EP0023402A1 - Craquage catalytique fluidisé avec des gradients de température et de composition réduits dans la phase diluée du régénérateur - Google Patents

Craquage catalytique fluidisé avec des gradients de température et de composition réduits dans la phase diluée du régénérateur Download PDF

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Publication number
EP0023402A1
EP0023402A1 EP19800302404 EP80302404A EP0023402A1 EP 0023402 A1 EP0023402 A1 EP 0023402A1 EP 19800302404 EP19800302404 EP 19800302404 EP 80302404 A EP80302404 A EP 80302404A EP 0023402 A1 EP0023402 A1 EP 0023402A1
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Prior art keywords
catalyst
regeneration
bed
gas
regeneration gas
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EP19800302404
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German (de)
English (en)
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EP0023402B1 (fr
Inventor
Edward Cooper Luckenbach
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ExxonMobil Technology and Engineering Co
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Exxon Research and Engineering Co
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Priority claimed from US06/058,491 external-priority patent/US4243518A/en
Priority claimed from US06/058,490 external-priority patent/US4243517A/en
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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
    • 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
    • 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 present invention relates to the regeneration of catalysts employed in a fluid catalytic cracking process. More particularly, this invention relates to the combustion of volatile hydrocarbons in mixture with spent fluid catalytic cracking catalyst prior to said mixture entering the regeneration zone.
  • the fluidized catalytic cracking of hydrocarbons is well known in the prior art and may be accomplished in a variety of processes which employ fluidized solid techniques. Normally in such processes, suitably preheated, relatively high molecular weight hydrocarbon liquids and/or vapors are contacted with hot, finely-divided, solid catalyst particles either in a fluidized bed reaction zone or in an elongated riser reaction zone, and maintained at an elevated temperature in a fluidized state for a period of time sufficient to effect the desired degree of cracking to lower molecular weight hydrocarbons typical of those present in motor gasolines and distillate fuels.
  • the catalyst is transferred from the reaction zone into a regeneration zone.
  • Typical regeneration zones comprise large vertical cylindrical vessels wherein the spent catalyst is maintained as a fluidized bed by the upward passage of an oxygen-containing regeneration gas, such as air.
  • the fluidized catalyst forms a dense phase catalyst bed in the lower portion of the vessel and a dilute catalyst phase containing entrained catalyst particles above, with an interface existing between the two phases.
  • the catalyst is contacted with the oxygen-containing regeneration gas
  • Flue gas which normally comprises gases arising from the combustion of the coke on the spent catalyst, inert gases such as nitrogen from air, any unconverted oxygen and entrained catalyst particles, is then passed from the dilute catalyst phase into solid-gas separation means within the regeneration zone (e.g., cyclone separators) to prevent excessive losses of the entrained catalyst particles.
  • the catalyst particles separated from the flue gas are returned to the dense phase catalyst bed.
  • a substantially catalyst-free flue gas may then be passed from the separation means to equipment downstream thereof, for example to a plenum chamber, or be discharged directly from the top of the regeneration zone.
  • the regenerated catalyst is subsequently withdrawn from the regeneration zone and reintroduced into the reaction zone for reaction with additional hydrocarbon feed.
  • spent catalyst from the reaction zone is passed therefrom to a stripping zone for removal of volatile hydrocarbons from the catalyst particles prior to transferring the catalyst to the regeneration zone.
  • the volatile hydrocarbons not recovered as product from the reaction zone will pass with the spent catalyst into the regeneration zone wherein they are combusted in preference to the carbon on the spent catalyst. This results in exhaustion of the oxygen in the regeneration gas in the area where the spent catalyst and volatile hydrocarbons enter the regeneration zone.
  • the spent catalyst and volatile hydrocarbons enter the regeneration zone at an off-center location to avoid interference with the regeneration overflow well and/or auxiliary heating air section.
  • one area of the dense phase bed is essentially starved of oxygen such that CO rather than C0 2 will be formed.
  • an excess of oxygen is present in the remaining portion of the dense phase bed since volatile hydrocarbons are not present therein.
  • Such high temperatures in the dilute catalyst phase can cause deactivation of the small amounts of catalyst still present, thereby requiring additional catalyst replacement to the process in order to maintain a desired catalytic activity in the hydrocarbon reaction zone. Additionally, these high temperatures may cause damage to mechanical components of the regeneration zone, particularly in that portion of the regeneration zone in contact with the substantially catalyst-free flue gas wherein the temperature may increase to 1800°F or greater.
