EP1612255B2 - Hydrodesulfurization process for naphtha fractions using a catalyst with controlled porosity. - Google Patents
Hydrodesulfurization process for naphtha fractions using a catalyst with controlled porosity. Download PDFInfo
- Publication number
- EP1612255B2 EP1612255B2 EP05291383.7A EP05291383A EP1612255B2 EP 1612255 B2 EP1612255 B2 EP 1612255B2 EP 05291383 A EP05291383 A EP 05291383A EP 1612255 B2 EP1612255 B2 EP 1612255B2
- Authority
- EP
- European Patent Office
- Prior art keywords
- catalyst
- process according
- activity
- range
- support
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
Classifications
-
- 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
- C10G45/00—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds
- C10G45/02—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing
- C10G45/04—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing characterised by the catalyst used
-
- 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
- C10G45/00—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds
- C10G45/02—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing
- C10G45/04—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing characterised by the catalyst used
- C10G45/06—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing characterised by the catalyst used containing nickel or cobalt metal, or compounds thereof
-
- 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
- C10G45/00—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds
- C10G45/02—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing
- C10G45/04—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing characterised by the catalyst used
- C10G45/06—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing characterised by the catalyst used containing nickel or cobalt metal, or compounds thereof
- C10G45/08—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing characterised by the catalyst used containing nickel or cobalt metal, or compounds thereof in combination with chromium, molybdenum, or tungsten metals, or compounds thereof
-
- 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
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/10—Feedstock materials
- C10G2300/1037—Hydrocarbon fractions
- C10G2300/1044—Heavy gasoline or naphtha having a boiling range of about 100 - 180 °C
-
- 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
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/20—Characteristics of the feedstock or the products
- C10G2300/201—Impurities
- C10G2300/202—Heteroatoms content, i.e. S, N, O, P
-
- 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
- C10G2400/02—Gasoline
Definitions
- the present invention relates to a desulfurization process using a catalyst containing at least one support, and an active phase comprising for example a metal.
- the process allows the hydrodesulphurization of gasolines, and especially the gasolines resulting from a catalytic cracking process (FCC Fluid Catalytic Cracking according to English terminology, that is to say catalytic cracking in a fluidized bed).
- the feedstock to be treated is usually a sulfur-containing gasoline cut such as for example a cut from a coking unit, visbreaking, steam cracking or catalytic cracking (FCC).
- Said feed is preferably constituted by a gasoline cut from a catalytic cracking unit whose boiling point range typically ranges from that of hydrocarbons with 5 carbon atoms to about 250 ° C.
- This gasoline can possibly be composed of a significant fraction of gasoline coming from other production processes such as atmospheric distillation (generally called straight run fuel by the refiner) or conversion processes (coker or steam-cracking gasoline).
- Catalytic cracking gasolines which can constitute 30 to 50% by volume of the gasoline pool, have high olefin and sulfur contents.
- the sulfur present in the reformulated gasoline is attributable, to nearly 90%, to the gasoline resulting from catalytic cracking.
- Desulphurisation of species and mainly FCC species is therefore of obvious importance for achieving standards.
- Hydrotreating or hydrodesulfurization of catalytic cracking gasoline when it is carried out under the conditions conventionally known to those skilled in the art, makes it possible to reduce the sulfur content of the cut.
- this process has the major disadvantage of causing a very large drop in the octane number of the cut, because of the hydrogenation or saturation of a large part or even all of the olefins under the conditions of the hydrotreatment.
- the patent US 5,318,690 proposes a process consisting in splitting the gasoline, softening the light fraction and hydrotraying the heavy fraction on a conventional catalyst and then treating it on a zeolite ZSM5 to recover the initial octane.
- the patent WO 01/40409 claims the treatment of an FCC gasoline under conditions of high temperature, low pressure and high hydrogen / charge ratio. Under these particular conditions, the recombination reactions involving H 2 S formed by the desulphurization reaction and the olefins to give rise to mercaptan formation are minimized.
- the catalysts used for this type of application are sulphide catalysts containing a group VIB element (Cr, Mo, W) and a group VIII element (Fe, Ru, Os, Co, Rh , Ir, Pd, Ni, Pt).
- the residual sulfur compounds present in the desulfurized gasolines by deep hydrodesulfurization comprise so-called recombinant mercaptans, resulting from the addition of the H 2 S formed during the reaction, on the olefins present, as well as unsaturated sulfur compounds such as thiophene and alkylthiophenes.
- the presence of the so-called recombination mercaptans explains at least in part that when it is desired to desulphurize in depth gasolines comprising an olefin fraction, a very high growth rate of hydrogenation of olefins is observed for the high levels of desulfurization. .
- the desired desulfurization rate approaches 100%, the saturation rate of olefins increases very significantly.
- the patent application EP 1 031 622 A1 discloses a process for desulfurizing olefinic gasolines comprising at least two steps, a step of hydrogenation of unsaturated sulfur compounds and a step of decomposition of saturated sulfur compounds.
- the invention is based on a two-step sequence such that the first step allows the elimination of unsaturated sulfur compounds from saturated sulfur compounds and the second step decomposes the saturated sulfur compounds into H 2 S with hydrogenation of olefins limited.
- the patent US6,231,753 describes a process for the hydrodesulfurization of olefinic gasolines comprising a first hydrodesulphurization step, an H2S extraction step and a second hydrodesulphurization step, the overall desulfurization rate and the temperature of this second step being greater than those from the first.
- the patent US6,231,754 describes a process in which a spent hydrotreatment catalyst is subsequently used in a higher temperature hydrodesulfurization step.
- the pore diameters of the catalyst are described as between 6 and 20 nm and the surface concentration of MoO 3 between 0.5. 10 -4 and 3.10 -4 g / m 2 .
- Requirement WO 03/099963 discloses a two-step process wherein the second step is carried out with a catalyst less loaded with metals and having a pore diameter equal to or greater than the catalyst used in the first step.
- the average pore diameter of the catalysts is between 6 and 20 nm and the surface concentration of MoO 3 is between 0.5. 10 -4 and 3.10 -4 g / m 2 .
- the hydrodesulfurization process of a gasoline according to the invention uses a catalyst comprising a support and an active phase comprising at least one metal characterized in that the average pore diameter of said catalyst is greater than 20 nanometers, preferably between 20 and 100 nm.
- the catalyst according to the invention contains at least one Group VI metal, more preferably it additionally contains at least one Group VIII metal.
- the surface density of the Group VI metal is preferably between 2 ⁇ 10 -4 and 40 ⁇ 10 -4 grams of oxide of said metal per m 2 of support.
- the support is preferably chosen from the group consisting of aluminas, silica, silica alumina or titanium or magnesium oxides used alone or in admixture with alumina or silica-alumina. . More preferably, the support is at least in part constituted by an alumina. According to a variant of the invention, the specific surface area of the support is less than 200 m 2 / g.
- the hydrodesulfurization process according to the invention comprises at least two successive stages of hydrodesulfurization and a catalyst whose average pore diameter is greater than 20 nanometers is used in at least one of said stages.
- the successive steps are performed without intermediate degassing.
- the process according to the invention comprises a succession of hydrodesulfurization steps and the activity of the catalyst of a step n + 1 is between 1% and 90% of the activity of the catalyst of step n, the catalyst of step n + 1 comprising a lower metal content than the catalyst of step n.
- the reaction temperature of step n + 1 is greater than that of step n.
- the catalyst of step n + 1 is the catalyst of step n which has undergone partial deactivation.
- the deactivation of the catalyst can be achieved by contacting the catalyst with a feed containing a hydrocarbon fraction comprising olefins at a temperature at least 250 ° C. It is also possible to recycle the catalyst from step n to step n + 1 when its activity has decreased by at least 10%.
- the process according to the invention uses at least one hydrodesulfurization catalyst comprising at least one Group VI metal (M VI ) and / or at least one Group VIII metal (M VIII ) on a support.
- the Group VI metal is generally molybdenum or tungsten the Group VIII metal generally nickel or cobalt.
- the catalyst support is usually a porous solid selected from the group consisting of aluminas, silicon carbide, silica, silica-aluminas or titanium or magnesium oxides used alone or in admixture with the alumina or silica-alumina. It is preferably selected from the group consisting of silica, the family of transition aluminas and silica-aluminas.
- the support consists essentially of at least one transition alumina, that is to say it comprises at least 51% by weight, preferably at least 60% by weight, very preferably at least 80% by weight. % weight, or even at least 90% weight of transition alumina. It may optionally consist solely of a transition alumina.
- the specific surface of the support is generally less than 200 m 2 / g, most often less than 150 m 2 / g.
- the porosity of the catalyst before sulfurization is such that it has an average pore diameter greater than 20 nm, preferably greater than 25 nm or even 30 nm and often between 20 and 140 nm, preferably between 20 and 100 nm, and very preferably between 25 and 80 nm.
- the pore diameter was measured by mercury porosimetry according to ASTM D4284-92 with a wetting angle of 140 °.
- the surface density of the group VI metal is in the range according to the invention between 2.10 and 40.10 -4 -4 gram of oxide of said metal per m 2 of support, preferably between 4.10 -4 and 16.10 -4 g / m 2.
- the molar ratio M VIII / (M VI + M VIII ) is typically greater than 0.1, preferably between 0.2 and 0.6 and very preferably between 0.2 and 0. 5.
- the catalyst according to the invention can be prepared using any technique known to those skilled in the art, and in particular by impregnation of the elements of groups VIII and VIB on the selected support.
- This impregnation may, for example, be carried out according to the method known to those skilled in the art in the dry-impregnation terminology, in which the quantity of desired elements in the form of soluble salts in the chosen solvent, for example demineralized water, so as to fill the porosity of the support as exactly as possible.
- the support thus filled with the solution is preferably dried.
- the preferred support is alumina which can be prepared from any type of precursors and shaping tools known to those skilled in the art.
- This treatment generally aims to transform the molecular precursors of the elements in the oxide phase. In this case it is an oxidizing treatment, but a direct reduction or even a simple drying of the catalyst can also be carried out.
- an oxidizing treatment also known as calcination
- this is generally carried out under air or under dilute oxygen, and the treatment temperature is generally between 200 ° C. and 550 ° C., preferably between 300 ° C. C and 500 ° C.
- a reducing treatment this is generally carried out under pure hydrogen or preferably diluted, and the treatment temperature is generally between 200 ° C. and 600 ° C., preferably between 300 ° C. and 500 ° C. ° C.
- Group VIB and VIII metal salts useful in the catalyst preparation process are, for example, cobalt nitrate, nickel nitrate, ammonium heptamolybdate or ammonium metatungstate. Any other salt known to those skilled in the art having sufficient and decomposable solubility during the activation treatment can also be used.
- the catalyst is usually used in a sulfurized form obtained after treatment in temperature in contact with a decomposable organic sulfur compound and generating H 2 S or directly in contact with a gas stream of H 2 S diluted in H 2 .
- This step can be carried out in situ or ex situ (inside or outside the reactor) of the hydrodesulfurization reactor at temperatures between 200 and 600 ° C and more preferably between 300 and 500 ° C.
- the present invention also relates to a process for the desulphurization of gasolines comprising olefins comprising at least two hydrodesulphurization stages and intended to minimize both the content of compounds which are the most refractory to hydrodesulfurization, such as the thiophene compounds and the so-called recombination mercaptans, derived from the addition of H 2 S to the olefins while limiting the degree of hydrogenation of the olefins associated with the removal of the sulfur compounds.
- At least one of the steps of the hydrodesulfurization process uses a catalyst as previously described.
- the method comprises at least two steps.
- a hydrodesulfurization first stage A is preferably carried out in a fixed bed reactor, generally in the vapor phase, on any catalyst conventionally used for this application.
- the use of so-called “selective" catalysts is preferred because it makes it possible to limit the hydrogenation of the olefins while maximizing the hydrodesulfurization.
- This first step is followed by a second step B, for example without operation between steps A and B other than a warming of the effluent of step A.
- Step B is characterized by the fact that it is carried out on a catalyst having a catalytic activity in conversion of thiophene of between 1% and 90%, or even between 1% and 70% and preferably between 1% and 50% of the activity of the catalyst of stage A.
- the catalyst implemented in step B may be either a catalyst whose catalytic formulation has been optimized to achieve the desired catalytic activity, or a partially deactivated catalyst.
- the use of catalysts which are preferably more selective in series makes it possible to limit the hydrogenation of the olefins to the high levels of desulfurization.
- a sequence makes it possible, by an inexpensive device, to significantly improve the selectivity of the desulfurization reaction by minimizing the olefin saturation rate while maintaining a degree of conversion of the sulfur compounds to H 2 S Student.
- This device also has the advantage that it allows, for a diagram without extraction of the H 2 S between the two reactors, to improve the selectivity of the process compared with a desulphurization performed in a single step.
