[go: up one dir, main page]

WO1990009842A1 - Craquage catalytique d'huile lourde - Google Patents

Craquage catalytique d'huile lourde Download PDF

Info

Publication number
WO1990009842A1
WO1990009842A1 PCT/US1989/001012 US8901012W WO9009842A1 WO 1990009842 A1 WO1990009842 A1 WO 1990009842A1 US 8901012 W US8901012 W US 8901012W WO 9009842 A1 WO9009842 A1 WO 9009842A1
Authority
WO
WIPO (PCT)
Prior art keywords
catalyst
temperature
stripping
riser
regenerator
Prior art date
Application number
PCT/US1989/001012
Other languages
English (en)
Inventor
Hartley Owen
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 JP1503373A priority Critical patent/JPH03505594A/ja
Publication of WO1990009842A1 publication Critical patent/WO1990009842A1/fr

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
    • 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
    • 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
    • C10G11/187—Controlling or regulating

Definitions

  • This invention is concerned with a fluidized catalytic cracking process wherein coked deactivated catalyst is subject to high temperature stripping to control the carbon level on spent catalyst. More particularly, the concept employs a high temperature stripper to control the carbon level on the spent catalyst, followed by catalyst cooling to control the temperature of the catalyst to regeneration.
  • catalyst passing from a fluid catalytic cracking stripper to a fluid catalytic cracking regenerator contains hydrogen-containing components, such as coke, adhering thereto. This causes hydrothermal degradation when the hydrogen reacts with oxygen in the regenerator to form water.
  • regenerator temperature control is desirable, because regenerator temperatures above 871°C (1600°F) can deactivate fluid cracking catalyst.
  • the temperature is controlled by adjusting the CO/CO- ratio produced in the regenerator. This control works on the principle that production of CO produces less heat than production of C0-. However, in some cases, this control is insufficient.
  • regenerator temperature It would be desirable to separate hydrogen from catalyst to eliminate hydrothermal degradation. It would be further advantageous to remove sulfur-containing compounds prior to regeneration to prevent S0 ⁇ from passing into the regenerator flue gas. Also, it would be advantageous to better control regenerator temperature.
  • U. S. Patent No. 4,353,812 to Lomas et al 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. The cooled catalyst is recycled to the regeneration zone.
  • This 'process is disadvantageous, in that it does not control the temperature of catalyst from the reactor to the regenerator.
  • the prior art also includes fluid catalytic cracking processes which utilize dense or dilute phase regenerated fluid catalyst heat removal zones or heat-exchangers that are remote from, and external to, the regenerator vessel to cool hot regenerated catalyst for return to the regenerator. Fxamples of such processes are found in U. S. Patent Nos.
  • the present invention comprises a fluid catalytic cracking process and apparatus which employs a high temperature stripper, followed by cooling of the stripped catalyst to control a regenerator inlet temperature.
  • the present invention provides a process for controlling the fluid catalytic cracking of a feedstock containing hydrocarbons, comprising the steps of: passing a mixture comprising catalyst and the feedstock through a riser conversion zone under fluid catalytic cracking conditions to crack the feedstock; passing the mixture, having a riser exit temperature, from the riser into a fluid catalytic cracking reactor vessel; separating a portion of catalyst from the mixture, with the remainder of the mixture forming a reactor vessel gaseous stream; heating the separated catalyst portion by combining the separated catalyst portion with a portion of regenerated catalyst from a fluid catalytic cracking regenerator vessel to form combined catalyst; stripping the combined catalyst, by contact with a stripping gas stream, at a stripping temperature between 55°C (100°F) above the riser exit temperature and 816°C (1500°F), the regenerated
  • the riser exit temperature is defined as the temperature of the catalyst-hydrocarbon mixture exiting from the riser.
  • the riser exit temperature may be at any suitable temperature. However, a riser exit temperature of 482°-593°C (900° to 1100°F) is preferred, and 538°-566°C (1000° to 1050°F) is most preferred.