  • Such high temperatures are realized because the reaction shown in equation (1) proceeds rapidly within the substantially catalyst-free flue gas since there is very little entrained catalyst present to absorb the heat released, and thereby reduce the rise in temperature. Thus, in that portion of the regeneration zone wherein the flue gas is substantially catalyst-free, there will occur a rapidly accelerating rise in temperature due to the heat released as complete combustion of carbon monoxide occurs in the absence of any means to moderate the temperature therein.
  • the formation of CO in the dense phase catalyst bed of the regeneration zone of a fluid catalytic cracking process due to the volatile hydrocarbons in the spent catalyst mixture entering said regeneration zone may be reduced and/or minimized by using a minor portion of the regeneration gas to combust said hydrocarbons prior to said mixture entering the regeneration zone or to combust said hydrocarbons at or'near the point where the mixture is released into the regeneration zone.
  • the amount of regeneration gas used to combust the hydrocarbons is not critical, and, typically, will range from about 2 to about 20% of the regeneration gas normally employed.
  • combustion of the hydrocarbons will occur in the line transferring spent catalyst from the reaction zone to the regeneration zone.
  • FIGS 1 and 2 disclose a catalyst cracking system in which the catalyst circulation rate is controlled either by adjusting the differential pressure between the zones by suitable control means or by varying the catalyst density in the riser entering the regeneration zone.
  • Figure 3 illustrates a system in which the catalyst flow rate between the reaction and regeneration zones is controlled by a slide valve.
  • the subject invention is not limited to these type systems and is equally applicable to other type cracking systems and to other zone configurations and positions such as upflow and downflow regeneration systems with and without slide valves.
  • Various items such as valves, pumps, compressors, steam lines, instrumentation and other process equipment and control means have been omitted from the figures for the sake of simplicity. Variations obvious to those having ordinary skill in the art of catalyst regeneration processes are included within the broad scope of the present invention.
  • Hydrocarbon feedstocks that can be suitably employed in a fluid catalytic cracking process include naphthas, light gas oils, heavy gas oils, wide-cut gas oils, vacuum gas oils, kerosenes, decanted oils, residual fractions, reduced crude oils, cycle oils derived from any of these, as well as suitable fractions derived from shale oil kerogen, . tar sands bitumen processing, synthetic oils, coal hydrogenation, 'and the like.
  • Such feedstocks may be employed singly, separately in parallel reaction zones, or in any desired combination.
  • Hydro-carbon gas and vapors passing through fluid bed 12 maintain the bed in a dense turbulent fluidized condition having the appearance of a boiling liquid.
  • the cracking catalyst becomes spent during contact with the hydrocarbon feedstock due to the deposition of coke thereon.
  • the terms "spent” or “coke-contaminated” catalyst as used herein generally refer to catalyst which has passed through a reaction zone and which contains a sufficient quantity of coke thereon to cause activity loss, thereby requiring regeneration.
  • the coke content of spent catalyst can vary anywhere from about 0.5 to about 5 wt. % or more.
  • spent catalyst coke contents vary from about 0.5 to about 1.5 wt. %.
  • the spent catalyst Prior to actual regeneration, the spent catalyst is usually passed from the reaction zone into a stripping zone 18 and contacted therein with a stripping gas, which is introduced into the lower portion of zone 18 via line 20.
  • the stripping gas which is usually introduced at a pressure of from about 10 to about 50 psi g , serves to remove most of the volatile hydrocarbons from the spent catalyst.
  • a preferred stripping gas is steam, although nitrogen, other inert gases or flue gas may be employed.
  • the stripping zone is maintained at essentially the same temperature'as the reaction zone, i.e., from about 850° to about 1100°F.
  • Stripped spent catalyst from which most of the volatile hydrocarbons have been stripped is then passed from the bottom of stripping zone'18, through a spent cata- m lyst transfer line, such as U-bend 22 and interconnected vertical riser 24, which extends into the lower portion of a regeneration zone 26.
  • a spent cata- m lyst transfer line such as U-bend 22 and interconnected vertical riser 24, which extends into the lower portion of a regeneration zone 26.
  • Riser 24 is shown entering regeneration zone 26 off-center to avoid interference with the auxiliary heating air from section 31 of the regeneration zone. In the embodiment shown, only one riser 24 is utilized. It is, however, within the contemplation of the subject invention that a plurality of risers may be used.
  • Air is added to riser 24 through line 41 and line 28 in an amount sufficient to reduce the density of the catalyst flowing therein, thus causing the catalyst to flow upward into the regeneration zone 26 by simple hydraulic balance.
  • the regeneration zone is a separate vessel (arranged at approximately the same level as reaction zone 10) containing a dense phase catalyst bed 30 having a level indicated at 32, which is undergoing regeneration to burn off coke deposits formed in the reaction zone during the cracking reaction, above which is a dilute catalyst phase 34.
