EP0899320B1 - Hydroraffinierungsverfahren und -anlage für Erdöleinsätze mit Ammoniakspaltung und Wasserstoffrückführung - Google Patents

Hydroraffinierungsverfahren und -anlage für Erdöleinsätze mit Ammoniakspaltung und Wasserstoffrückführung Download PDF

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EP0899320B1
EP0899320B1 EP98402040A EP98402040A EP0899320B1 EP 0899320 B1 EP0899320 B1 EP 0899320B1 EP 98402040 A EP98402040 A EP 98402040A EP 98402040 A EP98402040 A EP 98402040A EP 0899320 B1 EP0899320 B1 EP 0899320B1
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Prior art keywords
hydrogen
unit
hydrogen sulfide
effluent
cracking
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French (fr)
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EP0899320A1 (de
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Christian Streicher
Fabrice Lecomte
Christian Busson
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IFP Energies Nouvelles IFPEN
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IFP Energies Nouvelles IFPEN
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    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G49/00—Treatment of hydrocarbon oils, in the presence of hydrogen or hydrogen-generating compounds, not provided for in a single one of groups C10G45/02, C10G45/32, C10G45/44, C10G45/58 or C10G47/00
    • C10G49/007—Treatment of hydrocarbon oils, in the presence of hydrogen or hydrogen-generating compounds, not provided for in a single one of groups C10G45/02, C10G45/32, C10G45/44, C10G45/58 or C10G47/00 in the presence of hydrogen from a special source or of a special composition or having been purified by a special treatment
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G49/00—Treatment of hydrocarbon oils, in the presence of hydrogen or hydrogen-generating compounds, not provided for in a single one of groups C10G45/02, C10G45/32, C10G45/44, C10G45/58 or C10G47/00
    • C10G49/22—Separation of effluents

Definitions

  • the invention relates to a method and a device for catalytic cracking of ammonia. contained in a gaseous or liquid fluid which comprises hydrogen sulphide, thus that the separation of the hydrogen produced by this cracking of ammonia and the use of this hydrogen in a process for hydrotreating a hydrocarbon feed containing sulfur and nitrogen.
  • Hydrotreatments Pressurized hydrogen treatments of liquid petroleum fractions (hydrotreatments) are well known and widely used methods to improve the properties of these cuts. These treatments make it possible in particular to convert the organic compounds containing hetero atoms (sulfur, nitrogen) in hydrocarbons and mineral compounds (hydrogen sulfide, ammonia), which can then easily be separated by simple operations such as stripping (distillation) and water washes. Greater concern for environmental protection leads to lowering the sulfur and nitrogen contents of petroleum products and therefore to increase the quantity of hydrogen necessary for the operation of hydrotreatment units.
  • Refiners are therefore required to send this product to the thermal stage of a unit Claus.
  • the combustion of ammonia at the thermal stage of a Claus unit is tricky. It sometimes requires more or less modifications equipment of the Claus unit. This combustion, when it is not performed correctly, can also cause many operational difficulties (clogging, corrosion of the Claus unit). Finally, it causes a dilution of the Claus unit detrimental to the performance of this unit.
  • An object of the invention is to allow recovery, at least partially at the level a hydrotreating unit, hydrogen present in the form of ammonia especially in acidic refinery waters.
  • the invention relates to a catalytic cracking process for ammonia present in a fluid containing hydrogen sulfide, in which introduces the fluid into a reaction zone comprising an appropriate catalyst, characterized in that the temperature of said reaction zone is from 1000 to 1400 ° C and in that the cracking effluent obtained at the outlet of said reaction zone is sent to a hydrogen recovery unit treating one or more high purge gases pressure of hydrotreating unit (s), after being possibly cooled and / or partially condensed and / or compressed and / or treated by an amine washing unit.
  • hydrotreating unit hydrotreating unit
  • This cracking process can be implemented in a hydrotreatment process.