  • the present invention provides a process for controlling the fluid catalytic cracking of a feedstock containing hydrocarbons and sulfur-containing compounds, comprising the steps of: passing a mixture comprising catalyst and the feedstock through a riser conversion zone at fluid catalytic cracking conditions to crack the feedstock; passing the mixture, having a riser exit temperature between 538°-566°C (1000° and 1050°F), from the riser conversion zone to a closed cyclone system located within a fluid catalytic cracking reactor vessel; separating a portion of catalyst from the mixture in the closed cyclone system, with the remainder of the mixture forming a reactor vessel gaseous stream;heating the separated catalyst portion by combining the separated catalyst portion in the reactor vessel, with a portion of regenerated catalyst from a fluid catalytic cracking regenerator vessel to form combined catalyst; stripping the combined catalyst, by contact with a stripping gas stream in the reactor vessel, under stripping conditions comprising a stripping temperature between 83°C (150°F) above the riser exit temperature and
  • the present invention provides an apparatus for controlling the fluid catalytic cracking of a feedstock comprising hydrocarbons, comprising: means defining a riser conversion zone through which a mixture comprising catalyst and the feedstock passes at fluid catalytic cracking conditions to crack the feedstock; a fluid catalytic cracking reactor vessel; means for passing the mixture from the riser into the fluid catalytic cracking reactor vessel, the mixture having a riser exit temperature as it passes into the reactor vessel; means for separating a portion of catalyst from the mixture, with the remainder of the mixture forming a reactor vessel gaseous stream; means for heating the separated catalyst portion, comprising means for combining the separated catalyst portion with a portion of regenerated catalyst to form combined catalyst; means for stripping the combined catalyst by contact with a stripping gas stream to form a stripped catalyst stream; a fluid catalytic cracking regenerator vessel for producing the portion of regenerated catalyst; and a heat-exchanger for cooling the stripped catalyst stream, the heat-exchanger being located outside the reactor vessel, the
  • the present invention provides an apparatus for controlling the fluid catalytic cracking of a feedstock comprising hydrocarbons and sulfur-containing compounds, comprising: means defining a riser conversion zone through which a mixture comprising catalyst and the feedstock passes at fluid catalytic cracking conditions to crack the feedstock; a fluid catalytic cracking reactor vessel; means for passing the mixture from the riser conversion zone to a closed cyclone system located within the fluid catalytic cracking reactor vessel, the mixture having a riser exit temperature between 538°-566°C (1000° and 1050°F) as it passes from the riser to the closed cyclone system, the closed cyclone system including means for separating a portion of catalyst from the mixture and forming a reactor vessel gaseous stream from the remainder of the mixture; means for heating the separated portion of catalyst, comprising means for combining a portion of regenerated catalyst with the separated catalyst portion to form a combined catalyst in the reactor vessel; means for stripping the combined catalyst by contact with a stripping gas in the reactor vessel
  • 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, to eliminate hydrothermal degradation, which typically occurs when hydrogen reacts with oxygen in a fluid catalytic cracking regenerator to form water.
  • the high temperature stripper also removes sulfur from coked catalyst as hydrogen sulfide and ercaptans, which are easy to scrub.
  • removing sulfur from coked catalyst in a regenerator produces S0 ⁇ , which passes into the regenerator flue gas and is more difficult to scrub.
  • the high temperature stripper removes additional valuable hydrocarbon products to prevent burning these hydrocarbons in the regenerator.
  • An additional advantage of the high temperature stripper is that it quickly separates hydrocarbons from catalyst. If catalyst contacts hydrocarbons for too long a time at a temperature greater than or equal to 538°C (1000°F), then diolefins are produced which are undesirable for downstream processing, such as alkylation.
  • the present invention allows a precisely controlled, short contact time at 538°C (1000°F) or greater to produce premium, unleaded gasoline with high selectivity.