  • An oxygen-containing regeneration gas enters the lower portion of regeneration zone 26 via line 36 and passes up through a grid 38 and the dense phase catalyst bed 30, maintaining said bed in a turbulent fluidized condition similar to that present in reaction zone 10.
  • one embodiment of the present invention resides in passing a minor portion of said regeneration gas via lines 41 and 40 into riser 24 relatively close to where the riser enters regeneration zone 26 to combust the volatile hydrocarbons present therein prior to their entering the dense phase bed.
  • Oxygen-containing regeneration gases which may be employed in the process of the present invention are those gases which contain molecular oxygen in admixture with a substantial portion of an inert diluent gas
  • Air is a particularly suitable regeneration gas.
  • An additional gas which may be employed is air enriched with oxygen.
  • steam may be added to the dense phase bed along with the regeneration gas or separately therefrom to provide additional inert diluents and/or fluidization gas.
  • the specific vapor velocity of the regeneration gas will be in the range of from about 0.8 to about 6.0 feet/sec., preferably from about 1.5 to about 4 feet/ sec.
  • Regenerated catalyst from the dense phase catalyst bed 30 in the regeneration zone 26 flows downward through standpipe 42 and passes through U-bend 44 into the reaction zone 10 by way of the transfer line 46 which joins U-bend 44 at the level of the oil injection line 16 above the U-bend.
  • regenerated catalyst is meant catalyst leaving the regeneration zone which has contacted an oxygen-containing gas causing at least a portion, preferably a substantial portion, of the coke present on the catalyst to be removed. More specifically, the carbon content of the regenerated catalyst can vary anywhere from about 0.01 to about 0.2 wt.%, but preferably is from about 0.01 to about 0.1.
  • the hydrocarbon feedstock for the cracking process is injected into line 46 through line 16 to form an oil and catalyst mixture which is passed into the fluid bed 12 within the reaction zone 10.
  • Product vapors containing entrained catalyst particles pass overhead from fluid bed 12 into a gas-solid separation means 48 wherein the entrained catalyst particles are separated therefrom and returned through diplegs 50 leading back into fluid bed 12.
  • the product vapors are then conveyed through line 52 into the product recovery system.
  • flue gases formed during regeneration of the spent catalyst pass from the dense phase catalyst bed 30 into the dilute catalyst phase 34 along with entrained catalyst particles.
  • the catalyst particles are separated from the flue gas by a suitable gas-solid separation means 54 and returned to the dense phase catalyst bed 30 via diplegs 56.
  • the substantially catalyst-free flue gas then passes into a plenum chamber 58 prior to discharge from the regeneration zone 26 through line 60.
  • the flue gas will contain less than about 0.2, preferably less than 0.1, and more preferably less than 0.05 volume % carbon monoxide.
  • the oxygen content will vary from about 0.4 to about 7 vol.%, preferably from about 0.8 to about 5 vol.%, more preferably from about 1 to about 3 vol.%, most preferably from about 1.0 to about 2 vol.%.
  • transverse oxygen gradients i.e., gradients in the direction perpendicular to the flow of the regeneration gas
  • the gradient may be especially pronounced where only one assymetric riser 24 is used.
  • undesirable or excessive afterburning is meant to mean obtaining temperatures in the substantially catalyst-free flue gas system due to the combustion of carbon monoxide that exceed permissible catalyst deactivation, or materials of construction limitations and the like.
  • undesirable or excessive afterburning corresponds to temperatures above 1450°F.
  • the temperature should be maintained below about 1420°F, more preferably below about 1400°F, to avoid the undesirable effects of excessive afterburning.
  • the exact location at which the regeneration gas is injected is rather critical.
  • the air should be injected at a point at which it will have little, if any, effect on circulation rate.
  • the regeneration gas preferably is injected into riser 24 as close to regeneration zone 26 as mechanical considerations will permit. In a typical system, this point may be 5-8 feet from the discharge point of riser 24 into bed 30.
  • the amount of regeneration gas employed to conduct the volatile hydrocarbons is not critical. However, the amount of regeneration gas injected into the spent catalyst transfer line should be regulated somewhat to assure that only the approximate amount of regeneration gas required for combustion of the volatile hydrocarbons is added. Injection of an insufficient amount of regeneration gas will result in the continued presence of transverse oxygen gradients in regeneration zone 26. Injection of an excess amount of regeneration gas will cause excessive catalyst entrainment which might overload gas-solid separation means 54. Moreover, if a considerable excess of regeneration gas were injected into riser 24, complete combustion of the volatile hydrocarbon and the coke would be effected in the vicinity of the point where the riser enters the vessel, but incomplete combustion would occur in other areas of the regeneration zone.