- the device is most often based on a set of at least two or three reactors and can be carried out as follows: the reactor of step A contains the fresh catalyst and the reactor of step B contains the spent catalyst.
- the reactor of step A contains the fresh catalyst
- the reactor of step B contains the spent catalyst.
- the reactor containing the catalyst of deactivated step A is used in the second step, a reactor containing fresh catalyst is started and placed in step A.
- the reactor containing catalyst B is stopped the catalyst is replaced by fresh catalyst and the reactor is put on hold.
- This embodiment is more particularly of interest for an operation of the low pressure and high temperature hydrodesulphurization section for the two stages, conditions for which the formation of the recombination mercaptans is minimized but which results in a rapid deactivation of the catalysts.
- hydrodesulfurization By low pressure is meant relative pressures generally less than 2 relative MPa, and preferably less than 1.5 MPa relative or even 1 MPa relative and temperatures generally greater than 250 ° C or 260 ° C and most often greater than 280 ° C.
- the pressure of steps A and B is generally between about 0.4 MPa and 3 MPa, preferably between 0.6 MPa and 2.5 MPa, the flow rate of hydrogen is such that the ratio of hydrogen flow rates in normal liters per hour on the hydrocarbon flow rate in liters per hour is between 50 and 800 and preferably between 60 and 600.
- the temperature of step A is between 150 ° C and 450 ° C, preferably between 200 and 200 ° C. ° C and 400 ° C and more preferably between 230 ° C and 350 ° C and the temperature of step B is between 150 ° C and 450 ° C, preferably between 210 ° C and 410 ° C and more preferably between 240 ° C and 360 ° C.
- Steps A and B are performed according to a preferred mode in sequence without intermediate additional step. It is therefore possible to implement them in the same reactor.
- the catalytic zone corresponding to step B will be operated at an average temperature above the minimum of 10 ° C to the catalytic zone corresponding to step A.
- This temperature difference can come either from the heat of reaction released by the hydrogenation of olefins, either by injection between the catalytic zones A and B of a hotter fluid selected from hydrogen or an inert gas such as nitrogen, the feed or the fluid from the recycling of a fraction of the effluent of the process.
- Steps A and B can also be carried out in a catalytic column from which the gaseous compounds are withdrawn at the top under normal conditions of temperature and pressure.
- the catalytic zone of step A will be arranged higher in the column than the catalytic zone of step B.
- the catalyst of step B differs from the catalyst of step A by a catalytic activity of between 1% and 90%, or even between 1 and 70% and preferably between 1% and 50% of the catalytic activity of the catalyst.
- Step A. The catalysts of Steps A and B are carried out in sulphurous form. The sulphurization procedure can be carried out in situ or ex situ by any sulphurization method known to those skilled in the art.
- the catalyst used is a new catalyst prepared to exhibit reduced activity
- the contents of Group VIII and Group VIB metals deposited on the support will not exceed 10 and 14% by weight in oxide form and preferably 7.8% and 10% weight respectively in oxide form (to remain consistent with the maximum Co / Co + Mo ratio of 0.6 of the preferred range).
- the support used generally contains silica, silicon carbide, titanium oxide or magnesium oxide and / or alumina but will preferably be predominantly composed of alumina.
- the catalyst of step B can also be a deactivated hydrotreatment catalyst.
- a used catalyst from a distillate hydrodesulfurization unit or any other hydrodesulphurization process present in the refinery could be used, provided that the residual activity measured by the method described in Example 6 did not occur. does not exceed 90%, even 70% and preferably 50% of the activity of the catalyst of step A.
- the catalyst of step B may finally have been deactivated by treatment of a cut comprising olefins.
- the spent catalysts generally have a decreased activity due to the presence of carbon deposition due to the polymerization of the hydrocarbons treated on the catalyst.
- the present invention can be implemented as follows:
- the gasoline to be treated is for example characterized by a sulfur content greater than 50 ppm and an olefin content greater than 10% for which it is desired to transform at least 70% sulfur to H 2 S.
- the gas which has generally lower boiling temperatures than 250 ° C can be treated by the device of the present invention, or undergo a pretreatment consisting of a selective hydrogenation step and fractionation .
- These pretreatments are described in detail in the application EP 1 077 247 .
- advantageously only the fraction C 6+ (that is to say containing the hydrocarbons whose total carbon number is greater than or equal to 6) of the gasoline can be treated by the process according to the present invention.
- Gasoline mixed with hydrogen is heated by an exchanger train and / or an oven.
- the mixture brought to the desired temperature and pressure is usually in the vapor phase. It is sent to a first reactor (stage A) containing a hydrodesulphurization catalyst as described above implemented in a fixed bed.
- the effluent from this reactor contains hydrocarbons and sulfur compounds which have not reacted, paraffins resulting from the hydrogenation of olefins, H 2 S resulting from the decomposition of sulfur compounds and recombinant mercaptans from H 2 S addition reactions on olefins.
- This effluent is generally heated in an exchange train and / or an oven so that its temperature is increased by at least 10 ° C.
- step B a second reactor containing a low-active hydrodesulfurization catalyst such as described above implemented in fixed bed.
- the effluent from this reactor consists of hydrocarbons and a reduced amount of sulfur compounds which have not reacted during step A, paraffins resulting from the hydrogenation of olefins, the H 2 S from decomposition of sulfur compounds and a decreased amount of recombinant mercaptans from H 2 S addition reactions to olefins.
- steps A and B allows, with respect to step A alone, to minimize the loss of olefins by hydrogenation, for a given desulfurization rate.
- the following examples illustrate the advantages of the process in one or two steps as just described. In these examples (as well as in the foregoing description), the contents of sulfur or of sulfur compounds are given in ppm by weight.
- the catalysts are prepared according to the same method.
- the synthesis protocol consists in carrying out a dry impregnation of a solution of ammonium heptamolybdate and cobalt nitrate, the volume of the aqueous solution containing the metal precursors being equal to the volume of water recovery (ERV). corresponding to the mass of support to be impregnated.
- ERP volume of water recovery
- the concentrations of the precursors in the solution are adjusted so as to deposit on the support the weight contents of desired metal oxides.
- the solid is then allowed to mature at room temperature for 12 hours and then dried at 120 ° C for 12 hours. Finally, the solid is calcined at 500 ° C. for two hours under an air flow (11 / h / g).
- the alumina supports used are industrial supports supplied by Axens, the characteristics of which are given in Table 1 below. ⁇ b> Table 1: ⁇ / b> Characteristics of industrial aluminums.
- the sulphidation protocol of the catalyst is identical for each catalytic test.
- the catalyst in its calcined form (oxide), is loaded into the catalytic test unit and then sulphurated by a synthetic filler (4% S in the form of DMDS in n-heptane).
- the total mercaptan content is measured in potentiometric recipes by the ASTM D3227 method after separation of H 2 S.
- P 2.7 relative MPa
- VVH 4 h -1
- H 2 / load 360 normal liters per liter (nl / l)
- T 250 - 280 ° C.
- Each operating condition is maintained for the time necessary for the stabilization of the catalyst, both in hydrogenating activity and in desulfurizing activity (typically 24 to 48 hours).
- the results obtained on the catalysts A and D are shown in Table 4 below.
- Catalyst A Catalyst D T (° C) 250 260 270 250 260 S total 160 130 90 130 65 HDS /% 83.5 86.6 90.7 86.6 93.3 % olefins 26.7 26.1 25.5 23.0 21.1 HDO /% 25.2 26.9 28.6 35.6 40.9
- Example 3 Evaluation of the Performance of Catalysts A and B.
- the catalysts A (compliant) and B (compliant) are evaluated on FCC No. 2 gasoline with lower sulfur content than FCC No. 1 gasoline, the characteristics of which are given in Table 5 below. .
- Table 5 ⁇ / b> Characteristics of FCC No. 2 Gasoline.
- Each operating condition is maintained for the time necessary for the stabilization of the catalyst, both in hydrogenating activity and in desulfurizing activity (typically 24 to 48 hours).
- the results obtained on the catalysts A and B are shown in Table 6 below. ⁇ b> Table 6: ⁇ / b> Performance of Catalysts A and B for the Desulphurization of FCC No. 2 Gasoline.
- Catalyst A Catalyst B T (° C) 270 280 270 280 S total 96 46 92 54 HDS /% 78.7 89.8 79.5 88.0 % olefins 29.7 26.3 30.1 27.5 HDO /% 11.3 21.5 10.1 17.9
- catalyst B has a lower hydrogenation activity (HDO) than catalyst A.
- HDO hydrogenation activity
- Catalyst B (compliant) is therefore also more selective than catalyst D (non-compliant).
- Catalyst A and Catalyst C are compared in desulphurization with a depentanized and highly highly sulfurized FCC # 3 gasoline whose characteristics are given in Table 7.
- Table 7 ⁇ / b> Characteristics of FCC No. 3 Gasoline.
- a 100 ml sample of catalyst B is subjected to accelerated deactivation on a pilot unit under the following conditions: the catalyst is operated at 300 ° C. under a mixture consisting of the gasoline 4 described in Example 6 and hydrogen injected up to 100 normal liters of hydrogen per liter of gasoline, with a gasoline flow rate of 400 ml / h and under a total pressure of 1 MPa relative. After 800 hours, the reactor is stripped at 120 ° C under nitrogen to remove the adsorbed hydrocarbons. The catalyst thus deactivated is called catalyst G.
- the activity of the catalysts B, D, E, F, G is evaluated by a hydrodesulfurization test of a mixture of model molecules carried out in a stirred autoclave reactor of 500 ml.
- a hydrodesulfurization test of a mixture of model molecules carried out in a stirred autoclave reactor of 500 ml.
- the model charge used for the activity test has the following composition: 1000 ppm of sulfur in thiophene form, 10% by weight of olefins in the form of 2,3-dimethyl-butene-2 in n-heptane.
- This reaction mixture was chosen because considered representative of a catalytic cracking gasoline.
- the total system pressure is then adjusted and maintained at 3.5 relative MPa by hydrogen supply and the temperature is adjusted to 250 ° C.
- the catalyst is contacted with the reaction mixture.
- Periodic sampling of samples makes it possible to follow the evolution of the composition of the solution over time by gas chromatographic analysis.
- the duration of the test is chosen so as to obtain final thiophene conversion levels of between 50 and 90%.
- Gasoline No. 4 described in Table 10 is used to study the performance of catalyst chains. This species is from an FCC unit and has been depentanized. ⁇ b> Table 10: ⁇ / b> Characteristics of FCC # 4 Gasoline Total sulfur (ppm): 380 Olefins (% by weight): 27.8 Olefins (% by weight): 32.1 Aromatic (% weight): 33.9 ASTM distillation: PI: 55 ° C PF: 219 ° C
- the chaining tests are carried out in a pilot unit equipped with two reactors in series, each loaded with 100 ml of catalyst.
- the basic operating conditions used for all the tests are as follows, namely a pressure equal to 1.8 MPa relative and a hydrogen-to-charge ratio of 400 normal liters per liter.
- VVH (h -1 ) 4 4 4 4 4 4 4 4 S effluent ppm 12 13 14 13 15 12 13 Mercaptans, ppm 9 10 7 8 8 7 10 HDO% 28 32 24.5 21 20.1 21.4 30.6
- the two reactors placed in series are named respectively reactor 1 and reactor 2.
- the volume of catalyst in each reactor is 100 ml.
- Tests 1 and 2 were carried out on catalysts B and D alone. Catalyst D is not in accordance with the invention. The loss of olefins in run 1 is lower than the loss of olefins in run 2 due to the difference in selectivity between catalysts B and D.
- catalysts E, F or G in sequence with the catalysts B or D (tests 4, 5 in accordance with the invention) makes it possible to improve the overall selectivity. Indeed, for similar sulfur contents in the recipes, between 12 and 15 ppm, the losses of olefins measured by the HDO level are decreased compared to the tests 1 and 2, carried out on a single catalyst. In addition, observes that the best results have been obtained for the sequences 5 and 6 for which the catalysts used in the two steps are in accordance with the invention.
- Test No. 7 is made from a sequence not according to the invention for which reactor 2 is charged with a more active catalyst than that charged to reactor 1. Compared to tests 3 to 6, , a loss of olefins and a higher residual mercaptan content, for equivalent sulfur content in effluents.
Description
La présente invention concerne un procédé de désulfuration mettant en oeuvre un catalyseur contenant au moins un support, et une phase active comprenant par exemple un métal. Le procédé permet l'hydrodésulfuration des essences, et tout particulièrement les essences issues d'un procédé de craquage catalytique (FCC Fluid Catalytic Cracking selon la terminologie anglosaxonne, c'est-à-dire craquage catalytique en lit fluidisé).The present invention relates to a desulfurization process using a catalyst containing at least one support, and an active phase comprising for example a metal. The process allows the hydrodesulphurization of gasolines, and especially the gasolines resulting from a catalytic cracking process (FCC Fluid Catalytic Cracking according to English terminology, that is to say catalytic cracking in a fluidized bed).
