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WO1993000674A1 - Procede de rectification et de regeneration d'un catalyseur de craquage catalytique fluidise - Google Patents

Procede de rectification et de regeneration d'un catalyseur de craquage catalytique fluidise Download PDF

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Publication number
WO1993000674A1
WO1993000674A1 PCT/US1991/004499 US9104499W WO9300674A1 WO 1993000674 A1 WO1993000674 A1 WO 1993000674A1 US 9104499 W US9104499 W US 9104499W WO 9300674 A1 WO9300674 A1 WO 9300674A1
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WO
WIPO (PCT)
Prior art keywords
catalyst
stripper
regenerator
spent
hot
Prior art date
Application number
PCT/US1991/004499
Other languages
English (en)
Inventor
Paul Herbert Schipper
Hartley Owen
Amos Andrew Avidan
Original Assignee
Mobil Oil Corporation
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by Mobil Oil Corporation filed Critical Mobil Oil Corporation
Priority to PCT/US1991/004499 priority Critical patent/WO1993000674A1/fr
Priority to AU80916/91A priority patent/AU8091691A/en
Priority to CA002112133A priority patent/CA2112133A1/fr
Priority claimed from AU80916/91A external-priority patent/AU8091691A/en
Publication of WO1993000674A1 publication Critical patent/WO1993000674A1/fr

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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
    • C10G11/00—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
    • C10G11/14—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts
    • C10G11/18—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "fluidised-bed" technique
    • C10G11/182—Regeneration
    • 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
    • C10G11/00—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
    • C10G11/14—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts
    • C10G11/18—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "fluidised-bed" technique