  • a transverse oxygen gradient would be created and once again afterburning would occur in dilute catalyst phase 34.
  • the amount of regeneration gas injected into riser 24 preferably is regulated by monitoring the transverse oxygen gradient, the transverse CO gradient, or a transverse temperature gradient, A schematic diagram and a detailed description of such a control system is presented hereinafter.
  • the amount of air utilized may be dependent in part on the type of regeneration system utilized and where the minor portion of the regeneration gas is injected to combust the volatile hydrocarbons. Where the minor portion of the regeneration gas is injected into the spent catalyst transfer line, typically this will correspond to from about 2 to about 20%, preferably from about 4 to about 15%, of the regeneration gas. In the embodiment of Figure 1, about 0 to about 12% of the total regeneration gas enters through line 28 to control catalyst circulation, while about 2 to about 10%, and preferably about 3% to about 6%, of the total regeneration gas enters through line 40 to combust the volatile hydrocarbons.
  • FIG. 2 shows spent catalyst from a stripping zone (not shown) being introduced into the dense phase catalyst bed 30 of regeneration zone 26 via line 22. Also shown is regeneration gas in line 36 passing up through grid 38 and into bed 30 where it reacts with the carbon on the spent catalyst therein such that a regenerated catalyst is passed from zone 26 via line 42.
  • valve 68 controls the catalyst density which, in turn, governs the catalyst circulation rate. Operation of valve 68 may be controlled by a signal E 8 from a comparison means 70 which compares control signal E 7' corresponding to the desired temperature in reaction zone 10, to signal E 6' transmitting the actual temperature in the reaction zone. Typically, valve 68 is opened further to increase the catalyst circulation rate when the temperature in reaction zone 10 is too low, and, conversely, the opening in the valve is decreased when the temperature in zone 10 is too high. The catalyst circulation rate also may be varied to control other process variables such as the temperature in regeneration zone 26.
  • oxygen concentrations could be sensed at, for example, spaced-apart points (1) and (2).
  • concentration of hydrocarbon components or nonhydrocarbon components such as carbon monoxide, ammonia, hydrogen, or oxides of nitrogen, which are oxidizable in regeneration zone 26, alternatively could be sensed.
  • a temperature gradient and a C0 2 gradient also will be formed which alternatively may be sensed by spaced-apart points (1) and (2).
  • points (1) and (2) are preferably disposed in a horizontal plane generally transverse to the direction of flow of the regeneration gas.
  • points (1) and (2) could be located at any spaced-apart locations in dilute phase 34 at which differences resulting from the oxygen gradient could be detected.
  • signals E 1 and E 2 corresponding to the sensed temperatures or oxygen concentrations at points (1) and (2), respectively, could be developed and passed into a computation means 62 suitable for calculating a transverse oxygen or temperature gradient.
  • Suitable computation means can be selected from a variety of digital and/or analog computing devices, depending upon the particular application.
  • the computation means could be a large computer capable of controlling an entire refinery complex or, if desired, a minicomputer designed for more limited applications. Such computation means are well known articles of commerce and thus are readily available in the marketplace.
  • the oxygen, temperature or other gradient thus calculated can then be developed into a control signal E and sent to a comparison means 64 which compares signal E 3 with a signal E 4 corresponding to the desired transverse oxygen, temperature or other gradient at the points being monitored such that a control signal E 5 is generated.
  • the control signal E 5 is then applied to a control means 66 which regulates the amount of regeneration gas introduced into the spent catalyst line via line 40.
  • the greater the deviation from the desired oxygen gradient i.e., the greater the amount of volatile hydrocarbon introduced into bed 30
  • riser reaction zone 110 comprises a tubular, vertical extending vessel having a relatively large height in relation to its diameter.
  • Reaction zone 110 communicates with a disengagement zone 120, shown located a substantial height above regeneration zone 150.
  • the catalyst circulation rate is controlled by a valve means, such as slide valve 180, located in spent catalyst transfer line 140 extending between disengagement zone 120 and regeneration zone 150.
  • hydrocarbon feedstock is injected through line 112 into riser reaction zone 110 filled with catalyst to catalytically crack the feedstock.
  • Steam may be injected through lines 160 and 162 into return line 158 extending between regeneration zone 150 and reaction zone 110 to serve as a diluent, to provide a motive force for moving the hydrocarbon feedstock upwardly and for keeping the catalyst in a fluidized condition.
  • the vaporized, cracked feedstock products pass upwardly into disengagement zone 120 where a substantial portion of the entrained catalyst is separated.