  • the heat-exchanger controls regenerator temperature. This allows the hot stripper to run at a desired temperature to control sulfur and hydrogen without interfering with a desired regenerator temperature. It is desired to run the regenerator at least 55°C (100°F) hotter than the hot stripper. However, the regenerator temperature should be kept below 871°C (1600°F) to prevent deactivation of the catalyst.
  • the drawing is a schematic representation of a high temperature stripper and catalyst cooler of the present invention.
  • the figure illustrates a fluid catalytic cracking system of the present invention.
  • a hydrocarbon feed passes from a hydrocarbon feeder 1 to the lower end ,of a riser conversion zone d .
  • Regenerated catalyst from a standpipe 102, having a control valve 104 is combined with the hydrocarbon feed in the riser 4, such that a hydrocarbon-catalyst mixture rises in an ascending dispersed stream and passes through a riser effluent conduit 6 into a first reactor cyclone 8.
  • the riser exit temperature defined/ as the temperature at which the mixture passes from the riser 4 to conduit 6, ranges between 482° and 593°C (900° and 1100°F), and preferably between 538° and 566°C (1000° and 1050°F).
  • the riser exit temperature is controlled by monitoring and adjusting the rates and temperatures of hydrocarbons and regenerated catalyst into the riser 4.
  • Riser effluent conduit 6 is attached at one end to the riser 4 and at its other end to the cyclone 8.
  • the first reactor cyclone separates a portion of catalyst from the catalyst-hydrocarbon mixture and passes this catalyst down a first reactor cyclone dipleg 12 to a stripping zone 30 located therebelow.
  • the remaining gas and catalyst pass from the first reactor cyclone 8 through a gas effluent conduit 10.
  • the conduit 10 is provided with a connector 24 to allow for thermal expansion.
  • the catalyst passes through the conduit 10, then through a second reactor cyclone inlet conduit 22, and into a second reactor cyclone 14.
  • the second cyclone 14 separates the stream to form a catalyst stream, which passes through a second reactor cyclone dipleg 18 to the stripping zone 30 located therebelow, and an overhead stream .
  • the second cyclone overhead stream which contains the remaining gas and catalyst, passes through a second cyclone gaseous effluent conduit 16 to a reactor overhead port 20. Gases from the atmosphere of the reactor vessel 2 may pass through a reactor overhead conduit 22 into the reactor overhead port 20. The gases which exit the reactor 2 through the second cyclone gaseous effluent conduit 16 and the reactor overhead conduit 22 are combined and exit through the reactor overhead port 20. It will be apparent to those skilled in the art that although only one series connection of cyclones 8, 14 is shown in the embodiment, more than one series connection and/or more or less than two consecutive cyclones in series connection could be employed.
  • the mixture of catalyst and hydrocarbons passes through the first reactor cyclone overhead conduit 10 and the second reactor cyclone inlet conduit 22 without entering the reactor vessel 2 atmosphere.
  • the connector 24 may provide an annular port to admit stripping gas from the reactor vessel 2 into the conduit 10 to aid in separating catalyst from hydrocarbons adhering thereto.
  • the closed cyclone system and annular port is described more fully in U. S. Patent No. 4,502,947 to Haddad et al.
  • the separated catalyst from cyclones 8, 14 pass through respective diplegs 12, 18 and are discharged therefrom after a suitable pressure is generated within the diplegs by the buildup of the catalyst.
  • the catalyst falls from the diplegs into a bed of catalyst 31 located in the stripping zone 30.
  • the first dipleg 12 is sealed by being extended into the catalyst bed 31.
  • the second dipleg 18 is sealed by a trickle valve 19.
  • the separated catalyst is contacted and combined x- ⁇ th hot regenerated catalyst from the regenerator 80 in the stripping zone 30.
  • the regenerated catalyst has a temperature in the range between 55°C (100°F) above that of the stripping zone 30 and 871°C (1600°F) to heat the separated catalyst in bed 31.
  • the regenerated catalyst passes from the regenerator 80 to the reactor vessel 2 through a transfer line 106 attached at one end to the regenerator vessel 80 and at another end to the reactor vessel 2.
  • the transfer line 106 is provided with a slide valve 108.