Definitions

  • the invention relates to a process and apparatus for stripping and regenerating fluidized catalytic cracking catalyst.
  • catalyst circulates between a cracking reactor and a catalyst regenerator.
  • hydrocarbon feed contacts a source of hot, regenerated catalyst, which vaporizes and cracks the feed at a temperature fo 425-600°C, usually 460-560°C.
  • the cracking, reaction deposits carbonaceous hydrocarbons or coke on the catalyst, thereby deactivating the catalyst.
  • the cracked products are separated from the coked catalyst, which is then stripped of volatiles, usually with steam, in a catalyst stripper.
  • the stripped catalyst is then passed to the catalyst regenerator, where coke is burned from the catalyst with oxygen containing gas, usually air.
  • Decoking restores catalyst activity and simultaneously heats the catalyst to, for example, 500-900°C, usually 600-750 ⁇ C. This heated catalyst is recycled to the cracking reactor to crack more fresh feed. Flue gas formed by burning coke in the regenerator may. be treated for removal of particulates and for conversion of carbon monoxide, after which the flue gas is normally discharged into the atmosphere.
  • Catalyst passing from an FCC stripper to an FCC regenerator contains hydrogen-containing components, such as coke or unstripped hydrocarbons adhering thereto. This hydrogen burns in the regenerator to form water and cause hydrothermal degradation.
  • Regenerators are operating at higher and higher temperatures. This is because most FCC units are heat balanced, that is, the endothermic heat of the cracking reaction is supplied by burning the coke deposited on the catalyst. With heavier feeds, more coke is deposited on the catalyst than is needed for the cracking reaction. The regenerator gets hotter, and the extra heat is rejected as high temperature flue gas. Many refiners severely limit the amount of resid or similar high CCR feeds to that amount which can be tolerated by the unit. High temperatures are a problem for the metallurgy of many units, but more importantly, are a problem for the catalyst. In the regenerator, the burning of coke and unstripped hydrocarbons leads to much higher surface temperatures on the catalyst than the measured dense bed or dilute phase temperature. This is discussed by Occelli et al in "Dual-Function Cracking Catalyst Mixtures", Ch. 12, Fluid Catalytic Cracking, ACS Symposium Series 375, American Chemical Society, Washington, D.C., 1988.
  • regenerator temperature control is possible by adjusting the CO/C02 ratio produced in the regenerator. Burning coke partially to CO produces less heat than complete combustion to C02. However, in some cases, this control is insufficient, and also leads to increased CO emissions, which can be a problem unless a CO boiler is present.
  • U.S. Patent No. 4,353,812 discloses cooling catalyst from a regenerator by passing it through the shell side of a heat-exchanger with a cooling medium through the tube side- This and similar approaches remove heat from the regenerator, but will not prevent poorly, or even well, stripped catalyst from experiencing very high surface or localized temperatures in the regenerator.
  • Recent catalyst patents include U.S. 4,300,997 and 4,350,615, both directed to the use of Pd-Ru CO-combustion promoter.
  • the bi-metallic CO combustion promoter is reported to do an adequate job of converting CO to C02, while minimizing the formation of
  • U.S. 4,309,309 teaches the addition of a vaporizable fuel to the upper portion of a FCC regenerator to minimize NO emissions. Oxides of nitrogen formed in the lower portion of the regenerator are reduced in the reducing atmosphere generated by burning fuel in the upper portion of the regenerator.
  • the present invention resides in a fluidized catalytic cracking process wherein a heavy hydrocarbon feed comprising hydrocarbons having a boiling point above about 343°C (650°F) is catalytically cracked to lighter products
  • a heavy hydrocarbon feed comprising hydrocarbons having a boiling point above about 343°C (650°F) is catalytically cracked to lighter products
  • catalytically cracking said feed in a riser reactor by mixing the feed in the base of the reactor with a source of hot regenerated catalytic cracking catalyst withdrawn from a catalyst regenerator, and cracking said feed in said riser reactor to produce catalytically cracked products and spent catalyst which are discharged from the top of the riser into a catalyst disengaging zone; separating cracked products from spent catalyst in said catalyst disengaging zone to produce a cracked product vapor phase which is recovered as a product and a spent catalyst phase which is discharged from said disengaging zone into a catalyst stripper contiguous with and beneath said disengaging zone; stripping said spent catalyst with steam
  • Figure 1 is a schematic view of a conventional fluidized catalytic cracking unit
  • Figure 2 is a schematic view of a preferred embodiment of the invention, showing a stripper heated with catalyst from a regenerator cyclone,
  • Figure 3 is a schematic view of a multi-stage hot stripper of the invention, with a fast fluidized bed coke combustor.added to the regenerator,
  • Figure 4 is a schematic view of a multi-stage hot stripper of the invention, heated with catalyst from a regenerator cyclone, with a fast fluidized bed coke combustor, and
  • Figure 5 is a schematic view of a multi-stage hot stripper of the invention, with a preferred method of indirectly heat exchanging the catalyst in the stripper, and removing stripper vapors.
  • Figure 1 is a simplified schematic view of an FCC unit of the prior art, similar to the Kellogg Ultra Orthoflow converter Model F shown as Fig. 17 of Fluid Catalytic Cracking Report, in the January 8, 1990 edition of Oil & Gas Journal.
  • a heavy feed such as a vacuum gas oil is added to the base of the riser reactor 6 via feed injection nozzles 2.