  • the gaseous stream then-passes through a gas-solid separation means, such as two stage cyclone 122, which further separates out entrained catalyst and returns it to the disengagement zone through diplegs 124, 126.
  • the gaseous stream passes into plenum chamber 132 and exits through line 130 for further processing (not shown).
  • the upwardly moving catalyst in reaction zone 110 gradually becomes coated with carbonaceous material which decreases its catalytic activity. When the catalyst reaches the top of reaction.
  • zone 110 it is redirected by grid 128 into stripping zone 140 in spent catalyst transfer line 142 where it is contacted by a stripping gas, such as steam, entering through line 144 to partially remove the remaining volatile hydrocarbons from the spent catalyst.
  • the spent catalyst then passes through spent catalyst transfer line 142 into dense phase catalyst bed 152 of regeneration zone 150.
  • Oxygen containing regeneration gas enters dense phase catalyst bed 152 through line 164 to maintain the bed in a turbulent fluidized condition, similar to that in riser reaction zone 110.
  • Regenerated catalyst gradually moves upwardly through dense phase catalyst bed 152 eventually flowing into overflow well 156 communicating with return line 158.
  • Return line 158 is shown exiting through the center of dense phase catalyst bed 152, and communicating with riser reaction zone 110.
  • Flue gas formed during the regeneration of the spent catalyst passes from the dense phase catalyst bed 152 into dilute catalyst phase 154.
  • the flue gas then passes through cyclone 170 into plenum chamber 172 prior to discharge through line 174.
  • Catalyst entrained in the flue gas is removed by cyclone 170 and is returned to catalyst bed 152 through diplegs 176, 178.
  • hydrocarbons not removed from the spent catalyst in stripping zone 140 are combusted in preference to the coke on the spent catalyst in dense phase catalyst bed 152.
  • the area where the spent catalyst is discharged into dense phase catalyst bed becomes deficient in oxygen resulting in the formation of CO rather than C0 2 , while excess oxygen will be present in other areas of dense phase catalyst bed 152.
  • excess oxygen is present, the coke is completely converted to C0 2 and free oxygen also passes into the dilute catalyst phase 154, thereby resulting in the formation of dilute phase transverse oxygen gradients.
  • the afterburning can be significantly reduced by more completely combusting the volatile hydrocarbons prior to their entry into dense phase bed 152. This may be accomplished by introducing a minor portion of the regeneration gas through line 190 into spent catalyst transfer line 142.
  • the point at which the regeneration gas is injected into transfer line 142 may be less critical in this embodiment than that in the previous embodiment since here the catalyst recirculation rate is controlled by slide valve 180, rather than be the pressure in the transfer line.
  • the regeneration gas preferably is injected downstream of slide valve 180, most preferably close to regeneration zone 150 to minimize the effect of the regeneration gas on the catalyst flow rate and preclude operational problems.
  • One method of discharging the regeneration gas into transfer line 142 relatively close to regeneration zone 150 is to at least partially dispose a conduit means 192 communicating with line 190 in spent catalyst transfer line 142, with the conduit means terminating substantially near the terminus of the transfer line in dense phase catalyst bed 152.
  • the amount of regeneration gas added through line 190 preferably should be regulated as in the previous embodiment to minimize catalyst entrainment, and also to minimize transverse oxygen gradients.
  • the relative amount of regeneration gas added through lines 164 and 190 can be regulated by control valve 194 in line 190.
  • Valve 194 is controlled in a manner similar to valve 66 shown in Figure 2, the schematic control drawing for the embodiment of Figure 1. Typically, it is believed that about 4% to about 16% of the total regeneration gas should be added to spent catalyst transfer line 142 through line 190, and preferably between about 8% and about 14% of the total regeneration gas.
  • FIG 4 a cracking system substantially similar to that of Figure 1 is shown.
  • a main portion of the regeneration gas is added at or near the point where the spent catalyst mixture is discharged into the regeneration zone, whereas in Figure 1 the main portion of the regeneration gas is injected into the transfer line.
  • all elements except for the line through which a minor portion of the regeneration gas is added to combust the hydrocarbons are similar to those of Figure 1 and have similar reference numbers.
  • the line through which the minor portion of the regeneration gas is injected into the regeneration zone is denoted as line 240.
  • the operation of the cracking system is substantially similar to that of Figure 1 except that in this embodiment a minor portion of the regeneration gas passes through lines 41 and 240 and is released into the localized area where the spent catalyst/volatile hydro- carbon mixture from the stripping zone is released into the dense phase catalyst bed of the regeneration zone.
