversion et munie d'une conduite (1) pour l'introduction de la charge à traiter, d'une conduite (2) pour la sortie de l'effluent hydroconverti, d'au moins une conduite (31) pour le soutirage de catalyseur et d'au moins une conduite (32) pour l'apport de catalyseur frais, ainsi que d'une conduite (29) pour l'introduction de l'hydrogène, ladite zone opérant avec un courant ascendant de charge et de gaz,b) une zone (II) de séparation incluant au moins un séparateur (3) (6) pour séparer le gaz riche en hydrogène par la conduite (4), pour séparer dans la conduite (7) le sulfure d'hydrogène et obtenir dans la conduite (8) une fraction liquide, et incluant également une colonne de distillation (9) pour séparer au moins une coupe distillat incluant une fraction gazole dans la conduite (11) et une fraction lourde dans la conduite (10),c) une zone (III) d'hydrotraitement contenant au moins un lit fixe de catalyseur d'hydrotraitement pour traiter une fraction gazole obtenue à l'issue de l'étape b), munie d'une conduite (30) pour l'introduction d'hydrogène d'appoint et d'une conduite (12) pour la sortie de l'effluent hydrotraité,d) une zone (IV) de séparation incluant au moins un séparateur (13) (16) pour séparer l'hydrogène par la conduite (14), pour séparer dans la conduite (17) le sulfure d'hydrogène et par la conduite (18) un gazole ayant une teneur en soufre inférieure à 50 ppm.
- Installation selon la revendication 13 comportent également une zone (V) de craquage catalytique dans laquelle est envoyée ladite fraction lourde par la conduite (10).
- Installation selon l'une des revendications 13 ou 14 dans laquelle la zone (II) comporte un séparateur gaz/liquide (3) pour séparer un gaz contenant de l'hydrogène par la conduite (4), puis un séparateur (6) admettant l'effluent issu du séparateur (3) pour séparer le sulfure d'hydrogène et du naphta par la conduite (7) et obtenir une fraction liquide dans la conduite (8), ladite zone (II) comportant également une colonne (9) de distillation pour séparer par la conduite (11) une coupe naphta + gazole et par la conduite (10) une fraction plus lourde que le gazole et la conduite (10) est reliée à une zone (V) de craquage catalytique.
- Installation selon l'une des revendications 13 à 15 dans laquelle la zone (II) comporte un séparateur gaz liquide (3) pour séparer un gaz contenant de l'hydrogène par la conduite (4), puis un séparateur (6) admettant l'effluent issu du séparateur (3) pour séparer le sulfure d'hydrogène et du naphta par la conduite (7) et obtenir une fraction liquide dans la conduite (8), sur la conduite (7) est disposé un stabilisateur pour enlever le sulfure d'hydrogène, le naphta purifié étant envoyé dans la conduite (8), ladite zone (II) comportant également une colonne (9) de distillation pour séparer le naphta, une fraction plus lourde que le gazole par la conduite (10), et une coupe gazole par la conduite (11), la conduite (10) étant relié à la zone (V) de craquage catalytique.
- Installation selon l'une des revendications 13 à 16 comportant une zone (25) de traitement pour abaisser la teneur en H2S du gaz contenant de l'hydrogène, un compresseur (27) recomprimant le gaz issu de la zone (25) et l'hydrogène amené par la conduite (14), et une conduite (29) de recyclage de l'hydrogène dans la zone (I).
- Installation selon la revendication 17 également munie d'une conduite (28) de recyclage de l'hydrogène dans la zone (III).