  • the invention relates to a process for hydrotreating a hydrocarbon feed containing sulfur and nitrogen, in which the feed is hydrotreated in the presence of a catalyst in a hydrotreating zone (HDT), recovering a hydrotreated hydrocarbon product, a high pressure purge gas (12) comprising hydrogen, hydrogen sulfide and light hydrocarbons (C 5 -) and a first effluent containing water and sulfide ammonium, the first effluent is purified in a stripping zone so as to recover hydrogen sulfide and ammonia, the first effluent is introduced into a cracking zone comprising a catalyst, heated between 1000 and 1400 ° C, recovers a cracking effluent (9,11) comprising hydrogen sulfide, hydrogen and nitrogen resulting from the cracking of ammonia, the method being characterized in that said cracking effluent is cooled to a temperature a liquefies, a gaseous phase (11) comprising nitrogen, hydrogen and hydrogen sul
  • the high pressure purge gas (12) originating of the hydrotreating zone can be introduced with said gaseous phase into the unit (20) extraction of hydrogen sulfide and recovering a hydrogen-rich gas sulfide and the gas phase substantially free of hydrogen sulfide.
  • the cracking effluent can be cooled to a temperature from 30 to 100 ° C in an E2 heat exchanger during a period of time at least equal to 1 second and preferably between 1 and 5 seconds.
  • the first effluent can be compressed to a pressure from 2 to 10 MPa compatible with the hydrogen sulphide extraction unit, before its introduction into the cracking zone.
  • the cooled cracking effluent can be compressed in the exchanger E2 at a pressure of 2 to 10 MPa, compatible with the hydrogen extraction unit sulfide.
  • the gaseous phase is recovered which is introduced into said hydrogen sulfide extraction unit and a phase aqueous liquid.
  • This aqueous liquid phase can advantageously be recycled in the stripping zone into which is introduced the effluent from the hydrotreatment zone which contains hydrogen sulfide and ammonia produced by the hydrotreatment unit, in the form of an aqueous solution of ammonium sulfide.
  • This solution is striped there and we can recover on the one hand purified water at the bottom of the stripping zone and on the other hand, head of the stripping zone, the gaseous effluent containing water vapor, hydrogen sulfide and ammonia which is sent to the cracking zone Catalytic.
  • the invention relates to a unit for hydrotreating a hydrocarbon feed containing sulfur and nitrogen comprising a hydrotreatment reactor (HDT) which comprises a feed (1) with the feed, a feed (7) with hydrogen, a racking (2) of hydrotreated product, a racking (12) of purge gas, a racking (3) of an effluent containing water and ammonium sulfide, an extraction unit (20) of l hydrogen sulfide contained in the purge gas connected to the HDT reactor, said extraction unit comprising a line (14) for recovery of a product rich in hydrogen sulfide and a line (13) for recovery of a product poor in hydrogen sulphurized and rich in hydrogen, at least one hydrogen separator (SM) connected to the line (13) for recovering the product poor in hydrogen sulphurized and rich in hydrogen and at least one means (16) for recycling the recovered hydrogen connected to the hydrogen separator and the hy reactor drotreatment, the hydrotreatment unit being characterized in that it comprises a means for stripping (SE) of
  • the ammonia produced by the HDT unit is recovered by washing the effluent from the hydrotreatment reactor, in the form of an aqueous solution of ammonium sulphide sent by line 3 to a SE wastewater stripper.
  • This stripper can possibly also supplied, via line 4, with other wastewater similar from other units not shown in the figure.
  • the SE stripper produces purified water at the bottom, essentially free of ammonium sulphide which can be sent back to the HDT hydrotreating unit for washing with water reactor effluent, via a line 5, and possibly to other units via a line 6.
  • a gaseous effluent essentially consisting of water vapor and quantities substantially equal to hydrogen sulfide and ammonia.
  • the water content of the effluent gas is generally between 10 and 80%.