La production d'essences reformulées répondant aux nouvelles normes d'environnement nécessite notamment que l'on diminue de façon importante leur teneur en soufre. Ainsi, les normes environnementales en vigueur et futures contraignent les raffineurs à abaisser la teneur en soufre dans le pool essence à des valeurs inférieures ou au plus égales à 50 ppm en 2005 et 10 ppm au premier janvier 2009 au sein de la communauté européenne. La charge à traiter est généralement une coupe essence contenant du soufre telle que par exemple une coupe issue d'une unité de cokéfaction (coking), de viscoréduction (visbreaking), de vapocraquage ou de craquage catalytique (FCC). Ladite charge est de préférence constituée d'une coupe essence issue d'une unité de craquage catalytique dont la gamme de points d'ébullition s'étend typiquement de celui des hydrocarbures à 5 atomes de carbones jusqu'à environ 250°C. Cette essence peut éventuellement être composée d'une fraction significative d'essence provenant d'autres procédés de production telle que la distillation atmosphérique (généralement appelée essence straight run par le raffineur) ou de procédés de conversion (essence de coker ou de vapocraquage).In particular, the production of reformulated species that meet the new environmental standards requires a significant reduction in their sulfur content. Thus, the current and future environmental standards require refiners to lower the sulfur content in the gasoline pool to values of 50 ppm or less in 2005 and 10 ppm in the European community by 1 January 2009. The feedstock to be treated is usually a sulfur-containing gasoline cut such as for example a cut from a coking unit, visbreaking, steam cracking or catalytic cracking (FCC). Said feed is preferably constituted by a gasoline cut from a catalytic cracking unit whose boiling point range typically ranges from that of hydrocarbons with 5 carbon atoms to about 250 ° C. This gasoline can possibly be composed of a significant fraction of gasoline coming from other production processes such as atmospheric distillation (generally called straight run fuel by the refiner) or conversion processes (coker or steam-cracking gasoline).
Les essences de craquage catalytique, qui peuvent constituer 30 à 50 % en volume du pool essence, présentent des teneurs en oléfines et en soufre élevées. Le soufre présent dans les essences reformulées est imputable, à près de 90%, à l'essence issue du craquage catalytique. La désulfuration des essences et principalement des essences de FCC est donc d'une importance évidente pour l'atteinte des normes. L'hydrotraitement ou hydrodésulfuration des essences de craquage catalytique, lorsqu'il est réalisé dans les conditions classiquement connues de l'homme du métier, permet de réduire la teneur en soufre de la coupe. Cependant, ce procédé présente l'inconvénient majeur d'entraîner une chute très importante de l'indice d'octane de la coupe, en raison de l'hydrogénation ou saturation d'une partie importante voire de la totalité des oléfines dans les conditions de l'hydrotraitement. Il a donc été proposé des procédés permettant de désulfurer profondément les essences de FCC tout en maintenant l'indice d'octane à un niveau acceptable. Ainsi, le brevet
L'amélioration de la sélectivité de réaction (hydrodésulfuration / hydrogénation) recherchée peut donc être obtenue par le choix du procédé mais dans tous les cas l'utilisation d'un système catalytique intrinsèquement sélectif est primordiale. D'une façon générale, les catalyseurs utilisés pour ce type d'application sont des catalyseurs de type sulfure contenant un élément du groupe VIB (Cr, Mo, W) et un élément du groupe VIII (Fe, Ru, Os, Co, Rh, Ir, Pd, Ni, Pt).The improvement of the reaction selectivity (hydrodesulfurization / hydrogenation) sought can therefore be obtained by the choice of the process but in all cases the use of an inherently selective catalytic system is essential. In general, the catalysts used for this type of application are sulphide catalysts containing a group VIB element (Cr, Mo, W) and a group VIII element (Fe, Ru, Os, Co, Rh , Ir, Pd, Ni, Pt).
L'obtention de catalyseurs sélectifs pour l'hydrodésulfuration sélective de coupes essence oléfiniques est enseignée dans de nombreux brevets. Certains brevets proposent l'utilisation de supports autres que le support alumine classiquement utilisé pour les catalyseurs d'hydrotraitement, comme par exemple des supports à base de magnésie (brevet
Pour être compétitifs, les procédés d'hydrodésulfuration doivent répondre à deux contraintes principales que sont :
- une hydrogénation des oléfines limitée à fort taux de désulfuration,
- une bonne stabilité du système catalytique et une opération continue pendant plusieurs années.
- a hydrogenation of olefins limited to high desulphurization rate,
- good stability of the catalytic system and continuous operation for several years.
De plus, pour effectuer une désulfuration profonde, il est nécessaire de traiter l'ensemble des composés soufrés présents dans les essences de craquage et dans ce cadre les essences de craquage catalytique peuvent être classées en deux familles:
- les composés soufrés insaturés que sont le thiophène, les méthyl-thiophènes, les diméthyl-thiophènes, éthyl-thiophènes, et autres alkylthiophènes, les benzothiophènes et alkylbenzothiophènes.
- les composés soufrés saturés que sont les mercaptans, les sulfures cycliques ou aliphatiques, les disulfures.
- unsaturated sulfur compounds such as thiophene, methyl-thiophenes, dimethyl-thiophenes, ethyl-thiophenes, and other alkylthiophenes, benzothiophenes and alkylbenzothiophenes.
- saturated sulfur compounds such as mercaptans, cyclic or aliphatic sulfides, disulfides.
Les composés soufrés résiduels présents dans les essences désulfurées par hydrodésulfuration profonde comprennent des mercaptans dits de recombinaison, issus de l'addition de l'H2S, formé en cours de réaction, sur les oléfines présentes ainsi que des composés soufrés insaturés tels que le thiophène et les alkylthiophènes. La présence des mercaptans dits de recombinaisons explique au moins en partie que lorsque l'on cherche à désulfurer en profondeur des essences comprenant une fraction d'oléfines, on observe une croissance très forte du taux d'hydrogénation des oléfines pour les forts taux de désulfuration. Ainsi, lorsque le taux de désulfuration recherché approche 100%, le taux de saturation des oléfines augmente de façon très importante. L'utilisation de catalyseurs plus sélectifs peut permettre lorsque des taux de désulfuration proches de 100% sont désirés, de limiter cependant l'hydrogénation des oléfines, voir la formation des mercaptans de recombinaison. L'un des enjeux primordiaux de la désulfuration profonde est ainsi de trouver des procédés permettant d'atteindre des sélectivités élevées c'est à dire de minimiser les réactions d'hydrogénation des oléfines tout en traitant les composés soufrés résiduels comme les mercaptans.The residual sulfur compounds present in the desulfurized gasolines by deep hydrodesulfurization comprise so-called recombinant mercaptans, resulting from the addition of the H 2 S formed during the reaction, on the olefins present, as well as unsaturated sulfur compounds such as thiophene and alkylthiophenes. The presence of the so-called recombination mercaptans explains at least in part that when it is desired to desulphurize in depth gasolines comprising an olefin fraction, a very high growth rate of hydrogenation of olefins is observed for the high levels of desulfurization. . Thus, when the desired desulfurization rate approaches 100%, the saturation rate of olefins increases very significantly. The use of more selective catalysts can allow when desulfurization rates close to 100% are desired, however, to limit the hydrogenation of olefins, see the formation of recombinant mercaptans. One of the main issues of deep desulphurization is thus to find methods for achieving high selectivities that is to say to minimize the hydrogenation reactions of olefins while treating the residual sulfur compounds such as mercaptans.
Parmi les solutions envisageables pour atteindre les taux de désulfuration imposés par les normes actuelles ou futures, il peut être avantageux de recourir à un procédé de désulfuration en au moins deux étapes.Among the possible solutions for achieving the desulfurization rates imposed by current or future standards, it may be advantageous to use a desulfurization process in at least two stages.
Ainsi, la demande brevet
Le brevet
Le brevet
La demande
Selon la présente invention, il a été trouvé un procédé permettant de réduire la teneur en soufre total des coupes hydrocarbonées et de préférence de coupes essences de FCC, sans perte de rendement en essence et minimisant la diminution de l'indice d'octane.According to the present invention, there has been found a process for reducing the total sulfur content of hydrocarbon cuts and preferably FCC gasoline cuts, without loss of gasoline yield and minimizing the decrease of the octane number.
Le procédé d'hydrodésulfuration d'une essence selon l'invention met en oeuvre un catalyseur comprenant un support et une phase active comprenant au moins un métal caractérisé en ce que le diamètre moyen de pores dudit catalyseur est supérieur à 20 nanomètres, de préférence compris entre 20 et 100 nm.The hydrodesulfurization process of a gasoline according to the invention uses a catalyst comprising a support and an active phase comprising at least one metal characterized in that the average pore diameter of said catalyst is greater than 20 nanometers, preferably between 20 and 100 nm.
De préférence, le catalyseur selon l'invention contient au moins un métal du groupe VI, de manière plus préférée il contient en outre au moins un métal du groupe VIII. La densité surfacique du métal du groupe VI est de préférence comprise entré 2.10-4 et 40.10-4 gramme d'oxyde dudit métal par m2 de support.Preferably, the catalyst according to the invention contains at least one Group VI metal, more preferably it additionally contains at least one Group VIII metal. The surface density of the Group VI metal is preferably between 2 × 10 -4 and 40 × 10 -4 grams of oxide of said metal per m 2 of support.
Dans le procédé selon l'invention, le support est de préférence choisi dans le groupe constitué par les alumines, la silice, les silices alumine ou encore les oxydes de titane ou de magnésium utilisés seul ou en mélange avec l'alumine ou la silice alumine. De manière plus préférée, le support est constitué au moins en partie par une alumine. Selon une variante de l'invention, la surface spécifique du support est inférieure à 200 m2/g.In the process according to the invention, the support is preferably chosen from the group consisting of aluminas, silica, silica alumina or titanium or magnesium oxides used alone or in admixture with alumina or silica-alumina. . More preferably, the support is at least in part constituted by an alumina. According to a variant of the invention, the specific surface area of the support is less than 200 m 2 / g.
Le procédé d'hydrodésulfuration selon l'invention comprend au moins deux étapes successives d'hydrodésulfuration et un catalyseur dont le diamètre moyen de pores est supérieur à 20 nanomètres est mis en oeuvre dans au moins une desdites étapes. Les étapes successives sont réalisées sans dégazage intermédiaire.The hydrodesulfurization process according to the invention comprises at least two successive stages of hydrodesulfurization and a catalyst whose average pore diameter is greater than 20 nanometers is used in at least one of said stages. The successive steps are performed without intermediate degassing.
Le procédé selon l'invention comprend une succession d'étapes d'hydrodésulfuration et l'activité du catalyseur d'une étape n+1 est comprise entre 1% et 90% de l'activité du catalyseur de l'étape n, le catalyseur de l'étape n+1 comprenant une teneur en métaux inférieure à celle du catalyseur de l'étape n.The process according to the invention comprises a succession of hydrodesulfurization steps and the activity of the catalyst of a step n + 1 is between 1% and 90% of the activity of the catalyst of step n, the catalyst of step n + 1 comprising a lower metal content than the catalyst of step n.
Selon un autre mode de réalisation du procédé selon l'invention la température réactionnelle de l'étape n+1 est supérieure à celle de l'étape n. Selon un autre mode de réalisation, le catalyseur de l'étape n+1 est le catalyseur de l'étape n ayant subi une désactivation partielle. Dans ce cas, par exemple, la désactivation du catalyseur peut être obtenue par mise au contact du catalyseur avec une charge contenant une fraction hydrocarbonée comprenant des oléfines à une température d'au moins 250°C. Il est également possible de recycler le catalyseur de l'étape n dans l'étape n+1, lorsque son activité a diminué d'au moins 10%.According to another embodiment of the process according to the invention, the reaction temperature of step n + 1 is greater than that of step n. In another embodiment, the catalyst of step n + 1 is the catalyst of step n which has undergone partial deactivation. In this case, for example, the deactivation of the catalyst can be achieved by contacting the catalyst with a feed containing a hydrocarbon fraction comprising olefins at a temperature at least 250 ° C. It is also possible to recycle the catalyst from step n to step n + 1 when its activity has decreased by at least 10%.