  • Combining the separated catalyst with the regenerated catalyst promotes the stripping at a temperature in the range between 55°C (100°F) above the riser exit temperature and 816°C (1500°F).
  • the catalyst stripping zone operates at a temperature between 83°C (150°F) above the riser exit temperature and 760°C (1400°F).
  • the catalyst 31 in the stripping zone 30 is contacted at high temperature, discussed above, with a stripping gas, such as steam, flowing countercurrently to the direction of flow of the catalyst.
  • the stripping gas is introduced into the lower portion of the stripping zone 30 by one or more conduits 34 attached to a stripping gas header 36.
  • the catalyst residence time in the stripping zone 30 ranges from 2.5 to minutes.
  • the vapor residence time in the catalyst stripping zone 30 ranges from 0.5 to 30 seconds, and preferably 0.5 to 5 seconds.
  • the stripping zone 30 removes coke, sulfur and hydrogen from the separated catalyst which has been combined with the regenerated catalyst.
  • the sulfur is removed as hydrogen sulfide and mercaptans.
  • the hydrogen is removed as molecular hydrogen, hydrocarbons, and hydrogen sulfide.
  • the stripping zone 30 is maintained at temperatures between 83°C (150°F) above the riser exit temperature, which are sufficient to reduce coke load to the regenerator by at least 50%, remove ⁇ 0-80 °f the hydrogen as molecular hydrogen, light hydrocarbons and other hydrogen-containing compounds, and remove 45 to 55% of the sulfur as hydrogen sulfide and mercaptans, as well as a portion of nitrogen as ammonia and cyanides.
  • the catalyst stripping zone 30 may also be provided with trays (baffles) 32.
  • the trays may be disc- and doughnut-shaped and may be perforated or unperforated.
  • Stripped catalyst passes through a stripped catalyst effluent conduit 38 to a catalyst cooler 40.
  • the catalyst cooler 40 is a heat-exchanger which cools the stripped catalyst from the reactor vessel 2 to a temperature sufficient to maintain the regenerator vessel 80 at a temperature between 55°C (100°F) above the temperature of the stripping zone 30 and 871°C (1600°F).
  • the catalyst cooler 40 cools the stripped catalyst stream to a temperature sufficient to control the regenerator vessel 80 at a temperature to between 83°C (150°F) above the temperature of the stripping zone 30 and 871°C (1600°F).
  • the stripped catalyst stream is cooled between 28° and 83°C (50° and 150°F) below the stripping zone temperature, so long as the cooled catalyst temperature is at least 593°C (1100°F).
  • the catalyst cooler 40 is preferably an indirect heat-exchanger located outside the reactor vessel 2.
  • a heat-exchange medium such as liquid water (boiler feed water)
  • the catalyst passes through the shell side 46 of the catalyst cooler 40.
  • the catalyst cooler 40 is attached to an effluent conduit 42 provided with a slide valve 44.
  • the cooled catalyst passes through the conduit 42 into a regenerator inlet conduit 60.
  • air and cooled catalyst combine and pass upwardly through an air catalyst disperser 74 into a fast fluid bed 62.
  • the fast fluid bed 62 is part of the regenerator vessel 80.
  • combustible materials such as coke which adheres to the cooled catalyst, are burned off the catalyst by contact with lift air.
  • Air passes through an air supply line 66 through a control valve 68 and an air transfer line 68 to the regenerator inlet conduit 60.
  • the temperature of the cooled catalyst from the conduit 42 is less than 593°C (1100°F)
  • a portion of hot regenerated catalyst from the standpipe 102 passes through a conduit 101, provided with a control valve 103, into the fast fluid bed 62.
  • the fast fluid bed 62 contains a relatively dense catalyst bed 76.
  • the air fluidizes the catalyst in bed 76, and subsequently transports the catalyst continuously as a dilute phase through the regenerator riser 83.
  • the dilute phase passes upwardly through the riser 83, through a radial arm 84 attached to the riser 83, and then passes downwardly to a second relatively dense bed of catalyst 82 located within the regenerator vessel 80.
  • the major portion of catalyst passes downwardly through the radial arms 84, while the gases and remaining catalyst pass into the atmosphere of the regenerator vessel 80.
  • the gases and remaining catalyst then pass through an inlet conduit 89 and into the first regenerator cyclone 86.
  • the first cyclone 86 separates a portion of catalyst and passes it through a first dipleg 90, while remaining catalyst and gases pass through an overhead conduit 88 into a second regenerator cyclone 92.