  • the effluent can be compressed in a K compressor to a sufficient pressure to allow it, after passing through an exchanger E1, a reactor F for cracking ammonia, an E2 exchanger and a separator tank C, to be admitted to the washing unit high pressure amines 20, treating the unit's high pressure purge gas HDT hydrotreatment.
  • this compression stage K placed here preferably before reactor F, can also be placed after reactor F, in E2 exchanger outlet.
  • the latter arrangement has the disadvantage of require compression of a larger gas volume, 1 mole of ammonia being dissociated in reactor F in 0.5 mole of nitrogen and 1.5 mole of hydrogen. It is also possible to compress the gaseous effluent to the pressure required for admission to the high pressure amine washing unit in two stages placed respectively before and after reactor F, as indicated above.
  • the compressed effluent is then sent by a line 8 to the reactor F, being possibly preheated in exchanger E1, before admission to reactor F well said.
  • Preheating can be carried out by any conventional means of heating like an oven, but also by heat exchange with the effluent at high temperature leaving reactor F.
  • Reactor F is the seat of the reaction zone where the cracking of ammonia into nitrogen and hydrogen, including an embodiment and the conditions for implementation are described in patent application FR 2 745 806 of the Applicant.
  • reaction effluent leaving reactor F via a line 9, at high temperature generally above 1000 ° C, is cooled in the exchanger E2 to a temperature allowing admission to the high pressure amine washing unit; this temperature is generally between 30 and 100 ° C, preferably between 40 and 60 ° C.
  • This reaction effluent is essentially composed of nitrogen and the resulting hydrogen of the decomposition of ammonia in reactor F, as well as hydrogen sulfide and water vapor present at the inlet and unreacted in reactor F.
  • this reaction effluent may contain traces of ammonia which have not been broken down in reactor F.
  • the residual ammonia content in the reaction effluent usually does not exceed 1% volume, and is preferably less than 0.2% volume.
  • the cooling of the reaction effluent can be carried out with a residence time in the exchanger E2, high enough to allow elemental sulfur from dissociation of part of the hydrogen sulfide in reactor F, to recombine entirely with the hydrogen present in hydrogen sulfide. Lack of catalyst allows in the E2 exchanger to avoid significant recombination of nitrogen and hydrogen to ammonia.
  • the effluent cooled at the outlet of E2 is therefore essentially free of elemental sulfur.
  • the residence time of the reaction effluent in the exchanger E2 is at least equal to 1 second, preferably between 1 and 5 seconds.
  • reaction effluent would be cooled to a temperature slightly above the melting point of sulfur, i.e. temperature between 120 and 130 ° C. Elemental sulfur present in the effluent after this first stage could be recovered, in the form of liquid sulfur by decantation in a separating flask. The cooling of the reaction effluent as well rid of the elemental sulfur it contained can then be continued until the temperature required in a second stage.
  • the cooling of the reaction effluent may, depending on the final temperature reached in outlet of E2 and the water content of said effluent, cause partial condensation of the water present in this effluent. If such condensation occurs, the aqueous phase thus formed can be separated by decantation in the separator flask C.
  • a liquid aqueous phase can be recovered at the bottom of the flask C which may contain all residual ammonia present in the reaction effluent, as well as hydrogen sulphide dissolved in proportions substantially equivalent (in moles) to that of ammonia.
  • This aqueous phase can be returned by a line 10 to the stripper SE.
  • This system allows recycling of unreacted ammonia in oven F and therefore to obtain total destruction of the ammonia present in the acid waters supplying the stripper SE.
  • a gaseous phase is then recovered which consists solely of nitrogen, hydrogen and most of the hydrogen sulfide present in the reaction effluent, in molar proportions substantially equal to 2 H 2 S / 1 N 2/3 H 2, and a small amount of water vapor, generally less than 5 vol%, preferably less than 1% by volume, corresponding to the vapor pressure of water in the separator tank temperature vs.
  • This gas phase can then be sent by a line 11 to a unit 20 of high pressure amine wash treating the high pressure purge gas produced the HDT hydrotreating unit by a line 12.