Le procédé selon l'invention met en oeuvre au moins un catalyseur d'hydrodésulfuration comprenant au moins un métal du groupe VI (MVI) et/ou au moins un métal du groupe VIII (MVIII) sur un support. Le métal du groupe VI est généralement le molybdène ou le tungstène le métal du groupe VIII généralement le nickel ou le cobalt. Le support du catalyseur est habituellement un solide poreux choisi dans le groupe constitué par les alumines, le carbure de silicium, la silice, les silice-alumines ou encore les oxydes de titane ou de magnésium utilisés seul ou en mélange avec l'alumine ou la silice-alumine. Il est de préférence choisi dans le groupe constitué par la silice, la famille des alumines de transition et les silice-alumines. De manière très préférée, le support est essentiellement constitué par au moins une alumine de transition, c'est-à-dire qu'il comprend au moins 51 % poids, de préférence au moins 60 % poids, de manière très préféré au moins 80 % poids, voire au moins 90 % poids d'alumine de transition. Il peut éventuellement être constitué uniquement d'une alumine de transition.The process according to the invention uses at least one hydrodesulfurization catalyst comprising at least one Group VI metal (M VI ) and / or at least one Group VIII metal (M VIII ) on a support. The Group VI metal is generally molybdenum or tungsten the Group VIII metal generally nickel or cobalt. The catalyst support is usually a porous solid selected from the group consisting of aluminas, silicon carbide, silica, silica-aluminas or titanium or magnesium oxides used alone or in admixture with the alumina or silica-alumina. It is preferably selected from the group consisting of silica, the family of transition aluminas and silica-aluminas. Very preferably, the support consists essentially of at least one transition alumina, that is to say it comprises at least 51% by weight, preferably at least 60% by weight, very preferably at least 80% by weight. % weight, or even at least 90% weight of transition alumina. It may optionally consist solely of a transition alumina.
La surface spécifique du support est généralement inférieure à 200 m2/g, le plus souvent inférieure à 150 m2/g. La porosité du catalyseur avant sulfuration est telle que celui-ci possède un diamètre moyen de pores supérieur à 20 nm, de manière préférée supérieur à 25 nm voire 30 nm et souvent compris entre 20 et 140 nm, de préférence entre 20 et 100 nm, et très préférentiellement entre 25 et 80 nm. Le diamètre de pore a été mesuré par porosimétrie au mercure selon la norme ASTM D4284-92 avec un angle de mouillage de 140°.The specific surface of the support is generally less than 200 m 2 / g, most often less than 150 m 2 / g. The porosity of the catalyst before sulfurization is such that it has an average pore diameter greater than 20 nm, preferably greater than 25 nm or even 30 nm and often between 20 and 140 nm, preferably between 20 and 100 nm, and very preferably between 25 and 80 nm. The pore diameter was measured by mercury porosimetry according to ASTM D4284-92 with a wetting angle of 140 °.
La densité surfacique du métal du groupe VI est comprise selon l'invention entre 2.10-4 et 40.10-4 gramme d'oxyde dudit métal par m2 de support, de préférence entre 4.10-4 et 16.10-4 g/m2.The surface density of the group VI metal is in the range according to the invention between 2.10 and 40.10 -4 -4 gram of oxide of said metal per m 2 of support, preferably between 4.10 -4 and 16.10 -4 g / m 2.
Selon l'invention, le rapport molaire MVIII/(MVI+MVIII) est typiquement supérieur à 0,1, de manière préférée compris entre 0,2 et 0,6 et de manière très préférée compris entre 0,2 et 0,5.According to the invention, the molar ratio M VIII / (M VI + M VIII ) is typically greater than 0.1, preferably between 0.2 and 0.6 and very preferably between 0.2 and 0. 5.
Le catalyseur selon l'invention peut être préparé au moyen de toute technique connue de l'homme du métier, et notamment par imprégnation des éléments des groupes VIII et VIB sur le support sélectionné. Cette imprégnation peut par exemple être réalisée selon le mode connu de l'homme du métier sous la terminologie d'imprégnation à sec, dans lequel on introduit juste la quantité d'éléments désirés sous forme de sels solubles dans le solvant choisi, par exemple de l'eau déminéralisée, de façon à remplir aussi exactement que possible la porosité du support. Le support ainsi rempli par la solution est de préférence séché. Le support préféré est l'alumine qui peut être préparée à partir de tout type de précurseurs et outils de mise en forme connus de l'homme de métier.The catalyst according to the invention can be prepared using any technique known to those skilled in the art, and in particular by impregnation of the elements of groups VIII and VIB on the selected support. This impregnation may, for example, be carried out according to the method known to those skilled in the art in the dry-impregnation terminology, in which the quantity of desired elements in the form of soluble salts in the chosen solvent, for example demineralized water, so as to fill the porosity of the support as exactly as possible. The support thus filled with the solution is preferably dried. The preferred support is alumina which can be prepared from any type of precursors and shaping tools known to those skilled in the art.
Après introduction des éléments des groupes VIII et VIB, et éventuellement une mise en forme du catalyseur, celui-ci subi un traitement d'activation. Ce traitement a généralement pour but de transformer les précurseurs moléculaires des éléments en phase oxyde. Il s'agit dans ce cas d'un traitement oxydant mais une réduction directe voire un simple séchage du catalyseur peuvent également être effectués. Dans le cas d'un traitement oxydant, également appelé calcination, celui-ci est généralement mis en oeuvre sous air ou sous oxygène dilué, et la température de traitement est généralement comprise entre 200°C et 550°C, de préférence entre 300°C et 500°C. Dans le cas d'un traitement réducteur, celui-ci est généralement mis en oeuvre sous hydrogène pur ou de préférence dilué, et la température de traitement est généralement comprise entre 200°C et 600°C, de préférence entre 300°C et 500°C.After introduction of the elements of groups VIII and VIB, and possibly forming the catalyst, it undergoes an activation treatment. This treatment generally aims to transform the molecular precursors of the elements in the oxide phase. In this case it is an oxidizing treatment, but a direct reduction or even a simple drying of the catalyst can also be carried out. In the case of an oxidizing treatment, also known as calcination, this is generally carried out under air or under dilute oxygen, and the treatment temperature is generally between 200 ° C. and 550 ° C., preferably between 300 ° C. C and 500 ° C. In the case of a reducing treatment, this is generally carried out under pure hydrogen or preferably diluted, and the treatment temperature is generally between 200 ° C. and 600 ° C., preferably between 300 ° C. and 500 ° C. ° C.
Des sels de métaux des groupes VIB et VIII utilisables dans le procédé de préparation du catalyseur sont par exemple le nitrate de cobalt, le nitrate de nickel, l'heptamolybdate d'ammonium ou le métatungstate d'ammonium. Tout autre sel connu de l'homme du métier présentant une solubilité suffisante et décomposable lors du traitement d'activation peut également être utilisé.Group VIB and VIII metal salts useful in the catalyst preparation process are, for example, cobalt nitrate, nickel nitrate, ammonium heptamolybdate or ammonium metatungstate. Any other salt known to those skilled in the art having sufficient and decomposable solubility during the activation treatment can also be used.
Le catalyseur est habituellement utilisé sous une forme sulfurée obtenue après traitement en température au contact d'un composé organique soufré décomposable et générateur d'H2S ou directement au contact d'un flux gazeux d'H2S dilué dans H2. Cette étape peut être réalisée in situ ou ex situ (en dedans ou dehors du réacteur) du réacteur d'hydrodésulfuration à des températures comprises entre 200 et 600°C et plus préférentiellement entre 300 et 500°C.The catalyst is usually used in a sulfurized form obtained after treatment in temperature in contact with a decomposable organic sulfur compound and generating H 2 S or directly in contact with a gas stream of H 2 S diluted in H 2 . This step can be carried out in situ or ex situ (inside or outside the reactor) of the hydrodesulfurization reactor at temperatures between 200 and 600 ° C and more preferably between 300 and 500 ° C.
La présente invention se rapporte également à un procédé de désulfuration d'essences comprenant des oléfines comprenant au moins deux étapes d'hydrodésulfuration et destiné à minimiser, à la fois la teneur en composés les plus réfractaires à l'hydrodésulfuration tels que les composés thiophéniques et les mercaptans dits de recombinaison, issus de l'addition de l'H2S sur les oléfines tout en limitant le taux d'hydrogénation des oléfines associé à l'élimination des composés soufrés. Au moins une des étapes du procédé d'hydrodésulfuration met en oeuvre un catalyseur tel que précédemment décrit.The present invention also relates to a process for the desulphurization of gasolines comprising olefins comprising at least two hydrodesulphurization stages and intended to minimize both the content of compounds which are the most refractory to hydrodesulfurization, such as the thiophene compounds and the so-called recombination mercaptans, derived from the addition of H 2 S to the olefins while limiting the degree of hydrogenation of the olefins associated with the removal of the sulfur compounds. At least one of the steps of the hydrodesulfurization process uses a catalyst as previously described.
Le procédé comprend au moins deux étapes. Une première étape A d'hydrodésulfuration est réalisée de préférence dans un réacteur en lit fixe, généralement en phase vapeur, sur tout catalyseur classiquement utilisé pour cette application. L'utilisation de catalyseurs dits "sélectifs" est préférée car elle permet de limiter l'hydrogénation des oléfines tout en maximisant l'hydrodésulfuration. Cette première étape est suivie d'une deuxième étape B, par exemple sans opération entre les étapes A et B autre qu'un réchauffement de l'effluent de l'étape A. L'étape B est caractérisée par le fait qu'elle est réalisée sur un catalyseur présentant une activité catalytique en conversion du thiophène comprise entre 1% et 90%, voire entre 1% et 70% et de préférence entre 1% et 50% de l'activité du catalyseur de l'étape A. Le catalyseur mis en oeuvre dans l'étape B peut être soit un catalyseur dont la formulation catalytique a été optimisée pour atteindre l'activité catalytique désirée, soit un catalyseur partiellement désactivé.The method comprises at least two steps. A hydrodesulfurization first stage A is preferably carried out in a fixed bed reactor, generally in the vapor phase, on any catalyst conventionally used for this application. The use of so-called "selective" catalysts is preferred because it makes it possible to limit the hydrogenation of the olefins while maximizing the hydrodesulfurization. This first step is followed by a second step B, for example without operation between steps A and B other than a warming of the effluent of step A. Step B is characterized by the fact that it is carried out on a catalyst having a catalytic activity in conversion of thiophene of between 1% and 90%, or even between 1% and 70% and preferably between 1% and 50% of the activity of the catalyst of stage A. The catalyst implemented in step B may be either a catalyst whose catalytic formulation has been optimized to achieve the desired catalytic activity, or a partially deactivated catalyst.
Selon l'invention, l'utilisation de catalyseurs de préférence plus sélectifs en série permet de limiter l'hydrogénation des oléfines aux forts taux de désulfuration. Il a été observé, qu'un tel enchaînement permettait, par un dispositif peu coûteux, d'améliorer significativement la sélectivité de la réaction de désulfuration en minimisant le taux de saturation des oléfines tout en maintenant un taux de transformation des composés soufrés en H2S élevé. Ce dispositif présente en outre l'avantage qu'il permet, pour un schéma sans extraction de l'H2S entre les deux réacteurs, d'améliorer la sélectivité du procédé par rapport à une désulfuration réalisée en une seule étape. Par rapport à l'enseignement décrit dans la demande
Dans le cas particulier où le catalyseur de l'étape B est le même catalyseur que celui de l'étape A, mais dont l'activité catalytique a été diminuée par désactivation, le dispositif est le plus souvent basé sur un ensemble d'au moins deux voire trois réacteurs et peut être réalisé de la façon suivante : le réacteur de l'étape A contient le catalyseur frais et le réacteur de l'étape B contient le catalyseur usé. Lorsque le catalyseur de l'étape A est désactivé, le réacteur contenant le catalyseur de l'étape A désactivé est utilisé en deuxième étape, un réacteur contenant du catalyseur frais est démarré et placé en étape A. Le réacteur contenant le catalyseur B est arrêté, le catalyseur est remplacé par du catalyseur frais et le réacteur est mis en attente. Ce schéma permet d'opérer l'unité de désulfuration sans interruption lors du remplacement du catalyseur usé, tout en maximisant la sélectivité du procédé.In the particular case where the catalyst of step B is the same catalyst as that of step A, but whose catalytic activity has been decreased by deactivation, the device is most often based on a set of at least two or three reactors and can be carried out as follows: the reactor of step A contains the fresh catalyst and the reactor of step B contains the spent catalyst. When the catalyst of step A is deactivated, the reactor containing the catalyst of deactivated step A is used in the second step, a reactor containing fresh catalyst is started and placed in step A. The reactor containing catalyst B is stopped the catalyst is replaced by fresh catalyst and the reactor is put on hold. This scheme makes it possible to operate the desulfurization unit without interruption during the replacement of the spent catalyst, while maximizing the selectivity of the process.
Ce mode de réalisation trouve plus particulièrement son intérêt pour une opération de la section d'hydrodésulfuration à basse pression et hautes températures pour les deux étapes, conditions pour lesquelles la formation des mercaptans de recombinaison est minimisée mais qui engendrent une désactivation rapide des catalyseurs d'hydrodésulfuration. Par basse pression, on entend des pressions relatives généralement inférieures à 2 MPa relatif, et de façon préférée inférieures à 1,5 MPa relatif voire 1 MPa relatif et des températures généralement supérieures à 250°C voire 260°C et le plus souvent supérieures à 280 °C.This embodiment is more particularly of interest for an operation of the low pressure and high temperature hydrodesulphurization section for the two stages, conditions for which the formation of the recombination mercaptans is minimized but which results in a rapid deactivation of the catalysts. hydrodesulfurization. By low pressure is meant relative pressures generally less than 2 relative MPa, and preferably less than 1.5 MPa relative or even 1 MPa relative and temperatures generally greater than 250 ° C or 260 ° C and most often greater than 280 ° C.