  • the second cyclone 92 separates a portion of catalyst and passes the separated portion through a second dipleg 96 having a trickle valve 97, with the remaining gas and catalyst passing through a second overhead conduit 94 into a regenerator vessel plenum chamber 98.
  • a flue gas stream 110 exits from the regenerator plenum chamber 98 through a regenerator flue gas conduit 100.
  • the regenerated catalyst settles to form the bed 82, which is dense compared to the dilute catalyst passing through the riser 83.
  • the regenerated catalyst bed 82 is at a substantially higher temperature than the stripped catalyst from the stripping zone 30, due to the coke burning which occurs in the regenerator 80.
  • the catalyst in bed 82 is at least 55°C (100°F) hotter than the temperature of the stripping zone 30, preferably at least 83°C (150°F) hotter than the temperature of the stripping zone 30.
  • the regenerator temperature is, at most, 871°C (1600°F) to prevent deactivating the catalyst. Coke burning occurs in the regenerator inlet conduit 60, as well as the fast fluid bed 62 and riser 83.
  • air may also be passed from the air supply line 64 to an air transfer line 70, provided with a control valve 72, to an air header 78 located in the regenerator 80.
  • the regenerated catalyst then passes from the relatively dense bed 82 through the conduit 106 to the stripping zone 30 to provide heated catalyst for the stripping zone 30.
  • Any conventional fluid catalytic cracking catalyst can be used in the present invention.
  • Use of zeolite catalysts in an amorphous base is preferred.
  • Many suitable catalysts are discussed in U. S. Patent No. 3,926,778 to Owen et al.
  • Che example of a process which can be conducted in accordance with the present invention begins with a 343° to 593°C (650° to 1100°F) boiling point hydrocarbon feedstock which passes into a riser conversion zone 4, where it combines with hot regenerated catalyst at a temperature of about 815°C (1500°F) from a catalyst standpipe 102 to form a catalyst-hydrocarbon mixture.
  • the catalyst-hydrocarbon mixture passes upwardly through the riser conversion zone 4 and into a riser effluent conduit 6 at a riser exit temperature of about 538°C (100 °F).
  • the catalyst passes from the conduit 6 into the first reactor cyclone 8, where a portion of catalyst is separated from the mixture and drops through a dipleg 12 to a bed of catalyst 31 contained within a stripping zone 30 therebelow.
  • the stripping zone 30 operates at about 704°C
  • the remainder of the mixture passes upwardly through the first overhead conduit 10 into a second reactor cyclone 14.
  • the second cyclone 14 separates a portion of catalyst from the first cyclone overhead stream and passes the separated catalyst down the second dipleg 18.
  • the remaining solids and gases pass upwardly as a second cyclone overhead stream through conduit 16 into the reactor vessel overhead port 20.
  • the catalyst from diplegs 12, 18 combines with catalyst from regenerator 80, which passes through a conduit 106 and is stripped by contact with steam from a steam header 36.
  • the regenerated catalyst from the conduit 106 is at a temperature of about 815°C (1500°F) and provides heat to maintain the stripping zone 30 at about 704°C (1300°F).
  • the stripped catalyst passes through a conduit 38 into a catalyst cooler 40 at a temperature of about 704°C (130 °F).
  • the catalyst cooler 40 cools the 704°C (1300°F) catalyst to about 621°C (1150°F).
  • the cooling occurs by indirect heat-exchange of the hot stripped catalyst with boiler feed water, which passes through a conduit 50 to form steam which exits through a conduit 52.
  • the cooled catalyst at a temperature of about 621°C (1150°F), combines with lift air from a conduit 66 in a regenerator inlet conduit 60 to form an air-catalyst mixture.
  • the mixture passes upwardly through the conduit 60 into fast fluid bed 76.
  • the catalyst continues upwardly from fast fluid bed 76 through the regenerator riser 83 and into a regenerator vessel 80.
  • the catalyst is then separated from gases by the radial arm 84, as well as cyclones 86 and 92, and passes downwardly through the regenerator to form a relatively dense bed 82.
  • the coke adhering to the stripped catalyst burns in the conduit 60, the fast fluid bed 62, the riser 83, and the regenerator vessel 80.