  • This purge gas is essentially composed of hydrogen, hydrogen sulfide and hydrocarbons having mainly 1 with 5 carbon atoms, in varying proportions. It may also contain low contents, generally less than 5% vol, of other compounds such as nitrogen and water vapor.
  • the purge gas and the gas phase are mixed and washed with a solution of amines so as to extract the hydrogen sulphide from the gases. Washing with amines is generally carried out at the pressure of the purge gas, this pressure being generally between 2 to 10 MPa, preferably between 3 and 7 MPa, and at a temperature generally between 30 and 100 ° C, preferably between 40 and 60 ° C.
  • the amine unit then produces, under substantially equal pressure and temperature to those for washing, a washed gas essentially free of hydrogen sulfide and containing the major part of the other compounds of the treated gases.
  • the washed gas generally contains from 20 to 95% vol of hydrogen, preferably from 50 to 90% vol, with variable proportions of nitrogen, hydrocarbons from 1 to 5 carbon atoms and traces of water vapor (corresponding substantially to the vapor pressure of water at the temperature of said washing).
  • the amine unit also produces, under a pressure generally lower than that washing, preferably between 0.2 and 0.5 MPa abs. a gas rich in hydrogen sulfide, preferably containing at least 50% vol of hydrogen sulfide with varying proportions of hydrocarbons, which is usually sent, via a line 14, to a Claus unit.
  • the washed gas can then be sent via a line 13 to a recovery unit hydrogen.
  • This unit can be a cryogenic distillation, adsorption process or separation by membranes.
  • the washed gas being available under pressure relatively high a separation by membranes is preferably used such than the SM unit shown in the figure.
  • the washed gas can optionally be slightly cooled or reheated before being admitted to the permeation unit proper so as to be at the optimum temperature to separate hydrogen by gas permeation, this temperature being generally understood between 30 and 150 ° C, preferably between 50 and 100 ° C.
  • the SM unit then makes it possible to produce, on the one hand, a gas depleted in hydrogen (retentate), generally containing less than 50% vol of hydrogen, preferably from 5 to 30% theft with most of the other compounds present in said washed gas, under a pressure close to that of the washed gas; on the other hand a gas enriched in hydrogen (permeate), generally containing more than 90% vol, preferably more than 95% flight of hydrogen with varying proportions of the other compounds present in the washed gas, under a pressure lower than that of the washed gas, generally less than 2 MPa abs. and preferably between 0.5 and I MPa abs.
  • retentate gas depleted in hydrogen
  • permeate enriched in hydrogen
  • the retentate can then for example be sent via a line 15 to the gas network fuel from the refinery.
  • the permeate, recovered via line 16 can be mixed with the make-up hydrogen supplying the HDT hydrotreating unit, via a line 17.
  • One of the advantages of the process of the invention is that it allows total destruction of ammonia present in refinery wastewater, without any harmful release to the atmosphere.
  • Another advantage of the process of the invention lies in the fact that hydrogen sulfide present in the form of ammonium sulfide in refinery wastewater, can thus be sent to the Claus unit in a concentrated form, in particular free ammonia but also free of products (nitrogen and hydrogen) formed by the dissociation of this ammonia. This avoids combustion problems of ammonia in the Claus units and in particular to reduce the gas dilution of Claus.
  • Another advantage of the process lies in the possibility that it offers to recycle a part significant hydrogen present in the form of ammonia in the wastewater of refinery.
  • a last advantage of the process lies in its simplicity and in particular in the fact that it only requires the additional installation of a reduced number equipment, compared to those normally found in an equipped refinery hydrotreating units.
  • the amine washing units of the purge gas high pressure, hydrogen recovery by membrane on the high purge gas pressure SM and sewage stripping SE are normally present around the modern hydrotreating units.
  • the method of the invention can be installed generally without significant modification of these existing units. So it does require that the specific installation of compressor K, oven F, exchangers E1 and E2, as well as the separator flask C.