  • the term "localized area” is defined to be that area within a locus of about one diameter of the spent catalyst transfer line from the terminus of the spent catalyst transfer line in dense phase catalyst bed 30. Normally, the spent catalyst transfer line has a diameter of about 18 inches to about 42 inches depending upon the desired catalyst flow rate and velocity, and the method of circulating the spent catalyst to regeneration zone 26.
  • the amount of regeneration gas employed to combust the volatile hydrocarbons is also not critical and need be only an amount sufficient to at least partially combust the volatile hydrocarbons in the mixture with spent catalyst released into the dense phase bed.
  • the amount of regeneration gas employed to combust the volatile hydrocarbons preferably is regulated to assure that only the approximate amount of regeneration gas required for combustion of the volatile hydrocarbons is added for the reasons previously indicated in connection with the discussion of the embodiment of Figure 1.
  • the amount of regeneration gas injected into dense phase catalyst bed 30 through line 240 will correspond to from about 2 to about 20%, preferably from about 5 to about 9%, of the total regeneration gas.
  • a little more regeneration gas is required through line 240 relative to the embodiments of Figures 1 and 3 where a minor portion of the regeneration gas was injected into the spent catalyst transfer line.
  • a portion of the carbon on the spent catalyst will be combusted in addition to the volatile hydrocarbons.
  • introducing the regeneration gas directly into the bed rather than into the spent catalyst line has certain safety advantages since there is a large reservior of catalyst available to absorb excessive amounts of heat released.
  • an additional 4-12% of the total regeneration gas in line 36 is directed through lines 41 and 28 into riser 24 to fluidize the spent catalyst and regulate the spent catalyst circulation rate.
  • the subject invention is equally applicable to other type cracking systems and to other zone configurations and positions, such as upflow and downflow regeneration systems, including those which incorporate a slide valve to control the catalyst circulation rate.
  • a minor portion of the regeneration gas in line 36 is shown being passed via lines 240 and 41 into the dense phase catalyst bed in the localized area where the spent catalyst is released into said bed to combust volatile hydrocarbons not removed in said stripping zone which otherwise would react preferentially with the oxygen passing through grid 38, thereby causing a depletion of the oxygen in a localized area where the spent catalyst enters bed 30 such that CO rather than C0 2 is formed.
  • This would create transverse oxygen gradients in not only bed 30, but in dilute catalyst phase 34, when gases are passed from bed 30. Hence, undersirable or excessive afterburning could result.
  • the transverse oxygen gradients would be especially pronounced where the spent catalyst enters regeneration zone 26 off-center, as in the embodiment shown.
  • oxygen concentrations could be sensed at, for example, spaced apart points (1) and (2).
  • concentration of hydrocarbon components or non-hydrocarbon components, such as carbon monoxide, ammonia, hydrogen, or oxides of nitrogen, which are oxidizable in regeneration zone 26 alternatively could be sensed.
  • a temperature gradient also will be formed which alternatively may be sensed by spaced-apart points (1) and (2).
  • points (1) and (2) preferably are disposed in a horizontal plane generally transverse to the direction of flow of the gas.
  • points (1) and (2) could be disposed at any spaced-apart locations in dilute phase 34 at which the oxygen or other concentrations.or the temperature differences resulting from the oxygen gradient could be detected.
  • Signals E 1 and E 2 corresponding to the sensed temperature differences or oxygen or other concentration differences between points (1) and (2), respectively, could be developed and passed into a computation means 62 suitable for calculating a transverse temperature or oxygen gradient.
  • Suitable computation means can be selected from a variety of digital and/or analog computing devices, depending upon the particular application.
  • the computation means could be a large computer capable of controlling an entire refinery complex or, if desired, a mini-computer designed for more limited applications. Such computation means are well known articles of commerce and thus are readily available in the marketplace.
  • the temperature, oxygen, or other gradient thus calculated can then be developed into a control signal E 3 and sent to a comparison means 64 which compares signal E 3 with a signal E 4 corresponding to the desired transverse gradient at the points being monitored such that a control signal E 5 is generated.
  • the control signal E S is then applied to a control means 66 which regulates the amount of regeneration gas introduced into the dense phase bed via line 240 preferably to minimize the measured gradient.
  • the greater the deviation from the desired gradient i.e., the greater the amount of volatile hydrocarbon introduced into bed 30
  • the greater will be the amount of regeneration gas employed in line 240.
  • the amount.of regeneration gas used in line 240 could, alternatively, be regulated according to other variables in dilute catalyst phase 34.
  • combustion of the volatile hydrocarbons in mixture with the spent catalyst prior to said mixture entering the dense phase catalyst bed or within a localized area where said mixture enters the dense phase catalyst bed insures that the regeneration gas passing upward through the grid in said bed will burn only the carbon on the catalyst which is mixed throughout the bed.