L'étape A est généralement caractérisée par :
- un taux de désulfuration généralement inférieur à 98%, de façon préférée inférieur à 95% et de façon très préférée inférieure à 90%.
- un taux d'hydrogénation des oléfines inférieur à 60% et de façon préférée inférieur à 50%.
- a desulfurization rate generally less than 98%, preferably less than 95% and very preferably less than 90%.
- a degree of hydrogenation of the olefins of less than 60% and preferably less than 50%.
L'étape B est le plus souvent caractérisée par :
- un taux de désulfuration généralement inférieur à 98%, de façon préférée inférieur à 95% et de façon très préférée inférieure à 90%.
- un taux d'hydrogénation des oléfines- inférieur à 60% et de façon préféré inférieur à 50%.
- une température opératoire supérieure à celle de l'étape A, de façon préférée supérieure de plus de 10°C à la température de l'étape A et de manière plus préférée supérieure de plus de 20°C à la température de l'étape A,
- l'utilisation d'un catalyseur dont l'activité par unité de volume mesurée en conversion du thiophène est comprise entre 1% et 90% de l'activité du catalyseur de l'étape A. Cette activité catalytique est mesurée par un test molécule modèle décrit dans la suite du texte.
- a desulfurization rate generally less than 98%, preferably less than 95% and very preferably less than 90%.
- a degree of hydrogenation of the olefins of less than 60% and preferably less than 50%.
- a higher operating temperature than that of step A, preferably more than 10 ° C higher than the temperature of step A and more preferably more than 20 ° C above the temperature of step A ,
- the use of a catalyst whose activity per unit volume measured in conversion of thiophene is between 1% and 90% of the activity of the catalyst of step A. This catalytic activity is measured by a test molecule model described in the rest of the text.
La pression des étapes A et B est généralement comprise entre 0,4 MPa relatifs et 3 MPa relatifs, de préférence entre 0,6 MPa et 2,5 MPa, le débit d'hydrogène est tel que le rapport des débits d'hydrogène en normaux litres par heure sur le débit d'hydrocarbures en litres par heure soit compris entre 50 et 800 et de préférence entre 60 et 600. La température de l'étape A est comprise entre 150°C et 450°C, de préférence entre 200°C et 400°C et de manière plus préférée entre 230°C et 350°C et la température de l'étape B est comprise entre 150°C et 450°C, de préférence entre 210°C et 410°C et de manière plus préférée entre 240°C et 360°C.The pressure of steps A and B is generally between about 0.4 MPa and 3 MPa, preferably between 0.6 MPa and 2.5 MPa, the flow rate of hydrogen is such that the ratio of hydrogen flow rates in normal liters per hour on the hydrocarbon flow rate in liters per hour is between 50 and 800 and preferably between 60 and 600. The temperature of step A is between 150 ° C and 450 ° C, preferably between 200 and 200 ° C. ° C and 400 ° C and more preferably between 230 ° C and 350 ° C and the temperature of step B is between 150 ° C and 450 ° C, preferably between 210 ° C and 410 ° C and more preferably between 240 ° C and 360 ° C.
Les étapes A et B sont réalisées selon un mode préféré en enchaînement sans étape supplémentaire intermédiaire. Il est donc possible de les mettre en oeuvre dans le même réacteur. Dans ce cas, la zone catalytique correspondant à l'étape B sera opérée à une température moyenne supérieure au minimum de 10°C à la zone catalytique correspondant à l'étape A. Cette différence de température peut provenir, soit de la chaleur de réaction dégagée par l'hydrogénation des oléfines, soit par injection entre les zones catalytiques A et B d'un fluide plus chaud choisi parmi l'hydrogène ou un gaz inerte tel que l'azote, la charge ou le fluide issu du recyclage d'une fraction de l'effluent du procédé.Steps A and B are performed according to a preferred mode in sequence without intermediate additional step. It is therefore possible to implement them in the same reactor. In this case, the catalytic zone corresponding to step B will be operated at an average temperature above the minimum of 10 ° C to the catalytic zone corresponding to step A. This temperature difference can come either from the heat of reaction released by the hydrogenation of olefins, either by injection between the catalytic zones A and B of a hotter fluid selected from hydrogen or an inert gas such as nitrogen, the feed or the fluid from the recycling of a fraction of the effluent of the process.
Les étapes A et B peuvent également être mises en oeuvre dans une colonne catalytique de laquelle sont soutirés, en tête, les composés gazeux dans les conditions normales de température et de pression. Dans ce cas, la zone catalytique de l'étape A sera disposée plus haut dans la colonne que la zone catalytique de l'étape B.Steps A and B can also be carried out in a catalytic column from which the gaseous compounds are withdrawn at the top under normal conditions of temperature and pressure. In this case, the catalytic zone of step A will be arranged higher in the column than the catalytic zone of step B.
Le catalyseur de l'étape B diffère du catalyseur de l'étape A par une activité catalytique comprise entre 1 % et 90%, voire entre 1 et 70% et de préférence entre 1% et 50% de l'activité catalytique du catalyseur de l'étape A. Les catalyseurs des étapes A et B sont mis en oeuvre sous forme sulfurée. La procédure de sulfuration peut être réalisée in situ ou ex situ par toute méthode de sulfuration connue de l'homme du métier.The catalyst of step B differs from the catalyst of step A by a catalytic activity of between 1% and 90%, or even between 1 and 70% and preferably between 1% and 50% of the catalytic activity of the catalyst. Step A. The catalysts of Steps A and B are carried out in sulphurous form. The sulphurization procedure can be carried out in situ or ex situ by any sulphurization method known to those skilled in the art.
L'activité du catalyseur peut être définie par rapport à la constante de vitesse pour la conversion du thiophène normalisée par volume de catalyseur évaluée lors d'un test sur molécules modèles. La constante de vitesse est calculée en considérant un ordre 1 pour la réaction :
- A : activité du catalyseur, en min-1. cm3 catalyseur -1 (centimètre cube-1)
- k constante de vitesse pour la conversion du thiophène, en min-1
- mcatalyseur : masse de catalyseur utilisée en g
- DRT : densité de remplissage tassée du catalyseur, en cm3/g
- A: catalyst activity, in min -1 . cm 3 catalyst -1 (cubic centimeter -1 )
- k rate constant for thiophene conversion, in min -1
- m catalyst : mass of catalyst used in g
- DRT: packed packing density of catalyst, in cm 3 / g
Lorsque le catalyseur utilisé est un catalyseur neuf préparé pour présenter une activité réduite, il peut être envisagé de préparer un catalyseur neuf par imprégnation d'une faible quantité de métaux sur le support. Typiquement, les teneurs en métaux du groupe VIII et du groupe VIB déposés sur le support n'excèderont pas, respectivement 10,9 et 14% poids sous forme oxyde et de préférence respectivement 7,8% et 10% poids sous forme oxyde (pour rester cohérent avec le rapport Co/Co+Mo maximal de 0,6 de la fourchette préférée). Le support utilisé contient généralement de la silice, du carbure de silicium, d'oxyde de titane ou de magnésium et/ou de l'alumine mais sera de préférence majoritairement composé d'alumine.When the catalyst used is a new catalyst prepared to exhibit reduced activity, it may be envisaged to prepare a new catalyst by impregnating a small amount of metals on the support. Typically, the contents of Group VIII and Group VIB metals deposited on the support will not exceed 10 and 14% by weight in oxide form and preferably 7.8% and 10% weight respectively in oxide form (to remain consistent with the maximum Co / Co + Mo ratio of 0.6 of the preferred range). The support used generally contains silica, silicon carbide, titanium oxide or magnesium oxide and / or alumina but will preferably be predominantly composed of alumina.
Le catalyseur de l'étape B peut également être un catalyseur d'hydrotraitement désactivé. On pourra par exemple utiliser un catalyseur usé d'une unité d'hydrodésulfuration de distillats ou de tout autre procédé d'hydrodésulfuration présent dans la raffinerie, dans la mesure où l'activité résiduelle mesurée par la méthode décrite dans l'exemple 6 n'excède pas 90%, voire 70% et de préférence 50% de l'activité du catalyseur de l'étape A.The catalyst of step B can also be a deactivated hydrotreatment catalyst. For example, a used catalyst from a distillate hydrodesulfurization unit or any other hydrodesulphurization process present in the refinery could be used, provided that the residual activity measured by the method described in Example 6 did not occur. does not exceed 90%, even 70% and preferably 50% of the activity of the catalyst of step A.
Le catalyseur de l'étape B peut enfin avoir subi une désactivation par traitement d'une coupe comprenant des oléfines. Les catalyseurs usés ont généralement une activité diminuée par la présence de dépôt de carbone dû à la polymérisation des hydrocarbures traités sur le catalyseur.The catalyst of step B may finally have been deactivated by treatment of a cut comprising olefins. The spent catalysts generally have a decreased activity due to the presence of carbon deposition due to the polymerization of the hydrocarbons treated on the catalyst.
La présente invention peut être mise en oeuvre de la façon suivante: L'essence à traiter est par exemple caractérisée par une teneur en soufre supérieure à 50 ppm et une teneur en oléfines supérieure à 10% pour laquelle on cherche à transformer au moins 70% de soufre en H2S. Cette essence qui présente des températures d'ébullition généralement inférieures à 250°C peut être soit traitée directement par le dispositif de la présente invention, soit subir un prétraitement consistant en une étape d'hydrogénation sélective et un fractionnement. Ces prétraitements sont décrits en détail dans la demande
L'essence mélangée à de l'hydrogène est chauffée par un train d'échangeur et/ou un four. Le mélange porté à la température et la pression voulues se trouve généralement en phase vapeur. Il est envoyé dans un premier réacteur (étape A) contenant un catalyseur d'hydrodésulfuration tel que décrit plus haut mis en oeuvre en lit fixe. L'effluent de ce réacteur contient les hydrocarbures et les composés soufrés qui n'ont pas réagi, les paraffines issues de l'hydrogénation des oléfines, de l'H2S issu de la décomposition des composés soufrés et des mercaptans de recombinaison issus des réactions d'addition de l'H2S sur les oléfines. Cet effluent est généralement réchauffé dans un train d'échange et/ou un four afin que sa température soit augmentée d'au moins 10°C et est injecté dans un deuxième réacteur (étape B) contenant un catalyseur d'hydrodésulfuration peu actif tel que décrit plus haut mis en oeuvre en lit fixe. L'effluent de ce réacteur est constitué des hydrocarbures et d'une quantité diminuée de composés soufrés qui n'ont pas réagi au cours de l'étape A, des paraffines issues de l'hydrogénation des oléfines, l'H2S issu de la décomposition des composés soufrés et d'une quantité diminuée de mercaptans de recombinaison issus des réactions d'addition de l'H2S sur les oléfines.Gasoline mixed with hydrogen is heated by an exchanger train and / or an oven. The mixture brought to the desired temperature and pressure is usually in the vapor phase. It is sent to a first reactor (stage A) containing a hydrodesulphurization catalyst as described above implemented in a fixed bed. The effluent from this reactor contains hydrocarbons and sulfur compounds which have not reacted, paraffins resulting from the hydrogenation of olefins, H 2 S resulting from the decomposition of sulfur compounds and recombinant mercaptans from H 2 S addition reactions on olefins. This effluent is generally heated in an exchange train and / or an oven so that its temperature is increased by at least 10 ° C. and is injected into a second reactor (step B) containing a low-active hydrodesulfurization catalyst such as described above implemented in fixed bed. The effluent from this reactor consists of hydrocarbons and a reduced amount of sulfur compounds which have not reacted during step A, paraffins resulting from the hydrogenation of olefins, the H 2 S from decomposition of sulfur compounds and a decreased amount of recombinant mercaptans from H 2 S addition reactions to olefins.
L'enchaînement des étapes A et B permet, par rapport à l'étape A seule, de minimiser la perte en oléfines par hydrogénation, pour un taux de désulfuration donné. Les exemples qui suivent permettent d'illustrer les avantages du procédé en un ou deux étapes tel qu'il vient d'être décrit. Dans ces exemples (ainsi que dans la description qui précède), les teneurs en soufre ou en composés soufrés sont donnés en ppm poids.The sequence of steps A and B allows, with respect to step A alone, to minimize the loss of olefins by hydrogenation, for a given desulfurization rate. The following examples illustrate the advantages of the process in one or two steps as just described. In these examples (as well as in the foregoing description), the contents of sulfur or of sulfur compounds are given in ppm by weight.