  • This unit produces by line 3 waste water at a flow rate of 8173 kg / h and containing 0.6% by weight of ammonium sulphide.
  • This water is treated in a SE stripper, which is operated under a pressure of 0.2 MPa abs.
  • This stripper is further supplied, via line 4, with a flow rate of 132,550 kg / h of water containing 2% by weight of ammonium sulphide, coming from another refining unit.
  • the stripper produces at the head, at a temperature of 80 ° C., a gas containing 20% mol of water vapor, 40% mol of ammonia and 40% mol of hydrogen sulfide, at a flow rate of 2965 Nm 3 / h .
  • it produces purified water at a temperature of 119 ° C and at a flow rate of 137,548 kg / h.
  • the gas obtained at the top of the stripper should be sent to cremation or to a Claus unit when possible.
  • the hydrotreating unit is also supplied, by line 17, with a make-up gas rich in hydrogen. Most of this hydrogen is consumed chemically by hydrotreatment reactions. Another part is found in the purge gas high pressure produced by line 12, under a pressure of 4.6 MPa abs. This gas is desulphurized by washing with amines and then admitted via line 13 into a unit of hydrogen recovery by polyaramide membrane (Medal). We can thus recover most of the hydrogen present in the high pressure purge gas and recycle it via line 16 to the hydrotreating unit.
  • Table 1 shows the hydrogen balance of the hydrotreatment unit, as it usually occurs when the process of the invention is not implemented. Hydrogen balance of the hydrotreating unit in the absence of the process of the invention extra (17) HP purge (12) Washed purge (13) retentate (15) permeate (16) Composition (%flight) H 2 91.93 79.48 81.10 47.26 98.77 C 1 + 6.65 15.35 15.66 43.99 0.87 N 2 1.36 3.18 3.24 8.75 0.36 H 2 S - 1.99 - - H 2 O - - - - NH 3 - - - - P (bar abs) 20 46 45 45 20 T (° C) 90 50 50 90 90 Flow (Nm 3 / h) 23536 8166 8003 2746 5257
  • the SE stripper is then supplied not only with 8,173 kg / h of waste water at 0.6% wt of ammonium sulphide coming from the HDT unit and with 132550 kg / h of water containing 2% wt of sulphide d ammonium, but also, via line 10, by the water condensed in the separator flask C.
  • the flow rate of this condensed water is 473 kg / h and it contains 0.85% by weight of ammonium sulphide.
  • the stripper SE then produces at the head, under a pressure of 0.2 MPa abs.
  • the gas thus obtained at the top of the stripper SE is compressed in the compressor K to a pressure of 0.7 MPa abs. then reheated in the exchanger E1 to a temperature of 1000 ° C. This hot gas then feeds an oven F, produced according to the method described in application FR 96 / 02.909 of the Applicant.
  • the hot gas leaving the oven F is cooled in the exchanger E2 to a temperature of 50 ° C.
  • the residence time in the exchanger E2 is fixed at 2 s. This cooling causes most of the water vapor present in the gas leaving the oven to condense. It is this condensed water which is recovered at the level of the separator flask C and is returned by line 10 to the stripper SE.
  • the cracked gas thus recovered by line 11 is compressed to a pressure of 4.6 Mpa abs. in a second compressor K1, not shown in the figure, then mixed with the high-pressure purge gas leaving the HDT unit via line 12.
  • This gas mixture is washed in the amine washing unit 20 which produces through the line 13 a washed gas supplying the membrane separator SM at a pressure of 4.5 MPa.
  • the permeate from the SM unit is recycled to the hydrotreating unit.
  • Table 2 shows the hydrogen balance of the hydrotreatment unit when the process of the invention is implemented.