  • the present invention serves to correct an imbalance in the amount of combustible material present in a localized area of the dense phase catalyst bed by removing a portion of said combustible material (the volatile hydrocarbons) immediately after their entering said bed.
  • Such combustion of the volatile hydrocarbons also serves to prevent or minimize localized starvation of oxygen in the dense phase catalyst bed such that formation of CO rather than C0 2 is minimized.
  • any commercial catalytic cracking catalyst designed for high thermal stability could be suitably employed in the present invention.
  • Such catalysts include those containing silica and/or alumina. Catalysts containing combustion promoters such as platinum also can be used. Other refractory metal oxides such as magnesia or zirconia may be employed and are limited only by their ability to be effectively regenerated under the selected conditions.
  • preferred catalysts include the combinations of silica and alumina, containing 10 to 50 wt.% alumina, and particularly their admixtures with molecular sieves or crystalline aluminosilicates.
  • Suitable molecular sieves include both naturally occurring and synthetic aluminosilicate materials, such as faujasite, chabizite, X-type and Y-type aluminosilicate materials and ultra stable, large pore crystalline aluminosilicate materials.
  • the molecular sieve content of the finished fresh catalyst particles is suitably within the range from 5-15 wt.%, preferably 8-10 wt.%.
  • An equilibrium molecular sieve cracking catalyst may contain as little as about 1 wt.% crystalline material. Admixtures of clay-extended aluminas may also be employed.
  • Such catalysts may be prepared in any suitable method such as by impregnation, milling, co-gelling and the like, subject only to provision of the finished catalyst in a physical form capable of fluidization.
  • the regeneration zone employed in the present invention normally comprises vertical cylindrical vessels wherein the catalyst to be regenerated is maintained as a fluidized bed by the upward passage of an oxygen-containing regeneration gas thereby forming a dense phase catalyst bed and a dilute catalyst phase with an interface in between.
  • the dense phase bed which is usually located in the lower portion of the regeneration zone, is maintained at a temperature in the range of from about 1150°-1350°F, preferably from about 1250-1320°F.
  • the density of the dense phase bed may range from about 8 to about 30 lb/cu. ft.
  • the dilute catalyst phase is the primarily gaseous phase volume located above the dense phase bed within the regeneration zone. Specifically, the dilute phase contains relatively small quantities of catalyst compared to the dense phase bed.
  • the density of the dilute phase zone ranges from about 0.1 to about 1.0 lb/cu. ft. at the inlet to the separation means and from about 1 to about 5 lb/cu. ft. near the interface between the dense bed phase and the dilute catalyst phase.
  • the overall flow in the dilute phase is a concurrent flow of catalyst entrained with flue gases.
  • the dilute catalyst phase can include substantial quantities of the'dense bed material which passes into that phase from excessive agitation or bubbling of gaseous materials through the dense bed.
  • the temperature in the dilute catalyst phase is at least that in the dense bed phase and is advantageously maintained within the range from about 1200° to about 1450°F., preferably from about 1310° to about 1400°F.
  • substantially catalyst-free flue gas is the gaseous phase volume located within or downstream of the catalyst separation means within the regeneration zone. Specifically, the “substantially catalyst-free flue gas” comprises flue gas from the dilute catalyst phase from which entrained catalyst particles have been substantially removed. This corresponds to the gaseous effluent from the separation means within the regeneration zone wherein the concentration of entrained catalyst particles will be less than about 1, preferably less than about 0.2 grains per actual cubic foot.
  • actual cubic foot refers to the volume measured at actual operating conditions without correction to a standard temperature and pressure.
  • the substantially catalyst-free flue gas from the separation means may be discharged to a variety of downstream equipment such as a dispersion means to redistribute the flue gas, stack valves, a plenum chamber and the like, prior to leaving the regeneration zone.
  • downstream equipment such as a dispersion means to redistribute the flue gas, stack valves, a plenum chamber and the like, prior to leaving the regeneration zone.
  • substantial afterburning, and hence excessive temperatures in that portion of the regeneration zone wherein the flue gas is substantially catalyst-free may be avoided.
  • the temperature in that portion of said regeneration zone is maintained at least equal to that of the dilute catalyst phase at the inlet to the separation devices but no more than 50°F., preferably no more than 30°F, and most preferably no more than 20°F, above that at said inlet.
  • extraneous cooling means such as steam may be employed to further reduce the temperature and thereby inhibit the afterburning reaction in that portion of the regeneration zone wherein the flue gas is substantially catalyst-free
  • One or more gas-solids separation means may be utilized in the dilute catalyst phase to separate entrained regenerated catalyst particles from the regeneration gas.