  • the catalyst in bed 82 is heated to a temperature of about 815°C (1500°F). Catalyst bed 82 then supplies catalyst for the standpipe 102, which combines with the hydrocarbon feedstock. Bed 82 also provides catalyst for conduit 106 which passes to the stripping zone 30. Gaseous effluents pass through a first cyclone 86 and second cyclone 92 and leave the regenerator 80 as a flue gas stream 110 through a flue gas conduit 100.
  • the stripping zone as a high temperature (hot) stripper, at a temperature between 55°C (100°F) above a riser exit temperature and 816°C (1500°F), has the advantage that it separates hydrogen, as molecular hydrogen as well as hydrocarbons, from catalyst. Hydrogen removal eliminates hydrothermal degradation, which typically occurs when hydrogen reacts with oxygen in a fluid catalytic cracking regenerator to form water.
  • the hot stripper also removes sulfur from coked catalyst as hydrogen sulfide and mercaptans , which are easy to scrub . By removing sulfur from coked catalyst in the hot stripper, the hot stripper prevents formation of S0 ⁇ in the regenerator.
  • the hot stripper enhances removal of hydrocarbons from spent catalyst, and thus prevents burning of valuable hydrocarbons in the regenerator. Furthermore, the hot stripper quickly separates hydrocarbons from catalyst to avoid overcracking.
  • the hot stripper is maintained at a temperature between 83°C (150°F) above a riser exit temperature and 760°C (1400°F) to reduce coke load to the regenerator by at least 50%, and strip away 70 to 80% of the hydrogen as molecular hydrogen, light hydrocarbons and other hydrogen-containing compounds.
  • the hot stripper is also maintained within the desired temperature conditions to remove 45 to 55% of the sulfur as hydrogen sulfide and mercaptans, as well as a portion of nitrogen as ammonia and cyanides.
  • This concept advances the development of a heavy oil (residual oil) catalytic cracker and high temperature cracking unit for conventional gas oils.
  • the process combines the control of catalyst deactivation with controlled catalyst carbon-contamination level and control of temperature levels in the stripper and regenerator.
  • 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, sulfur) remaining on the catalyst to the regenerator. This residual carbon level controls the temperature rise between the reactor 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. This concept may be practiced in a multi-stage, multi-temperature stripper or a single stage stripper.
  • Bnploying a hot stripper, to remove carbon on the catalyst, rather than a regeneration stage reduces air pollution, and allows all of the carbon made in the reaction to be burned to CO-, if desired.
  • the stripped catalyst is cooled (as a function of its carbon level) to a desired regenerator inlet temperature to control the degree of regeneration desired, in combination with the other variables of CO/CO2 ratio desired, the amount of carbon burn-off desired, the catalyst recirculation rate from the regenerator to the hot stripper, and the degree of desulfurization/ denitrification/decarbonization desired in the hot stripper.
  • Increasing CO/CC2 ratio decreases the heat generated in the regenerator, and accordingly decreases the regenerator temperature. Burning the coke, adhering to the catalyst in the regenerator, to CO removes the coke, as would burning coke to CO2, but burning to CO produces less heat than burning to CO-, .
  • regenerator temperature affects regenerator temperature, because greater carbon burn-off generates greater heat.
  • the catalyst recirculation rate from the regenerator to the hot stripper affects regenerator temperature, because increasing the amount of hot catalyst from the regenerator to the hot stripper increases hot stripper temperature. Accordingly, the increased hot stripper temperature removes increased amounts of coke so less coke need burn in the regenerator; thus, regenerator temperature can decrease.
  • the catalyst cooler controls regenerator temperature , thereby allowing the hot stripper to be run at temperatures between 55°C (100°F) above a riser exit temperature to 816°C (1500°F), which facilitate controlling sulfur and hydrogen, while allowing the regenerator to be run independently at temperatures at least 100°F hotter than the stripper, while preventing regenerator temperatures greater than 871°C (1600°F) which deactivate catalyst.
  • Use of the catalyst cooler on catalyst exiting the stripper also allows circulation of catalyst to the regenerator riser to increase catalyst density in the regenerator riser, while controlling the regenerator temperature. This reduces catalyst deactivation and provides additional control.