  • the cracking reaction is completed in the riser reactor and spent catalyst and cracked products are discharged by way of 90° elbow 10 to riser cyclones 12.
  • the cyclones 12 separate most of the spent catalyst from cracked product, with the latter being discharged into disengager 14, and eventually removed via upper cyclones 16 and conduit 18 to a fractionator (not shown) .
  • Spent catalyst is discharged from a dipleg of riser cyclones 12 down into catalyst stripper 8, where one, or preferably 2 or more, stages of steam stripping occur, with stripping steam admitted by means not shown in Figure 1.
  • the stripped hydrocarbons, and stripping steam pass into disengager 14 and are removed with cracked products after passage through upper cyclones 16.
  • Stripped catalyst is discharged down via spent catalyst standpipe 26 into catalyst regenerator 24, with the flow of catalyst is controlled by a spent catalyst plug valve 36.
  • Catalyst is regenerated in regenerator 24 by contact with air, added via air lines and an air grid distributor (not shown) .
  • a catalyst cooler 28 is provided so that heat may be removed from the regenerator, if desired.
  • Regenerated catalyst is withdrawn from the regenerator via regenerated catalyst plug valve assembly 30 and fed via lateral 32 into the base of the riser reactor 6 to contact and crack fresh feed injected via injectors 2, as previously discussed. Flue gas, and some entrained catalyst, are discharged into a dilute phase region in the upper portion of regenerator 24. Entrained catalyst is separated from flue gas in multiple stages of cyclones 4, and discharged via outlets 8 into plenum 20 for discharge to a flare via line 22.
  • a multi-stage hot stripper 108 is added to the lower end of the existing catalyst stripper 8 so as to extend within the regenerator, and preferably into the regenerator bubbling dense bed, so that the spent catalyst in the stripper 108 is heated by indirect heat exchange.
  • the efficiency of the indirect heat exchange between the regenerator and the hot stripper 108 can be increased by modifying the internal or external surface of hot stripper vessel with fins, dimples, ridges or the like.
  • catalyst from a regenerator cyclone 118 discharged via cyclone dipleg 120 heats the catalyst from the primary stripping zone 8 by direct contact heat exchange.
  • Stripping steam, or other stripping medium is added by conventional steam addition means 122 and 126.
  • the stripped hydrocarbons and stripping gas are removed either via side withdrawal means 124, preferably at multiple elevations within the stripper, or via one or more central funnels 130, defining multiple annular openings 132 connected through a central vapor outlet 134 to the vapor space above the existing stripper 8.
  • the embodiment shown in Figure 2 has several important advantages.
  • a significant amount of heating of the hot stripper is effected by indirect heat exchange, because the hot stripper is within the regenerator, and preferably is at least partly immersed in the regenerator bubbling dense bed. This is beneficial in that catalyst traffic in the stripper and in the regenerator can be reduced. This reduces the size and cost of equipment and slightly reduces catalyst fines or dust lost from the regenerator.
  • the hot stripper operation is improved, because the concentration of spent catalyst is higher.
  • the Figure 2 design also allows all stripped product from all stages of stripping to be withdrawn together, and sent to product fractionatio ⁇ .
  • this design permits hot regenerated catalyst to be added to the hot stripper safely and in a manner which is very tolerant of failure of the hot catalyst recycle line. The latter is an important consideration for any unit which is expected to last for years in the erosive environment of a regenerator.
  • Figure 3 shows a preferred embodiment of the invention, with a hot stripper and a fast fluidized bed region created in the bubbling bed in the base of the regenerator.
  • the Figure 3 embodiment employs external control of hot regenerated catalyst flow to the hot stripper.
  • the stripper 8 discharges stripped catalyst into hot stripper 208 which is at least partially immersed in a high efficiency regenerator, comprising coke combustor 250 and dilute phase transport riser 252.
  • a high efficiency regenerator comprising coke combustor 250 and dilute phase transport riser 252.
  • the air admission rate, and the cross-sectional area available for flow, and catalyst addition and catalyst recycle, if any, are adjusted to maintain much or all of the bed in a "fast fluidized condition", characterized by intense agitation, relatively small bubbles, and rapid coke combustion.
  • the vapor velocity should exceed 1 m/second (3.5 feet/second), and preferably should be 1.2-4.6 m/second (4-15 feet/second), and most preferably 1.2-3 m/second (4-10 feet/second).
  • the densities and superficial vapor velocities discussed herein presume that the unit operates at a pressure where the vast majority of FCC units operate, namely 270-380 kPa (25-40 psig) . Changes in pressure change the superficial vapor velocity needed to maintain a fast fluidized bed or a bubbling dense bed. However, it is easy to calculate the superficial vapor velocity needed to support a given type of fluidization, and the bed density expected at those conditions. In general, an increase in pressure will decrease the superficial vapor velocity needed to achieve a fast fluidized bed.
  • the arrangement shown in Figure 3 provides a significant amount of indirect, counter-current heat exchange of spent catalyst with regenerating catalyst.
  • the first stage of catalyst regeneration takes place in coke combustor 250, which is operates as a fast fluidized bed.
  • Partially regenerated catalyst, and flue gas are discharged from the fast fluidized bed region and pass as a dilute phase up transport riser 252, which encompasses the lower portion of hot stripper 208.