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  • Engineering & Computer Science (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
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Claims (11)

  1. Verfahren zum Hydrotreatment einer Schwefel und Stickstoff enthaltenden Kohlenwasserstoffcharge, in dem die Charge in Gegenwart eines Katalysators in einer Hydrotreatmentzone (HDT) hydrierbehandelt wird, ein hydrierbehandeltes Kohlenwasserstoffprodukt, ein Hockdruckentleerungsgas (12), das Wasserstoff, Schwefelwasserstoff und leichte Kohlenwasserstoffe (C5-) umfasst, und ein erster, Wasser und Ammoniumsulfid enthaltender Abstrom gewonnen wird, der erste Abstrom in einer Abstreifzone (SE) derart gereinigt wird, dass Schwefelwasserstoff und Ammoniak gewonnen wird, der erste Abstrom in eine Crackzone mit einem Katalysator eingeführt wird, die zwischen 1000 und 1400°C beheizt ist, ein Crackabstrom (9, 11) gewonnen wird, der Schwefelwasserstoff, Wasserstoff und Stickstoff umfasst, welcher aus dem Kracken von Ammoniak resultiert, wobei das Verfahren dadurch gekennzeichnet t ist, dass der Crackabstrom bei einer geeigneten Temperatur gekühlt wird, eine Gasphase (11) gewonnen wird, die Stickstoff, Wasserstoff und Schwefelwasserstoff umfasst, diese Gasphase in eine Einheit (20) zum Extrahieren des Schwefelwasserstoffs eingeführt wird, man die so im wesentlichen von Schwefelwasserstoff befreite Gasphase in einer Wasserstoffgewinnungseinheit (SM) passieren lässt und wenigstens ein Teil des in der Hydrotreatmentzone (HDT) gewonnenen Wasserstoffs rezykliert wird.
  2. Verfahren nach Anspruch 1, bei dem das aus der Hydrotreatmentzone kommende Hockdruckentleerungsgas (12) in die Einheit (20) zum Extrahieren des Schwefelwasserstoffs eingeführt wird und das schwefelwasserstoffreiche Gas und die im wesentlichen von Schwefelwasserstoff befreite Gasphase gewonnen wird.
  3. Verfahren nach Anspruch 1 und 2, bei dem man den Crackabstrom auf eine Temperatur von 30 bis 100°C in einem Wärmetauscher E2 in einem Zeitraum von wenigstens 1 Sekunde, vorzugsweise zwischen 1 und 5 Sekunden kühlt.
  4. Verfahren nach einem der Ansprüche 1 bis 3, bei dem der erste Abstrom auf einen Druck von 2 bis 10 MPa, kompatibel mit der Einheit zum Extrahieren des Schwefelwasserstoffs vor dessen Verwendung in der Crackzone komprimiert wird.
  5. Verfahren nach einem der Ansprüche 1 bis 4, bei dem der in dem Austauscher E2 gekühlte Crackabstrom auf einem Druck von 2 bis 10 MPa, kompatibel mit der Einheit zum Extrahieren des Schwefelwasserstoffs vor dessen Verwendung in der Crackzone komprimiert wird.
  6. Verfahren nach einem der Ansprüche 1 bis 5, bei dem die Einheit zum Extrahieren des Schwefelwasserstoffs eine Einheit zur Hochdruckextraktion der Amine ist.
  7. Verfahren nach einem der Ansprüche 1 bis 6, bei dem die Einheit zur Wasserstoffgewinnung eine Einheit zur Permeation durch eine Membran ist.
  8. Verfahren nach einem der Ansprüche 1 bis 7, bei dem wenigstens ein Teil des in dem Crackabstrom enthaltenen Wassers durch Dekantieren getrennt wird, die Gasphase, die man in die Einheit zum Extrahieren des Schwefelwasserstoffs einführt, und eine wässrige Flüssigphase gewonnen wird.