Les catalyseurs sont préparés selon une même méthode. Le protocole de synthèse consiste à réaliser une imprégnation à sec d'une solution d'heptamolybdate d'ammonium et de nitrate de cobalt, le volume de la solution aqueuse contenant les précurseurs métalliques étant égal au volume de reprise à l'eau (VRE) correspondant à la masse de support à imprégner.The catalysts are prepared according to the same method. The synthesis protocol consists in carrying out a dry impregnation of a solution of ammonium heptamolybdate and cobalt nitrate, the volume of the aqueous solution containing the metal precursors being equal to the volume of water recovery (ERV). corresponding to the mass of support to be impregnated.
Les concentrations des précurseurs dans la solution sont ajustées de manière à déposer sur le support les teneurs pondérales en oxydes métalliques souhaitées. Le solide est ensuite laissé à maturer à température ambiante durant 12 heures, puis séché à 120°C, durant 12 heures. Finalement, le solide est calciné à 500°C durant deux heures sous flux d'air (1l/h/g). Les supports alumine employés sont des supports industriels fournis par la société Axens, dont les caractéristiques sont fournies dans le tableau 1 ci-dessous.
** volume poreux total d'intrusion au Hg
** total pore volume of Hg intrusion
Différents catalyseurs de type CoMo ont été préparés sur ces supports. On constate (tableau 2) que ces catalyseurs se distinguent essentiellement par leurs propriétés texturales pour les catalyseurs A, B, C, D et par leur teneur en phase active pour les catalyseurs E et F.
** diamètre de pores correspondant à un volume d'intrusion de VP(Hg)/2
** pore diameter corresponding to an intrusion volume of V P (Hg) / 2
Le protocole de sulfuration du catalyseur est identique pour chaque test catalytique. Le catalyseur, sous sa forme calcinée (oxyde), est chargé dans l'unité de test catalytique, puis sulfuré par une charge synthétique (4% S sous forme de DMDS dans du n-heptane). Les conditions de sulfuration sont les suivantes : VVH = 2 h-1 (volume de charge / volume de catalyseur / h), P = 2 MPa relatifs, H2/charge = 300 (Nl/l), Tpalier = 350°C (4h, montée en T à 20°C/heure).The sulphidation protocol of the catalyst is identical for each catalytic test. The catalyst, in its calcined form (oxide), is loaded into the catalytic test unit and then sulphurated by a synthetic filler (4% S in the form of DMDS in n-heptane). Sulfurization conditions are: LHSV = 2 h -1 (volume of feed / volume catalyst / hr), P = 2 MPa relative, H 2 / feed = 300 (Nl / l) bearing T = 350 ° C (4h, rise in T at 20 ° C / hour).
La teneur en soufre (en ppm) est évaluée dans la charge et dans les recettes (après élimination de l'H2S dissout) selon la méthode iso 14596 ; ce qui permet le calcul du taux de désulfuration de l'essence selon la formule :
La teneur pondérale en oléfines est évaluée dans la charge et dans la recette par chromatographie en phase gazeuse ; ceci permet d'évaluer le taux d'hydrogénation des oléfines de l'essence selon la formule :
La teneur totale en mercaptans est mesurée dans les recettes par potentiométrie par la méthode ASTM D3227 après séparation de l'H2S.The total mercaptan content is measured in potentiometric recipes by the ASTM D3227 method after separation of H 2 S.
Dans cet exemple les performances des catalyseurs A (conforme) et D (non conforme) sont comparées en HDS sélective d'une essence de FCC soufrée dont les caractéristiques sont fournies dans le tableau 3 ci-dessous.
Les conditions de test sont les suivantes : P = 2,7 MPa relatif, VVH = 4 h-1, H2/charge = 360 Normaux litres par litre (nl/l), T = 250 - 280°C. Chaque condition opératoire est maintenue durant le temps nécessaire à la stabilisation du catalyseur, tant en activité hydrogénante qu'en activité désulfurante (typiquement de 24 à 48 heures). Les résultats obtenus sur les catalyseurs A et D sont présentés dans le tableau 4 ci-dessous.
On observe que pour des niveaux de désulfuration (HDS) comparables, le catalyseur A présente des taux d'hydrogénation des oléfines (HDO) moins importants que le catalyseur D. Le catalyseur A (conforme) est donc plus sélectif que le catalyseur D (non conforme)It is observed that for comparable desulphurization levels (HDS), catalyst A has lower hydrogenation rates of olefins (HDO) than catalyst D. Catalyst A (compliant) is therefore more selective than catalyst D (no compliant)
Dans cet exemple les catalyseurs A (conforme) et B (conforme) sont évalués sur une essence de FCC n°2 plus faiblement soufrée que l'essence de FCC n°1, et dont les caractéristiques sont fournies dans le tableau 5 ci-dessous.
Les conditions de test sont les suivantes : P = 1,5 MPa relatif, VVH = 5 h-1, H2/charge = 300 Nl/l, T = 270 - 280°C. Chaque condition opératoire est maintenue durant le temps nécessaire à la stabilisation du catalyseur, tant en activité hydrogénante qu'en activité désulfurante (typiquement de 24 à 48 heures). Les résultats obtenus sur les catalyseurs A et B sont présentés dans le tableau 6 ci-dessous.
Pour des taux de désulfuration (HDS) similaires, le catalyseur B présente une activité hydrogénante (HDO) plus faible que le catalyseur A. Le catalyseur B (conforme) est donc également plus sélectif que le catalyseur D (non conforme).For similar desulphurization rates (HDS), catalyst B has a lower hydrogenation activity (HDO) than catalyst A. Catalyst B (compliant) is therefore also more selective than catalyst D (non-compliant).
Dans cet exemple le catalyseur A et le catalyseur C sont comparés en désulfuration d'une essence de FCC n°3 dépentanisée et très fortement soufrée dont les caractéristiques sont fournies dans le tableau 7.
Les conditions de test sont les suivantes : P = 1,5 MPa relatif, VVH = 4 h-1, H2/charge = 300 Nl/l, T = 290 - 310°C. Chaque condition opératoire est maintenue durant le temps nécessaire à la stabilisation du catalyseur, tant en activité hydrogénante qu'en activité désulfurante (typiquement de 24 à 96 heures). Les résultats obtenus sur les catalyseurs A et C sont présentés dans le tableau 8 ci-dessous.
L'évolution du taux d'hydrogénation des oléfines en fonction du niveau de désulfuration montre que les deux catalyseurs présentent des sélectivités comparables. Le catalyseur C n'est donc pas plus sélectif que le catalyseur A. En revanche, le catalyseur C est moins actif que le catalyseur A en hydrodésulfuration, ce qui peut potentiellement constituer un handicap en terme de durée de vie de ce type de catalyseur sur une unité industrielle. En terme de sélectivité, le catalyseur C reste néanmoins supérieur au catalyseur D (cf. exemple 2, tableau 4).The evolution of the degree of hydrogenation of the olefins as a function of the level of desulfurization shows that the two catalysts have comparable selectivities. Catalyst C is therefore no more selective than catalyst A. On the other hand, catalyst C is less active than catalyst A in hydrodesulfurization, which can potentially constitute a handicap in terms of the service life of this type of catalyst. an industrial unit. In terms of selectivity, catalyst C nevertheless remains higher than catalyst D (see Example 2, Table 4).
Un échantillon de 100 ml de catalyseur B est soumis à une désactivation accélérée sur unité pilote dans les conditions suivantes : le catalyseur est opéré à 300°C sous un mélange constitué de l'essence 4 décrite dans l'exemple 6 et d'hydrogène injecté à hauteur de 100 normaux litres d'hydrogène par litre d'essence, avec un débit d'essence de 400 ml/h et sous une pression totale de 1 MPa relatif. Au bout de 800 heures, le réacteur est mis en stripage à 120°C sous azote afin d'éliminer les hydrocarbures adsorbés, Le catalyseur ainsi désactivé est appelé catalyseur G.A 100 ml sample of catalyst B is subjected to accelerated deactivation on a pilot unit under the following conditions: the catalyst is operated at 300 ° C. under a mixture consisting of the gasoline 4 described in Example 6 and hydrogen injected up to 100 normal liters of hydrogen per liter of gasoline, with a gasoline flow rate of 400 ml / h and under a total pressure of 1 MPa relative. After 800 hours, the reactor is stripped at 120 ° C under nitrogen to remove the adsorbed hydrocarbons. The catalyst thus deactivated is called catalyst G.
L'activité des catalyseurs B, D, E, F, G est évaluée par un test d'hydrodésulfuration d'un mélange de molécules modèles effectué dans un réacteur autoclave agité de 500 ml. Typiquement entre 2 g et 6 g de catalyseur sont sulfurés à pression atmosphérique en banc de sulfuration sous mélange H2S/H2 constitué de 15% volumique d'H2S à 1 l/h/g de catalyseur et à 400°C durant deux heures.The activity of the catalysts B, D, E, F, G is evaluated by a hydrodesulfurization test of a mixture of model molecules carried out in a stirred autoclave reactor of 500 ml. Typically between 2 g and 6 g of catalyst are sulfurized at atmospheric pressure in a sulfurization bench under H 2 S / H 2 mixture consisting of 15% by volume of H 2 S at 1 l / h / g of catalyst and at 400 ° C. for two hours.
La charge modèle utilisée pour le test d'activité présente la composition suivante : 1000 ppm de soufre sous forme thiophène, 10% poids d'oléfines sous forme de 2,3 diméthyl-butène-2 dans du n-heptane.The model charge used for the activity test has the following composition: 1000 ppm of sulfur in thiophene form, 10% by weight of olefins in the form of 2,3-dimethyl-butene-2 in n-heptane.
Ce mélange réactionnel a été choisi car jugé représentatif d'une essence de craquage catalytique. La pression totale du système est ensuite ajustée et maintenue à 3,5 MPa relatif par apport d'hydrogène et la température est ajustée à 250°C. Au temps t=0, le catalyseur est mis en contact avec le mélange réactionnel. Des prélèvements périodiques d'échantillons permettent de suivre l'évolution de la composition de la solution au cours du temps par analyse chromatographique en phase gaz. La durée du test est choisie de manière à obtenir des niveaux finaux de conversion du thiophène compris entre 50 et 90%.This reaction mixture was chosen because considered representative of a catalytic cracking gasoline. The total system pressure is then adjusted and maintained at 3.5 relative MPa by hydrogen supply and the temperature is adjusted to 250 ° C. At time t = 0, the catalyst is contacted with the reaction mixture. Periodic sampling of samples makes it possible to follow the evolution of the composition of the solution over time by gas chromatographic analysis. The duration of the test is chosen so as to obtain final thiophene conversion levels of between 50 and 90%.
L'activité du catalyseur est définie par rapport à la constante de vitesse pour la conversion du thiophène normalisée par volume de catalyseur. La constante de vitesse est calculée en considérant un ordre 1 pour la réaction,
- A : activité du catalyseur, en min-1 cm3 catalyseur -1 (centimètre cube -1)
- k constante de vitesse pour la conversion du thiophène, en min-1
- mcatalyseur : masse de catalyseur utilisée en g (avant sulfuration)
- DRT : densité de remplissage tassée du catalyseur, en cm3/g
- A: catalyst activity, in min -1 cm 3 catalyst -1 (cubic centimeter -1 )
- k rate constant for thiophene conversion, in min -1
- m catalyst : mass of catalyst used in g (before sulphurization)
- DRT: packed packing density of catalyst, in cm 3 / g
Les activités relatives des catalyseurs B, D, E et F ainsi obtenues sont reportées dans le tableau 9 ci-dessous,
L'essence n°4 décrite dans le tableau 10 est utilisée pour étudier les performances d'enchaînements de catalyseurs. Cette essence est issue d'une unité de FCC et a été dépentanisée.
Les essais d'enchaînement sont réalisés dans une unité pilote munie de deux réacteurs en série, chacun chargé de 100 ml de catalyseur.The chaining tests are carried out in a pilot unit equipped with two reactors in series, each loaded with 100 ml of catalyst.
Les performances de différents enchaînements de catalyseurs ont été évaluées pour illustrer la présente invention. Pour chaque catalyseur, la procédure classique de sulfuration décrite précédemment a été mise en oeuvre, procédure identique pour l'ensemble des catalyseurs.The performance of different catalyst sequences has been evaluated to illustrate the present invention. For each catalyst, the conventional sulfurization procedure described above was carried out, the same procedure for all the catalysts.
Les conditions opératoires de base utilisés pour l'ensemble des essais sont les suivantes à savoir une pression égale à 1,8 MPa relatif et un rapport hydrogène sur charge de 400 normaux litres par litre.The basic operating conditions used for all the tests are as follows, namely a pressure equal to 1.8 MPa relative and a hydrogen-to-charge ratio of 400 normal liters per liter.