  • Partially or totally regenerated catalyst and flue gas are discharged from the transport riser via cap or deflector 260, which directs catalyst and flue gas down to the bubbling dense bed.
  • the catalyst tends to continue in a straight line to the bubbling dense bed, while the gas flows sideways, so a measure of catalyst separation is achieved.
  • Catalyst discharged from cap 260 is collected as a bubbling dense bed 265. Additional regeneration gas may be added to dense bed 265, for fluffing, and preferably to obtain an additional stage of regeneration.
  • the base of the stripper 208 is well below the level of bubbling dense bed 265 it is possible to transfer catalyst from bed 265 into the hot stripper via line 220 and slide valve 222. Because of the extent of immersion of the hot stripper in the coke combustor and transport riser, and because of the intense fluidization which occurs in both of these regions, the rate of heat transfer into the hot stripper via indirect heat exchange can be very high, so relatively low rates of catalyst recycle via line 220 may be needed. This design will work well even when no catalyst is recycled, provided that conductive, rather than insulating, refractory materials are used to line the inside and outside of hot stripper 208.
  • a significant amount of combustion air is added to bed 265 both to maintain fluidization and achieve a significant amount of coke combustion.
  • bed 265 is a typical fluidized bubbling bed, characterized by relatively large stagnant regions, and large bubbles of combustion air which bypass the bed, it is an excellent place to achieve some additional coke combustion.
  • One of the most significant benefits of coke combustion in bubbling bed 265 is the relatively drier atmosphere. There is a lower steam partial pressure in the dense bed 265 than in a conventional dense bed regenerator, such as that shown in Fig. 1.
  • Figure 4 shows another preferred embodiment with a hot stripper and a fast fluidized bed region in the bubbling bed in the base of the regenerator.
  • the Figure 4 embodiment employs internal flow of hot regenerated catalyst to the hot stripper, as opposed to the external flow arrangement of Figure 3.
  • Conventional stripper 8 discharges stripped catalyst into hot stripper 308, which again extends into the regenerator.
  • Catalyst for direct contact heat exchange of spent catalyst in the hot stripper 308 is obtained from a cyclone, preferably a primary cyclone 318, which discharges recovered, hot, regenerated catalyst via dipleg 320 into seal pot 324.
  • This pot is designed to allow a predetermined amount of hot regenerated catalyst to flow via line 328 into the hot stripper308, while allowing any excess material to simply overflow seal pot 324.
  • This embodiment shows several preferred methods of controlling the amount of hot regenerated catalyst that is allowed to enter hot stripper 308.
  • a plurality of steam lines, 330 and 332 are at different elevations in the hot stripper, under or near the outlet of line 328.
  • Fig. 5 shows a multi-stage hot stripper 508, which is intended to be mounted below a conventional steam stripper.
  • the hot stripper 508 is at least partially, and preferably totally,, immersed in the dilute phase and perhaps even the dense phase region of the bubbling bed regenerator.
  • the stripper 508 includes a plurality of tubes 510, with inlets 512 at the top for spent catalyst, and for the discharge of stripper vapor, and outlets at the base of the tubes for discharge of stripped catalyst into the regenerator.
  • Stripping gas preferably steam, is admitted to a lower portion of each tube 510 to strip and aerate the spent catalyst in the tubes. The aeration should be sufficient to promote vigorous stripping, but not sufficient to blow more than minor amounts of stripped catalyst out the tops of the tubes 512.
  • channel 518 above the tubes 510.
  • This channel isolates the tubes from the rush of catalyst discharged by the primary stripper, and provides for a more orderly addition of spent catalyst to the stripping tubes, and for more orderly withdrawel of stripper vapor.
  • channel 518 may be a generally ring shaped baffle above the tubes.
  • the hot stripper 508 should be sealed from the regenerator, which is accomplished by providing seal plate 542 around tubes 510.
  • the tubes 510 should be made of stainless steel, or some other equivalent material which is both strong and conductive.
  • the tubes are part of a tube and shell heat exchanger and the spent catalyst is passed through the shell side of the heat exchanger, while the tube side is open to the dilute phase region of the regenerator.
  • indirect heat transfer between the regenerator and the hot stripper is effected through heat pipes containing a working fluid, such as sodium, which is vaporised in the regenerator and condensed in the stripper.
  • a working fluid such as sodium
  • Any conventional FCC feed can be used.
  • the process of the present invention is especially useful for processing difficult charge stocks, those with high levels of CCR material, exceeding 2, 3, 5 and even 10 wt % CCR.
  • the feeds may range from the typical, such as ' petroleum distillates or residual stocks, either virgin or partially refined, to the atypical, such as coal oils and shale oils.
  • the feed frequently will contain recycled hydrocarbons, such as light and heavy cycle oils which have already been subjected to cracking.
  • Preferred feeds are gas oils, vacuum gas oils, atmospheric resids, and vacuum resids, and mixtures thereof.
  • the present invention is very useful with heavy feeds having a metals contamination problem. With these feeds, the possibility of reduced burning load in the regenerator, and even more importantly, the possibility of a dryer regenerator, because of reduced hydrogen content of coke, will be a significant benefit.
  • the catalyst can be 100% amorphous, but preferably includes some zeolite in a porous refractory matrix such as silica-alumina, clay, or the like.
  • the zeolite is usually 5-40 wt.% of the catalyst, with the rest being matrix.