Landscapes

  • 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)
  • Catalysts (AREA)

Abstract

On décrit un procédé et un appareil de craquage catalytique fluide comprenant une colonne de rectification à haute température (une colonne de rectification à chaud) permettant de commander le niveau de carbone et le soufre sur le catalyseur épuisé, suivie par un refroidissement du catalyseur pour commander la température d'entrée de régénération. La colonne de rectification à haute température fonctionne à une température comprise entre 55°C (100°F) au-dessus de la température du mélange catalyseur-hydrocarbure sortant d'un tuyau montant et 816°C (1500°F). On règle la température d'entrée du régénérateur de façon à obtenir la température de régénération, la température de sortie du régénérateur et le degré de régénération voulus. Le régénérateur est maintenu à une température comprise entre 55°C (100°F) au-dessus de celle du catalyseur se trouvant dans la colonne de rectification à haute température et 871°C (1600°F). L'avantage de la présente invention est que l'hydrogène est séparé du catalyseur pour éliminer la dégradation hydrothermale et que le soufre est séparé du catalyseur de même que le sulfure d'hydrogène et les mercaptans que l'on peut aisément enlever. Le refroidisseur de catalyseur permet au régénérateur et à la colonne de rectification à haute température de fonctionner indépendamment l'un de l'autre à des températures respectives choisies.
PCT/US1989/001012 1985-12-30 1989-03-03 Craquage catalytique d'huile lourde WO1990009842A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
JP1503373A JPH03505594A (ja) 1989-03-03 1989-03-03 重質油接触クラッキング

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US81471485A 1985-12-30 1985-12-30
CA000593136A CA1320924C (fr) 1985-12-30 1989-03-08 Craquage catalytique de petrole lourd

Publications (1)

Publication Number Publication Date
WO1990009842A1 true WO1990009842A1 (fr) 1990-09-07

Family

ID=25672511

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US1989/001012 WO1990009842A1 (fr) 1985-12-30 1989-03-03 Craquage catalytique d'huile lourde

Country Status (3)

Country Link
EP (1) EP0415935B1 (fr)
CA (1) CA1320924C (fr)
WO (1) WO1990009842A1 (fr)

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0759808A4 (fr) * 1994-05-17 1997-11-12 Robert W Pfeiffer Processus utilisant des solides fluidifies et appareil permettant la mise en oeuvre de ces processus
CN110325278A (zh) * 2017-02-28 2019-10-11 环球油品有限责任公司 紧凑型两段再生器及其使用方法
WO2021019345A1 (fr) * 2019-07-31 2021-02-04 Sabic Global Technologies B.V. Réacteur à colonne montante et à plaques chauffantes

Citations (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2477042A (en) * 1943-03-10 1949-07-26 Standard Oil Dev Co Method of heat exchange in fluidized hydrocarbon conversion systems
US2518693A (en) * 1941-07-24 1950-08-15 Standard Oil Dev Co Process and apparatus for contacting finely divided solids and gases
US3392110A (en) * 1965-09-02 1968-07-09 Mobil Oil Corp Method for the utilization of highly active hydrocarbon conversion catalysts
US3821103A (en) * 1973-05-30 1974-06-28 Mobil Oil Corp Conversion of sulfur contaminated hydrocarbons
US4353812A (en) * 1981-06-15 1982-10-12 Uop Inc. Fluid catalyst regeneration process
US4419221A (en) * 1981-10-27 1983-12-06 Texaco Inc. Cracking with short contact time and high temperatures
US4435281A (en) * 1980-09-15 1984-03-06 Standard Oil Company (Indiana) Catalytic cracking with reduced emission of noxious gas
US4574044A (en) * 1982-03-31 1986-03-04 Chevron Research Company Method for spent catalyst treating for fluidized catalytic cracking systems
US4693809A (en) * 1985-12-05 1987-09-15 Engelard Corporation Hydrocarbon conversion process