  9. Verfahren nach Anspruch 8, bei dem die wässrige Flüssigphase in die Abstreifzone rezykliert wird.
  10. Einheit zum Hydrotreatment einer Schwefel und Stickstoff enthaltenden Kohlenwasserstoffcharge, die einen Hydrotreatmentreaktor (HDT), welcher eine Chargenversorgung (1), eine Wasserstoffversorgung (17), einen Abzug (2) von hydrierbehandeltem Produkt, einen Abzug (12) von Entleerungsgas, einen Abzug (3) von einem Wasser und Ammoniumsulfid enthaltendem Abstrom umfasst, eine Einheit (20) zum Extrahieren des in dem Entleerungsgas enthaltenden Schwefelwasserstoffs, die mit dem Reaktor (HDT) verbunden ist, wobei die Extraktionseinheit eine Leitung (14) zur Gewinnung eines schwefelwasserstoffreichen Produkts und eine Leitung (13) zur Gewinnung eines schwefelwasserstoffarmen und wasserstoffreichen Produkts umfasst, wenigstens einen Separator (SM) von Wasserstoff, der mit der Leitung (13) zur Gewinnung des schwefelwasserstoffarmen und wasserstoffreichen Produkts verbunden ist, und wenigstens ein Mittel (16) zur Rezyklierung des gewonnenen Wasserstoffs , das mit dem Separator von Wasserstoff und dem Hydrotreatmentreaktor verbunden ist, enthält, wobei die Einheit zum Hydrotreatment dadurch gekennzeichnet ist, dass sie ein Mittel (SE) zum Abstreifen des Abstroms, das mit dem Abzug (3) verbunden ist, wenigstens einen Reaktor zum katalytischen Cracken des abgestreiften Abstroms, der ausgelegt ist, um zwischen 1000 und 1400°C zu arbeiten und mit dem Mittel (SE) zum Abstreifen verbunden ist, wenigstens ein Kühlmittel (E2) des gecrackten wasserstoffhaltigen Abstroms , wenigstens einen Kompressor (K) vor dem Crackreaktor oder hinter dem Kühlmittel (E2) und eine Austrittsleitung (11) einer Gasphase, die mit der Einheit (20) zum Extrahieren des Schwefelwasserstoffs verbunden ist, umfasst.
  11. Einheit nach Anspruch 10, bei der ein Phasenseparator zwischen dem Kühlmittel E2 und der Extraktionseinheit (20) eingeschoben ist, welcher eine Leitung (10) zur Rezyklierung einer Flüssigphase in das Mittel zum Abstreifen und die Leitung (11) einer Gasphase, die mit der Einheit (20) zum Extrahieren von Schwefelwasserstoff verbunden ist, umfasst.
EP98402040A 1997-08-25 1998-08-12 Hydroraffinierungsverfahren und -anlage für Erdöleinsätze mit Ammoniakspaltung und Wasserstoffrückführung Expired - Lifetime EP0899320B1 (de)

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FR9710679 1997-08-25
FR9710679A FR2767529B1 (fr) 1997-08-25 1997-08-25 Procede et unite d'hydrotraitement d'une charge petroliere comprenant le craquage de l'ammoniac et le recyclage de l'hydrogene dans l'unite

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EP0899320A1 EP0899320A1 (de) 1999-03-03
EP0899320B1 true EP0899320B1 (de) 2002-11-06

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US (1) US6096195A (de)
EP (1) EP0899320B1 (de)
CA (1) CA2243626A1 (de)
DE (1) DE69809159T2 (de)
ES (1) ES2186985T3 (de)
FR (1) FR2767529B1 (de)

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FR2837273B1 (fr) * 2002-03-15 2004-10-22 Inst Francais Du Petrole Procede d'elimination au moins partielle de depots carbones dans un echangeur de chaleur
CA2546462C (en) * 2003-12-05 2012-07-17 Exxonmobil Research And Engineering Company A process for the acid extraction of hydrocarbon feed
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FR2767529A1 (fr) 1999-02-26
CA2243626A1 (fr) 1999-02-25
ES2186985T3 (es) 2003-05-16
DE69809159T2 (de) 2003-03-20
US6096195A (en) 2000-08-01
EP0899320A1 (de) 1999-03-03
FR2767529B1 (fr) 1999-10-08
DE69809159D1 (de) 2002-12-12

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