  • Conventional zeolites include X and Y zeolites, with ultra stable, or relatively high silica Y zeolites being preferred. Dealuminized Y (DEAL Y) and ultrahydrophobic Y (UHP Y) zeolites may be used.
  • the zeolites may be stabilized with Rare Earths, e.g., 0.1 to 10 Wt % RE.
  • Relatively high silica zeolite containing catalysts are preferred for use in the present invention. They withstand the high temperatures usually associated with complete combustion of CO to C02 within the FCC regenerator.
  • the catalyst inventory may also contain one or more additives, either present as separate additive particles, or mixed in with each particle of the cracking catalyst.
  • Additives can be added to enhance octane (shape selective zeolites, i.e., those having a Constraint Index of 1-12, preferably ZSM-5) , adsorb SOX (alumina) , remove Ni and V (Mg and Ca oxides) .
  • Typical riser cracking reaction conditions include catalyst/oil ratios of 0.5:1 to 15:1 and preferably 3:1 to 8:1, and a catalyst contact time of 0.1 to 50 seconds, and preferably 0.5 to 5 seconds, and most preferably about 0.75 to 2 seconds, and riser top temperatures of 480 to 565°C (900 to 1050°F).
  • Typical hot stripper operating conditions include temperatures which are at least 11°C (20°F) above the temperature in the conventional stripping zone, preferably at least 28°C (50°F) above the temperature in the conventional stripper, and most preferably temperatures in the hot stripper are at least 55 ⁇ C (100°F) hotter.
  • a stripping gas or medium preferably steam, is used for stripping.
  • the desired heating of spent catalyst in the hot stripper can be achieved by indirect heat exchange with or without direct contact heat exchange (recycle of hot regenerated catalyst into the hot stripper) .
  • Each mode of heating will be briefly reviewed.
  • regenerated catalyst When direct contact heat exchange is practiced, it usually will be preferred to recycle an amount of regenerated catalyst equal to 10 to 500 % of the spent catalyst, and preferably from 15 to 150% of the spent catalyst.
  • the heat balance equations are fairly simple, because the heat capacity of spent and regenerated catalyst is about the same.
  • a 50/50 mix (100 % addition of regenerated to spent) of 540°C (1000 ⁇ F) spent and 730°C (1350 ⁇ F) regenerated catalyst will give a mix temperature of about 635°C (1175°F) .
  • a realistic overall heat transfer coefficient is about 450 J/m 2 s°C (80 Btu/ft 2 h ⁇ F) , provided that the tubes are immersed in, or are very near, a dense phase fluidized bed of catalyst. There is usually not enough heat present in most dilute phase regions to permit rapid heat transfer.
  • One exception is the amount of heat available in a dilute phase transport riser above a coke combustor. Although this stream is, strictly speaking, a dilute phase, it is a dilute phase charactised by a very high solids content, and a high velocity. Any heat exchange tube placed in a dilute phase transport riser will exhibit an even higher rate of heat transfer, well in excess of the heat transfer coefficient obtainable in a classical bubbling, dense phase fluidized bed.
  • CO combustion promoter in the regenerator or combustion zone is not essential for the practice of the present invention, however, it is preferred. These materials are well-known.
  • U.S. 4,072,600 and U.S. 4,235,754 disclose operation of an FCC regenerator with minute quantities of a CO combustion promoter. From 0.01 to 100 ppm Pt metal or enough other metal to give the same CO oxidation, may be used with good results. Very good results are obtained with as little as 0.1 to 10 wt. ppm platinum present on the catalyst in the unit.
  • the hot stripper temperature controls the amount of carbon removed from the catalyst in the hot stripper. Accordingly, the hot stripper controls the amount of carbon (and hydrogen and sulfur) remaining on the catalyst to the regenerator. This residual carbon level controls the temperature rise between the stripper and the regenerator.
  • the hot stripper also controls the hydrogen content of the spent catalyst sent to the regenerator as a function of residual carbon. Thus, the hot stripper controls the temperature and amount of hydrothermal deactivation of catalyst in the regenerator.
  • the present invention strips catalyst at a temperature higher than the riser exit temperature to separate hydrogen, as molecular hydrogen or hydrocarbons from the coke which adheres to catalyst. This minimizes catalyst steaming, or hydrothermal degradation, which typically occurs when hydrogen reacts with oxygen in the FCC regenerator to form water.
  • the high temperature stripper also removes much of the sulfur from the coked catalyst as hydrogen sulfide and mercaptans, which are easy to scrub. In contrast, burning from coked catalyst in a regenerator produces SO in the regenerator flue gas. The high temperature stripping recovers additional valuable hydrocarbon products to prevent burning these hydrocarbons in the regenerator.
  • hot stripping Another benefit of hot stripping is reduced solids emissions from the regenerator.
  • solids content of flue gas is roughly proportional to the solids traffic in the dilute phase of the regenerator. Reducing the solids traffic can reduce the amount of dust and fines that escape the regenerator cyclones.
  • catalyst is recycled from a bubbling dense bed to the coke combustor, and this catalyst recycle significantly increases catalyst traffic in the regenerator.
  • the hot stripper of the present invention allows heat to be transferred from the regenerator to the catalyst from the stripper, without recycling catalyst from the regenerator, or at least with a reduced amount of catalyst recirculation. This reduced catalyst load to the coke combustor reduces the amount of catalyst discharged from the coke combustor, and reduces the amount of catalyst traffic in the dilute phase region above the bubbling dense bed downstream of the coke combustor.