Les températures ont été ajustées pour atteindre une cible de teneur en soufre située entre 10 ppm et 15 ppm. Le tableau 11 suivant résume les performances des différents enchaînements évalués.
Les deux réacteurs placés en série sont nommés respectivement réacteur 1 et réacteur 2. Le volume de catalyseur dans chaque réacteur est de 100 ml.The two reactors placed in series are named respectively reactor 1 and reactor 2. The volume of catalyst in each reactor is 100 ml.
Les essais 1 et 2 ont été réalisés sur les catalyseurs B et D seuls. Le catalyseur D n'est pas conforme à l'invention. La perte en oléfines lors de l'essai 1 est inférieure à la perte en oléfines de l'essai 2 du fait de la différence de sélectivité entre les catalyseurs B et D.Tests 1 and 2 were carried out on catalysts B and D alone. Catalyst D is not in accordance with the invention. The loss of olefins in run 1 is lower than the loss of olefins in run 2 due to the difference in selectivity between catalysts B and D.
La mise en oeuvre des catalyseurs E, F ou G en enchaînement avec les catalyseurs B ou D (essais 4, 5 conformes à l'invention) permet d'améliorer la sélectivité globale. En effet, pour des teneurs en soufre voisines dans les recettes, situées entre 12 et 15 ppm, les pertes en oléfines mesurées par le taux d'HDO sont diminuées par rapport aux essais 1 et 2, réalisés sur un catalyseur seul. De plus, on observe que les meilleurs résultats ont été obtenus pour les enchaînements 5 et 6 pour lesquels les catalyseurs utilisés dans les deux étapes sont conformes à l'invention.The implementation of catalysts E, F or G in sequence with the catalysts B or D (tests 4, 5 in accordance with the invention) makes it possible to improve the overall selectivity. Indeed, for similar sulfur contents in the recipes, between 12 and 15 ppm, the losses of olefins measured by the HDO level are decreased compared to the tests 1 and 2, carried out on a single catalyst. In addition, observes that the best results have been obtained for the sequences 5 and 6 for which the catalysts used in the two steps are in accordance with the invention.
L'essai n° 7 est réalisé à partir d'un enchaînement non conforme à l'invention pour lequel le réacteur 2 est chargé avec un catalyseur plus actif que celui chargé dans le réacteur 1. On constate, par rapport aux essais 3 à 6, une perte en oléfines et une teneur en mercaptans résiduels supérieures, pour une teneur en soufre dans les effluents équivalente.Test No. 7 is made from a sequence not according to the invention for which reactor 2 is charged with a more active catalyst than that charged to reactor 1. Compared to tests 3 to 6, , a loss of olefins and a higher residual mercaptan content, for equivalent sulfur content in effluents.
La comparaison entre les essais qui précède met en outre en évidence la diminution de quantité de mercaptans dans le produit obtenu grâce à la mise en oeuvre de l'invention.The comparison between the preceding tests also demonstrates the decrease in the amount of mercaptans in the product obtained by virtue of the practice of the invention.
Claims (14)
- A process for hydrodesulphurizing a gasoline, comprising employing a catalyst comprising a support and an active phase comprising nickel or cobalt and in which the mean pore diameter of said catalyst is more than 20 nanometres,
said process comprising at least two successive hydrodesulphurization steps in which said catalyst is employed in at least one of said steps,
the activity of the catalyst of a step n+1 is in the range 1 percent to 90% of the activity of the catalyst of step n,
the catalyst of step n+1 has a lower metals content than that of the catalyst of step n, and the successive steps being carried out without intermediate degassing - A process according to claim 1, in which the mean pore diameter is in the range 20 to 100 nm.
- A process according to claim 1 or claim 2, in which the catalyst contains at least one group VI metal.
- A process according to claim 3, in which the surface density of the group VI metal is in the range 2 x 10-4 to 40 x 10-4 grams of the oxide of said metal per m2 of support.
- A process according to one of the preceding claims, in which the support is selected from the group constituted by aluminas, silica, silica aluminas or oxides of titanium or magnesium, used alone or as a mixture with alumina or silica alumina.
- A process according to one of the preceding claims, in which the support is at least in part constituted by an alumina.
- A process according to one of the preceding claims, in which the specific surface area of the support is less than 200 m2/g,
- A process according to claim 1, in which the reaction temperature of the successive steps is in the range from 150°C to 450°C, the pressure is in the range from 0.4 to 3 MPa relative, and the volume ratio of hydrogen to hydrocarbons, H2/HC, is in the range from 50 N1/1 to 800 Nl/l.
- A process according to claim 8 in which, for each step, the pressure is less than 2 MPa relative and the temperature is more than 250°C.
- A process according to claim 1, in which the activity of a step is in the range 1 percent to 50 percent of the activity of the catalyst in the preceding step.
- A process according to claim 1, in which the reaction temperature in step n+1 is higher than that in step n.
- A process according to claims 1, in which the catalyst of step n+1 is the catalyst of step n which has undergone partial deactivation.
- A process according to claim 12, in which the catalyst is deactivated by bringing the catalyst into contact with a feed containing a hydrocarbon fraction comprising olefins at a temperature of at least 250 °C.
- A process according to claim 13, in which the catalyst of step n is recycled to step n+1 when its activity has reduced by at least 10 percent.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
DE602005003402.1T DE602005003402T3 (en) | 2004-07-01 | 2005-06-27 | Hydrodesulfurization process for gasolines using a controlled porosity catalyst. |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
FR0407335A FR2872516B1 (en) | 2004-07-01 | 2004-07-01 | METHOD OF HYDRODESULFURING ESSENCES USING A CONTROLLED POROSITY CATALYST |
Publications (3)
Publication Number | Publication Date |
---|---|
EP1612255A1 EP1612255A1 (en) | 2006-01-04 |
EP1612255B1 EP1612255B1 (en) | 2007-11-21 |
EP1612255B2 true EP1612255B2 (en) | 2016-03-30 |
Family
ID=34946714
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP05291383.7A Active EP1612255B2 (en) | 2004-07-01 | 2005-06-27 | Hydrodesulfurization process for naphtha fractions using a catalyst with controlled porosity. |
Country Status (8)
Country | Link |
---|---|
US (2) | US20060000751A1 (en) |
EP (1) | EP1612255B2 (en) |
KR (1) | KR101209347B1 (en) |
BR (1) | BRPI0502597B1 (en) |
CA (1) | CA2510668C (en) |
DE (1) | DE602005003402T3 (en) |
DK (1) | DK1612255T4 (en) |
FR (1) | FR2872516B1 (en) |
Families Citing this family (18)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
JP5498701B2 (en) * | 2006-01-17 | 2014-05-21 | エクソンモービル リサーチ アンド エンジニアリング カンパニー | Selective catalysts for naphtha hydrodesulfurization. |
PL1996677T3 (en) * | 2006-01-17 | 2015-10-30 | Exxonmobil Res & Eng Co | A method for making a catalyst for the hydrodesulfurisation of naphtha |
CA2636918C (en) | 2006-01-17 | 2015-10-06 | Exxonmobil Research And Engineering Company | Selective catalysts having high temperature alumina supports for naphtha hydrodesulfurization |
BRPI0707142A2 (en) | 2006-01-17 | 2011-04-19 | Exxonmobil Res & Eng Co | method for producing a suitable catalyst for naphtha hds, and method for naphtha hds |
FR2908781B1 (en) * | 2006-11-16 | 2012-10-19 | Inst Francais Du Petrole | PROCESS FOR DEEP DEFLAVING CRACKING SPECIES WITH LOW LOSS OF OCTANE INDEX |
US7749375B2 (en) * | 2007-09-07 | 2010-07-06 | Uop Llc | Hydrodesulfurization process |
US20090223864A1 (en) * | 2008-03-06 | 2009-09-10 | Opinder Kishan Bhan | Process for the selective hydrodesulfurization of an olefin containing hydrocarbon feedstock |
US20090223866A1 (en) * | 2008-03-06 | 2009-09-10 | Opinder Kishan Bhan | Process for the selective hydrodesulfurization of a gasoline feedstock containing high levels of olefins |
US20090223867A1 (en) * | 2008-03-06 | 2009-09-10 | Opinder Kishan Bhan | Catalyst and process for the selective hydrodesulfurization of an olefin containing hydrocarbon feedstock |
US20090223868A1 (en) * | 2008-03-06 | 2009-09-10 | Opinder Kishan Bhan | Catalyst and process for the selective hydrodesulfurization of an olefin containing hydrocarbon feedstock |
EP2361294A4 (en) * | 2008-11-26 | 2014-06-11 | Sk Innovation Co Ltd | Process for the preparation of clean fuel and aromatics from hydrocarbon mixtures catalytic cracked on fluid bed |
ES2652032T3 (en) | 2011-07-29 | 2018-01-31 | Saudi Arabian Oil Company | Selective hydrotreatment procedure of medium distillates |
FR2994864B1 (en) | 2012-09-05 | 2015-08-21 | IFP Energies Nouvelles | PROCESS FOR SULFURING A HYDRODESULFURATION CATALYST |
EP2816094B1 (en) | 2013-06-19 | 2020-04-29 | IFP Energies nouvelles | Method for producing gasoline with low sulphur and mercaptan content |
US9393538B2 (en) | 2014-10-10 | 2016-07-19 | Uop Llc | Process and apparatus for selectively hydrogenating naphtha |
US9822317B2 (en) | 2014-10-10 | 2017-11-21 | Uop Llc | Process and apparatus for selectively hydrogenating naphtha |
FR3094985B1 (en) | 2019-04-12 | 2021-04-02 | Axens | Hydrotreatment process for naphtha |
FR3116825A1 (en) | 2020-11-27 | 2022-06-03 | IFP Energies Nouvelles | Process for the hydrodesulphurization of a gasoline cut using a catalyst having a particular bimodal porosity |
Family Cites Families (24)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
AU513580B2 (en) | 1976-03-04 | 1980-12-11 | Amoco Corporation | The selective desulfurization of cracked naphthas |
US4203829A (en) | 1978-09-28 | 1980-05-20 | Standard Oil Company (Indiana) | Catalyst, method of preparation and use thereof in hydrodesulfurizing cracked naphtha |
CA1195278A (en) * | 1981-09-28 | 1985-10-15 | Chevron Research And Technology Company | Layered residua treatment catalyst process and temperature profile |
US5287708A (en) | 1990-09-28 | 1994-02-22 | Kabushiki Kaisha Toyoda Jidoshokki Seisakusho | Car air conditioner with a hydraulically driven refrigerant compressor |
US5318690A (en) | 1991-08-15 | 1994-06-07 | Mobil Oil Corporation | Gasoline upgrading process |
US5423975A (en) * | 1992-07-08 | 1995-06-13 | Texaco Inc. | Selective hydrodesulfurization of naphtha using spent resid catalyst |
WO1994020213A1 (en) * | 1993-03-12 | 1994-09-15 | Tricom, Inc. | Catalyst regeneration |
US5340466A (en) | 1993-04-19 | 1994-08-23 | Texaco Inc. | Hydrodesulfurization of cracked naphtha with hydrotalcite-containing catalyst |
US5525211A (en) | 1994-10-06 | 1996-06-11 | Texaco Inc. | Selective hydrodesulfurization of naphtha using selectively poisoned hydroprocessing catalyst |
US5770046A (en) | 1995-03-17 | 1998-06-23 | Texaco Inc | Selective hydrodesulfurization of cracked naphtha using novel catalysts |
US6231753B1 (en) | 1996-02-02 | 2001-05-15 | Exxon Research And Engineering Company | Two stage deep naphtha desulfurization with reduced mercaptan formation |
US6409913B1 (en) | 1996-02-02 | 2002-06-25 | Exxonmobil Research And Engineering Company | Naphtha desulfurization with reduced mercaptan formation |
US6013598A (en) | 1996-02-02 | 2000-01-11 | Exxon Research And Engineering Co. | Selective hydrodesulfurization catalyst |
US6231754B1 (en) | 1996-02-02 | 2001-05-15 | Exxon Research And Engineering Company | High temperature naphtha desulfurization using a low metal and partially deactivated catalyst |
FR2764298B1 (en) * | 1997-06-10 | 1999-07-16 | Inst Francais Du Petrole | HYDROTREATMENT OF HYDROCARBON CHARGES IN A BOILING BED REACTOR |