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
FR0114594 | 2001-11-12 | ||
FR0114594A FR2832159B1 (fr) | 2001-11-12 | 2001-11-12 | Procede de conversion de fractions lourdes petrolieres incluant un lit bouillonnant pour produire des distillats moyens de faible teneur en soufre |
Publications (2)
Publication Number | Publication Date |
---|---|
EP1312661A1 true EP1312661A1 (fr) | 2003-05-21 |
EP1312661B1 EP1312661B1 (fr) | 2011-06-08 |
Family
ID=8869294
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP02290433A Expired - Lifetime EP1312661B1 (fr) | 2001-11-12 | 2002-02-22 | Procédé de conversion de fractions lourdes petrolieres incluant un lit bouillonnant pour produire des distillats moyens de faible teneur en soufre |
Country Status (5)
Country | Link |
---|---|
EP (1) | EP1312661B1 (fr) |
AT (1) | ATE512207T1 (fr) |
CA (1) | CA2372619C (fr) |
ES (1) | ES2367677T3 (fr) |
FR (1) | FR2832159B1 (fr) |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2009141703A2 (fr) * | 2008-05-20 | 2009-11-26 | I F P | Recyclage sélectif de gazole lourd pour obtenir une intégration optimale de la conversion de pétrole lourd et du traitement de gazole sous vide |
US7704377B2 (en) | 2006-03-08 | 2010-04-27 | Institut Francais Du Petrole | Process and installation for conversion of heavy petroleum fractions in a boiling bed with integrated production of middle distillates with a very low sulfur content |
Families Citing this family (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
FR2857370B1 (fr) * | 2003-07-07 | 2005-09-02 | Inst Francais Du Petrole | Procede de production de distillats et d'huiles lubrifiantes |
Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3380910A (en) * | 1966-05-17 | 1968-04-30 | Chemical Construction Corp | Production of synthetic crude oil |
FR2791354A1 (fr) * | 1999-03-25 | 2000-09-29 | Inst Francais Du Petrole | Procede de conversion de fractions lourdes petrolieres comprenant une etape d'hydroconversion en lits bouillonnants et une etape d'hydrotraitement |
-
2001
- 2001-11-12 FR FR0114594A patent/FR2832159B1/fr not_active Expired - Lifetime
-
2002
- 2002-02-20 CA CA2372619A patent/CA2372619C/fr not_active Expired - Lifetime
- 2002-02-22 EP EP02290433A patent/EP1312661B1/fr not_active Expired - Lifetime
- 2002-02-22 AT AT02290433T patent/ATE512207T1/de not_active IP Right Cessation
- 2002-02-22 ES ES02290433T patent/ES2367677T3/es not_active Expired - Lifetime
Patent Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3380910A (en) * | 1966-05-17 | 1968-04-30 | Chemical Construction Corp | Production of synthetic crude oil |
FR2791354A1 (fr) * | 1999-03-25 | 2000-09-29 | Inst Francais Du Petrole | Procede de conversion de fractions lourdes petrolieres comprenant une etape d'hydroconversion en lits bouillonnants et une etape d'hydrotraitement |
Cited By (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US7704377B2 (en) | 2006-03-08 | 2010-04-27 | Institut Francais Du Petrole | Process and installation for conversion of heavy petroleum fractions in a boiling bed with integrated production of middle distillates with a very low sulfur content |
US7919054B2 (en) | 2006-03-08 | 2011-04-05 | IFP Energies Nouvelles | Process and installation for conversion of heavy petroleum fractions in a boiling bed with integrated production of middle distillates with a very low sulfur content |
WO2009141703A2 (fr) * | 2008-05-20 | 2009-11-26 | I F P | Recyclage sélectif de gazole lourd pour obtenir une intégration optimale de la conversion de pétrole lourd et du traitement de gazole sous vide |
WO2009141703A3 (fr) * | 2008-05-20 | 2010-06-17 | I F P | Recyclage sélectif de gazole lourd pour obtenir une intégration optimale de la conversion de pétrole lourd et du traitement de gazole sous vide |
Also Published As
Publication number | Publication date |
---|---|
CA2372619C (fr) | 2010-05-11 |
ES2367677T3 (es) | 2011-11-07 |
CA2372619A1 (fr) | 2003-05-12 |
FR2832159A1 (fr) | 2003-05-16 |
ATE512207T1 (de) | 2011-06-15 |
EP1312661B1 (fr) | 2011-06-08 |
FR2832159B1 (fr) | 2004-07-09 |
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