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  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Engineering & Computer Science (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

Procédé permettant d'effectuer la rectification à chaud d'un catalyseur épuisé de craquage catalytique fluidisé, dans un régénérateur (24) à lit barbotant sur lequel est montée une colonne de rectification (8) et dans lequel se situe une colonne d'alimentation (208) du catalyseur rectifié. On effectue la rectification du catalyseur chaud par échange thermique indirect entre le catalyseur régénéré chaud situé dans le régénérateur et le catalyseur épuisé situé dans la colonne de rectification. On réalise cet échange thermique indirect en plongeant la colonne de rectification chaude dans le lit barbotant du régénérateur ou dans un brûleur de coke (250) associé au régénérateur, ou bien en utilisant des tubes de chauffe contenant un fluide de travail qui est vaporisé et condensé dans le régénérateur dans la colonne de rectification chaude. Le catalyseur régénéré peut également être recyclé (220) depuis le régénérateur vers la colonne de rectification chaude pour effectuer le chauffage par contact direct du catalyseur épuisé.
PCT/US1991/004499 1991-06-25 1991-06-25 Procede de rectification et de regeneration d'un catalyseur de craquage catalytique fluidise WO1993000674A1 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
PCT/US1991/004499 WO1993000674A1 (fr) 1991-06-25 1991-06-25 Procede de rectification et de regeneration d'un catalyseur de craquage catalytique fluidise
AU80916/91A AU8091691A (en) 1991-06-25 1991-06-25 A process for stripping and regenerating fluidized catalytic cracking catalyst
CA002112133A CA2112133A1 (fr) 1991-06-25 1991-06-25 Procede d'extraction des fractions legeres et de regeneration d'un catalyseur de craquage catalytique par barbotage