US6435273B1 (en) | 1998-12-14 | 2002-08-20 | Vladlen Futernik | Device for air temperature control in a vehicle |
FR2790000B1 (en) | 1999-02-24 | 2001-04-13 | Inst Francais Du Petrole | PROCESS FOR PRODUCING LOW SULFUR ESSENCE |
FR2797639B1 (en) | 1999-08-19 | 2001-09-21 | Inst Francais Du Petrole | PROCESS FOR PRODUCING LOW SULFUR ESSENCE |
US6793016B2 (en) | 2000-01-28 | 2004-09-21 | Denso Corporation | Vehicle air conditioning system with seat air conditioning unit |
US20020148758A1 (en) * | 2001-02-08 | 2002-10-17 | Yun-Feng Chang | Gasoline hydrodesulfurization |
JP3659213B2 (en) | 2001-10-30 | 2005-06-15 | 日産自動車株式会社 | Vehicle cooling system |
US7297251B2 (en) | 2002-05-21 | 2007-11-20 | Exxonmobil Research And Engineering Company | Multi-stage hydrodesulfurization of cracked naphtha streams with a stacked bed reactor |
US7069938B2 (en) | 2003-11-18 | 2006-07-04 | Yo Fu Umbrella Co., Ltd. | Golf sunshade |
BRPI0601787B1 (en) * | 2006-05-17 | 2016-06-07 | Petroleo Brasileiro Sa | selective naphtha hydrodesulfurization process |
-
2004
- 2004-07-01 FR FR0407335A patent/FR2872516B1/en active Active
-
2005
- 2005-06-27 EP EP05291383.7A patent/EP1612255B2/en active Active
- 2005-06-27 DE DE602005003402.1T patent/DE602005003402T3/en active Active
- 2005-06-27 DK DK05291383.7T patent/DK1612255T4/en active
- 2005-06-28 CA CA2510668A patent/CA2510668C/en active Active
- 2005-06-29 BR BRPI0502597-4A patent/BRPI0502597B1/en active IP Right Grant
- 2005-07-01 KR KR1020050059196A patent/KR101209347B1/en active IP Right Grant
- 2005-07-01 US US11/171,287 patent/US20060000751A1/en not_active Abandoned
-
2011
- 2011-11-28 US US13/305,527 patent/US8926831B2/en active Active
Also Published As
Publication number | Publication date |
---|---|
FR2872516B1 (en) | 2007-03-09 |
DK1612255T4 (en) | 2016-07-11 |
BRPI0502597A (en) | 2006-02-14 |
KR20060049757A (en) | 2006-05-19 |
DE602005003402D1 (en) | 2008-01-03 |
DE602005003402T3 (en) | 2016-07-21 |
CA2510668C (en) | 2013-01-29 |
DK1612255T3 (en) | 2008-03-17 |
EP1612255A1 (en) | 2006-01-04 |
EP1612255B1 (en) | 2007-11-21 |
DE602005003402T2 (en) | 2008-02-28 |
CA2510668A1 (en) | 2006-01-01 |
US20060000751A1 (en) | 2006-01-05 |
KR101209347B1 (en) | 2012-12-06 |
BRPI0502597B1 (en) | 2014-12-30 |
US20120067780A1 (en) | 2012-03-22 |
FR2872516A1 (en) | 2006-01-06 |
US8926831B2 (en) | 2015-01-06 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
EP1612255B2 (en) | Hydrodesulfurization process for naphtha fractions using a catalyst with controlled porosity. | |
EP1892039B1 (en) | Method of hydrodesulfuration of cuts containing sulphur compounds and olefins in the presence of a supported catalyst comprising elements from groups VIII and VIB | |
EP1174485B1 (en) | Process comprising two gasoline hydrodesulphurisation steps with intermediary elimination of H2S | |
EP1923452B1 (en) | Method of deep sulphur removal from cracked petrol with minimum loss of octane number | |
EP1800748B1 (en) | Method of selective hydrogenation using a sulphided catalyst | |
EP2169032B1 (en) | Catalyst capable of at least partially decomposing or hydrogenating unsaturated sulfur compounds | |
EP2161076B1 (en) | Selective hydrogenation method using a sulphurated catalyst with a specific composition | |
EP3428248B1 (en) | Partially coked catalysts for use in the hydrotreatment of cuts containing sulphurous compounds and olefins | |
EP1746144B1 (en) | New process for olefinic gasoline desulfurisation which limits mercaptan content | |
EP1849850A1 (en) | Method of desulphurating olefin gasolines comprising at least two distinct hydrodesulphuration steps | |
EP2072607A1 (en) | Two-step method of desulphurating olefin gasolines comprising arsenic | |
EP2644683B1 (en) | Method for selective hydrogenation of a gasoline | |
EP2816094A1 (en) | Method for producing gasoline with low sulphur and mercaptan content | |
EP1369466B1 (en) | Hydrodesulfurization of sulphur and olefins containing fractions with a metals of groups VIII and VIB containing supported catalyst. | |
EP1800750A2 (en) | Method of selective hydrogenation using a catalyst with controlled porosity | |
EP1369467B1 (en) | Hydrodesulfurization of sulphur and olefins containing fractions with a supported catalyst containing an element of group VIII and tungsten. | |
FR2993571A1 (en) | METHOD OF DESULFURIZING A GASOLINE | |
WO2014068209A1 (en) | Process for producing a petrol with low sulphur content | |
EP2796196B1 (en) | Catalytic adsorber for arsenic collection and selective hydrodesulphurisation of gasoline | |
WO2021013527A1 (en) | Method for producing a petrol with low sulfur and mercaptans content | |
EP4004158A1 (en) | Method for producing gasoline with low sulfur and mercaptan content | |
EP3283601B1 (en) | Method for sweetening an olefinic petrol of sulphide-type compounds | |
WO2021185658A1 (en) | Method for producing a gasoline having a low sulfur and mercaptan content | |
EP4004159A1 (en) | Method for producing a petrol with low sulphur and mercaptan content | |
WO2021013525A1 (en) | Process for treating a gasoline by separation into three cuts |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
PUAI | Public reference made under article 153(3) epc to a published international application that has entered the european phase |
Free format text: ORIGINAL CODE: 0009012 |
|
AK | Designated contracting states |
Kind code of ref document: A1 Designated state(s): AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HU IE IS IT LI LT LU MC NL PL PT RO SE SI SK TR |
|
AX | Request for extension of the european patent |
Extension state: AL BA HR LV MK YU |
|
RIN1 | Information on inventor provided before grant (corrected) |
Inventor name: BOUCHY, CHRISTOPHE Inventor name: PICARD, FLORENT Inventor name: MARCHAL, NATHALIE |
|
17P | Request for examination filed |
Effective date: 20060704 |
|
AKX | Designation fees paid |
Designated state(s): BE DE DK GB IT NL |
|
GRAP | Despatch of communication of intention to grant a patent |
Free format text: ORIGINAL CODE: EPIDOSNIGR1 |
|
GRAS | Grant fee paid |
Free format text: ORIGINAL CODE: EPIDOSNIGR3 |
|
GRAA | (expected) grant |
Free format text: ORIGINAL CODE: 0009210 |
|
AK | Designated contracting states |
Kind code of ref document: B1 Designated state(s): BE DE DK GB IT NL |
|
REG | Reference to a national code |
Ref country code: GB Ref legal event code: FG4D Free format text: NOT ENGLISH |
|
REF | Corresponds to: |
Ref document number: 602005003402 Country of ref document: DE Date of ref document: 20080103 Kind code of ref document: P |
|
GBT | Gb: translation of ep patent filed (gb section 77(6)(a)/1977) |
Effective date: 20071219 |
|
REG | Reference to a national code |
Ref country code: DK Ref legal event code: T3 |
|
PLBI | Opposition filed |
Free format text: ORIGINAL CODE: 0009260 |
|
PLBI | Opposition filed |
Free format text: ORIGINAL CODE: 0009260 |
|
26 | Opposition filed |
Opponent name: EXXONMOBIL RESEARCH AND ENGINEERING COMPANY Effective date: 20080801 |
|
PLAB | Opposition data, opponent's data or that of the opponent's representative modified |
Free format text: ORIGINAL CODE: 0009299OPPO |
|
PLAX | Notice of opposition and request to file observation + time limit sent |
Free format text: ORIGINAL CODE: EPIDOSNOBS2 |
|
26 | Opposition filed |
Opponent name: ALBEMARLE CATALYSTS B.V. Effective date: 20080820 Opponent name: EXXONMOBIL RESEARCH AND ENGINEERING COMPANY Effective date: 20080801 |
|
R26 | Opposition filed (corrected) |
Opponent name: ALBEMARLE CATALYSTS B.V. Effective date: 20080820 Opponent name: EXXONMOBIL RESEARCH AND ENGINEERING COMPANY Effective date: 20080801 |
|
NLR1 | Nl: opposition has been filed with the epo |
Opponent name: EXXONMOBIL RESEARCH AND ENGINEERING COMPANY |
|
NLR1 | Nl: opposition has been filed with the epo |
Opponent name: EXXONMOBIL RESEARCH AND ENGINEERING COMPANY Opponent name: ALBEMARLE CATALYSTS B.V. |
|
PLAF | Information modified related to communication of a notice of opposition and request to file observations + time limit |
Free format text: ORIGINAL CODE: EPIDOSCOBS2 |
|
PLBB | Reply of patent proprietor to notice(s) of opposition received |
Free format text: ORIGINAL CODE: EPIDOSNOBS3 |
|
APBM | Appeal reference recorded |
Free format text: ORIGINAL CODE: EPIDOSNREFNO |
|
APBP | Date of receipt of notice of appeal recorded |
Free format text: ORIGINAL CODE: EPIDOSNNOA2O |
|
APAH | Appeal reference modified |
Free format text: ORIGINAL CODE: EPIDOSCREFNO |
|
APBM | Appeal reference recorded |
Free format text: ORIGINAL CODE: EPIDOSNREFNO |
|
APBP | Date of receipt of notice of appeal recorded |
Free format text: ORIGINAL CODE: EPIDOSNNOA2O |
|
APAW | Appeal reference deleted |
Free format text: ORIGINAL CODE: EPIDOSDREFNO |
|
APAY | Date of receipt of notice of appeal deleted |
Free format text: ORIGINAL CODE: EPIDOSDNOA2O |
|
APBM | Appeal reference recorded |
Free format text: ORIGINAL CODE: EPIDOSNREFNO |
|
APBP | Date of receipt of notice of appeal recorded |
Free format text: ORIGINAL CODE: EPIDOSNNOA2O |
|
APBQ | Date of receipt of statement of grounds of appeal recorded |
Free format text: ORIGINAL CODE: EPIDOSNNOA3O |
|
APBQ | Date of receipt of statement of grounds of appeal recorded |
Free format text: ORIGINAL CODE: EPIDOSNNOA3O |
|
RAP2 | Party data changed (patent owner data changed or rights of a patent transferred) |
Owner name: IFP ENERGIES NOUVELLES |
|
APBU | Appeal procedure closed |
Free format text: ORIGINAL CODE: EPIDOSNNOA9O |
|
PLAY | Examination report in opposition despatched + time limit |
Free format text: ORIGINAL CODE: EPIDOSNORE2 |
|
PLBC | Reply to examination report in opposition received |
Free format text: ORIGINAL CODE: EPIDOSNORE3 |
|
PLAY | Examination report in opposition despatched + time limit |
Free format text: ORIGINAL CODE: EPIDOSNORE2 |
|
PUAH | Patent maintained in amended form |
Free format text: ORIGINAL CODE: 0009272 |
|
STAA | Information on the status of an ep patent application or granted ep patent |
Free format text: STATUS: PATENT MAINTAINED AS AMENDED |
|
27A | Patent maintained in amended form |
Effective date: 20160330 |
|
AK | Designated contracting states |
Kind code of ref document: B2 Designated state(s): BE DE DK GB IT NL |
|
REG | Reference to a national code |
Ref country code: DE Ref legal event code: R102 Ref document number: 602005003402 Country of ref document: DE |
|
REG | Reference to a national code |
Ref country code: DE Ref legal event code: R082 Ref document number: 602005003402 Country of ref document: DE Representative=s name: VKK PATENTANWAELTE, DE Ref country code: DE Ref legal event code: R082 Ref document number: 602005003402 Country of ref document: DE Representative=s name: VKK PATENTANWAELTE PARTG MBB, DE |
|
REG | Reference to a national code |
Ref country code: DK Ref legal event code: T4 Effective date: 20160704 |
|
REG | Reference to a national code |
Ref country code: NL Ref legal event code: FP |
|
PGFP | Annual fee paid to national office [announced via postgrant information from national office to epo] |
Ref country code: NL Payment date: 20230626 Year of fee payment: 19 Ref country code: DK Payment date: 20230621 Year of fee payment: 19 Ref country code: DE Payment date: 20230627 Year of fee payment: 19 |
|
P01 | Opt-out of the competence of the unified patent court (upc) registered |
Effective date: 20230712 |
|
PGFP | Annual fee paid to national office [announced via postgrant information from national office to epo] |
Ref country code: BE Payment date: 20230626 Year of fee payment: 19 |
|
PGFP | Annual fee paid to national office [announced via postgrant information from national office to epo] |
Ref country code: IT Payment date: 20230620 Year of fee payment: 19 Ref country code: GB Payment date: 20230620 Year of fee payment: 19 |