Patent Citations (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2518693A (en) * 1941-07-24 1950-08-15 Standard Oil Dev Co Process and apparatus for contacting finely divided solids and gases
US2477042A (en) * 1943-03-10 1949-07-26 Standard Oil Dev Co Method of heat exchange in fluidized hydrocarbon conversion systems
US3392110A (en) * 1965-09-02 1968-07-09 Mobil Oil Corp Method for the utilization of highly active hydrocarbon conversion catalysts
US3821103A (en) * 1973-05-30 1974-06-28 Mobil Oil Corp Conversion of sulfur contaminated hydrocarbons
US4435281A (en) * 1980-09-15 1984-03-06 Standard Oil Company (Indiana) Catalytic cracking with reduced emission of noxious gas
US4353812A (en) * 1981-06-15 1982-10-12 Uop Inc. Fluid catalyst regeneration process
US4419221A (en) * 1981-10-27 1983-12-06 Texaco Inc. Cracking with short contact time and high temperatures
US4574044A (en) * 1982-03-31 1986-03-04 Chevron Research Company Method for spent catalyst treating for fluidized catalytic cracking systems
US4693809A (en) * 1985-12-05 1987-09-15 Engelard Corporation Hydrocarbon conversion process

Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0759808A4 (fr) * 1994-05-17 1997-11-12 Robert W Pfeiffer Processus utilisant des solides fluidifies et appareil permettant la mise en oeuvre de ces processus
CN110325278A (zh) * 2017-02-28 2019-10-11 环球油品有限责任公司 紧凑型两段再生器及其使用方法
CN110325278B (zh) * 2017-02-28 2024-02-20 环球油品有限责任公司 紧凑型两段再生器及其使用方法
WO2021019345A1 (fr) * 2019-07-31 2021-02-04 Sabic Global Technologies B.V. Réacteur à colonne montante et à plaques chauffantes
CN114174472A (zh) * 2019-07-31 2022-03-11 沙特基础工业全球技术公司 加热板提升管反应器
US12233405B2 (en) 2019-07-31 2025-02-25 Sabic Global Technologies B.V. Heating plates riser reactor

Also Published As

Publication number Publication date
EP0415935A1 (fr) 1991-03-13
EP0415935A4 (en) 1991-05-15
CA1320924C (fr) 1993-08-03
EP0415935B1 (fr) 1993-09-15

Similar Documents

Publication Publication Date Title
US4820404A (en) Cooling of stripped catalyst prior to regeneration in cracking process
AU627306B2 (en) Heavy oil catalytic cracking process and apparatus
US5248408A (en) Catalytic cracking process and apparatus with refluxed spent catalyst stripper
US5000841A (en) Heavy oil catalytic cracking process and apparatus
CA2087275C (fr) Procede et appareil de controle de la regeneration d'un catalyseur en plusieurs etapes avec combustion partielle du co
US4274942A (en) Control of emissions in FCC regenerator flue gas
US4789458A (en) Fluid catalytic cracking with plurality of catalyst stripping zones
US5128109A (en) Heavy oil catalytic cracking apparatus
US5365006A (en) Process and apparatus for dehydrogenating alkanes
CA2087277A1 (fr) Procede pour le controle de la regeneration d'un catalyseur en plusieurs etapes avec combustion complete puis combustion partielle du co
US5183558A (en) Heavy oil catalytic cracking process and apparatus
US4973452A (en) Heavy oil catalytic cracking
EP0415935B1 (fr) Craquage catalytique d'huile lourde
CA1261774A (fr) Methode et dispositif de fractionnement catalytique fluide
AU633480B2 (en) Heavy oil catalytic cracking
WO1992001511A1 (fr) Procede et appareil servant a commander la regeneration multiphase de catalyseurs avec combustion complete du co
WO1993000674A1 (fr) Procede de rectification et de regeneration d'un catalyseur de craquage catalytique fluidise
EP0639216A1 (fr) Procede de craquage catalytique et appareil concu a cet effet
JPH03505594A (ja) 重質油接触クラッキング
AU8221391A (en) A process for stripping and regenerating fluidized catalytic cracking catalyst

Legal Events

Date Code Title Description
AK Designated states

Kind code of ref document: A1

Designated state(s): AU JP

AL Designated countries for regional patents

Kind code of ref document: A1

Designated state(s): BE DE FR GB IT NL

WWE Wipo information: entry into national phase

Ref document number: 1989903557

Country of ref document: EP

WWP Wipo information: published in national office

Ref document number: 1989903557

Country of ref document: EP

WWG Wipo information: grant in national office

Ref document number: 1989903557

Country of ref document: EP