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
PCT/US1991/004499 WO1993000674A1 (fr) 1991-06-25 1991-06-25 Procede de rectification et de regeneration d'un catalyseur de craquage catalytique fluidise
AU80916/91A AU8091691A (en) 1991-06-25 1991-06-25 A process for stripping and regenerating fluidized catalytic cracking catalyst
CA002112133A CA2112133A1 (fr) 1991-06-25 1991-06-25 Procede d'extraction des fractions legeres et de regeneration d'un catalyseur de craquage catalytique par barbotage

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Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP1046695A2 (fr) 1999-04-23 2000-10-25 China Petrochemical Corporation Réacteur à colonne montante pour la conversion catalytique fluidisée
EP1046696A3 (fr) * 1999-04-23 2001-01-03 China Petrochemical Corporation Procédé de conversion catalytique pour la production d'essence enrichie en isobutane et en isoparaffines
EP1408100A1 (fr) 2002-10-10 2004-04-14 Kellog Brown & Root, Inc. Régénératuer de catalysateur avec un conduit central
US8383052B2 (en) 2010-04-16 2013-02-26 Kellogg Brown & Root Llc System for a heat balanced FCC forlight hydrocarbon feeds
CN117282472A (zh) * 2023-11-27 2023-12-26 中科益天环境工程(北京)有限公司 一种催化裂化催化剂老化方法及设备

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US4385985A (en) * 1981-04-14 1983-05-31 Mobil Oil Corporation FCC Reactor with a downflow reactor riser
US4574044A (en) * 1982-03-31 1986-03-04 Chevron Research Company Method for spent catalyst treating for fluidized catalytic cracking systems
US4789458A (en) * 1984-12-27 1988-12-06 Mobil Oil Corporation Fluid catalytic cracking with plurality of catalyst stripping zones

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4385985A (en) * 1981-04-14 1983-05-31 Mobil Oil Corporation FCC Reactor with a downflow reactor riser
US4574044A (en) * 1982-03-31 1986-03-04 Chevron Research Company Method for spent catalyst treating for fluidized catalytic cracking systems
US4789458A (en) * 1984-12-27 1988-12-06 Mobil Oil Corporation Fluid catalytic cracking with plurality of catalyst stripping zones

Cited By (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP1046695A2 (fr) 1999-04-23 2000-10-25 China Petrochemical Corporation Réacteur à colonne montante pour la conversion catalytique fluidisée
EP1046695A3 (fr) * 1999-04-23 2001-01-03 China Petrochemical Corporation Réacteur à colonne montante pour la conversion catalytique fluidisée
EP1046696A3 (fr) * 1999-04-23 2001-01-03 China Petrochemical Corporation Procédé de conversion catalytique pour la production d'essence enrichie en isobutane et en isoparaffines
US7678342B1 (en) 1999-04-23 2010-03-16 China Petrochemical Corporation Riser reactor for fluidized catalytic conversion
EP1408100A1 (fr) 2002-10-10 2004-04-14 Kellog Brown & Root, Inc. Régénératuer de catalysateur avec un conduit central
US7153479B2 (en) 2002-10-10 2006-12-26 Kellogg Brown & Root Llc Catalyst regenerator with a centerwell
RU2326930C2 (ru) * 2002-10-10 2008-06-20 Келлог Браун Энд Рут, Инк. Регенератор катализатора с центральным сборником
US7435331B2 (en) 2002-10-10 2008-10-14 Kellogg Brown & Root Llc Catalyst regenerator with a centerwell
US8383052B2 (en) 2010-04-16 2013-02-26 Kellogg Brown & Root Llc System for a heat balanced FCC forlight hydrocarbon feeds
CN117282472A (zh) * 2023-11-27 2023-12-26 中科益天环境工程(北京)有限公司 一种催化裂化催化剂老化方法及设备
CN117282472B (zh) * 2023-11-27 2024-02-09 中科益天环境工程(北京)有限公司 一种催化裂化催化剂老化方法及设备

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