  • Preferred separation means will be cyclone separators, multiclones or the like whose design and construction are well known in the art. In the case of cyclone separators, a single cyclone may be used, but preferably, more than one cyclone will be used in parallel or in series flow to effect the desired degree of separation.
  • the construction of the regeneration zone can be made with any material sufficiently able to withstand the relatively high temperatures involved when afterburning is encountered within the vessel and the high attrition conditions which are inherent in systems wherein fluidized catalyst is regenerated and transported.
  • metals are contemplated which may or may not be lined.
  • ceramic liners are contemplated within any and all portions of the regeneration zone together with alloy use and structural designs in order to withstand the erosive conditions and temperatures of about 1400°F. and, for reasonably short periods of time, temperatures which may be as high as 1800°F.
  • the pressure in the regeneration zone is usually maintained in a range from about atmospheric to about 50 psig., preferably from about 10 to 50 psig. It is preferred, however, to design the regeneration zone to withstand pressures of up to about 100 psig. Operation of the regeneration zone at increased pressure has the effect of promoting the conversion of carbon monoxide to carbon dioxide and reducing the temperature level within the dense bed phase at which the substantially complete combustion of carbon monoxide can be accomplished. The higher pressure also lowers the equilibrium level of carbon on regenerated catalyst at a given regeneration temperature.
  • the residence time of the spent catalyst in the regeneration zone is not critical. In general, it can vary from about 1 to about 6 minutes; typically, from about 2 to about 4 minutes.
  • the contact time or residence time of the flue gas in the dilute catalyst phase established the extent to which the combustion reaction can reach equilibrium.
  • the residence time of the flue gas may vary from about 10 to about 60 seconds in the regeneration zone and from about 2 to about 15 seconds in the dense bed phase.
  • the residence time of the flue gas varies from about 15 to about 20 seconds in the regeneration zone and from about 6 to about 10 seconds in the dense bed.
  • the present invention may be applied remedially to any type of fluid cat cracking unit with little or no modifications and without limitations as to the spatial arrangement of the reaction, stripping, and regeneration zones thereof.
  • the regeneration zone of a catalytic cracking unit can be designed independently from the reaction zone since the regeneration zone merely receives spent catalyst, oxidizes the coke thereon to regenerate the catalyst, and returns the regenerated catalyst to the reaction zone. Therefore, the reaction zone can be a pure transfer line, i.e. one in which the reaction occurs in a single pipe type vessel directly terminating in a rough cut cyclone or cyclones as in Figure 3, a conventional dilute riser/ dense bed combination as in Figures 1 and 4 or a dense bed alone.
  • the invention provides for a minor proportion of the regeneration gas passing to the regenerator to contact the spent catalyst containing coke and combustible hydrocarbons in the vicinity of the region where the spent catalyst enters the dense phase bed of the regenerator.
  • the said region may be in the transfer line for spent catalyst close to its end at the regenerator or it may be within the dense phase regeneration bed close to the said end of the spent catalyst transfer line.
  • temperatures in 0 F are converted to °C by subtracting 32 and then dividing by .1.8. Temperature differences in °F are converted to °C by dividing by 1.8.
  • Lengths expressed in inches are converted to cms by multiplying by 2.54, and lengths in feet are converted to cms by multiplying by 30.48
  • Weights in grains are converted to grams by multiplying by 0.06479891 Pressures in pounds per square inch gauge (psig) are converted to kg/cm by multiplying by 0.07031, and densities in pounds per cubic foot (lb/cu.ft.) are converted to g/cc by multiplying by 0.0160185.

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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)
  • Catalysts (AREA)
EP19800302404 1979-07-18 1980-07-17 Craquage catalytique fluidisé avec des gradients de température et de composition réduits dans la phase diluée du régénérateur Expired EP0023402B1 (fr)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US58491 1979-07-18
US58490 1979-07-18
US06/058,491 US4243518A (en) 1979-07-18 1979-07-18 External method for reducing transverse oxygen gradients in FCCU regeneration
US06/058,490 US4243517A (en) 1979-07-18 1979-07-18 Internal method for reducing transverse oxygen gradients in FCCU regeneration

Publications (2)

Publication Number Publication Date
EP0023402A1 true EP0023402A1 (fr) 1981-02-04
EP0023402B1 EP0023402B1 (fr) 1984-05-02

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EP (1) EP0023402B1 (fr)
CA (1) CA1157796A (fr)
DE (1) DE3067687D1 (fr)
ES (1) ES8105025A1 (fr)

Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR2515680A1 (fr) * 1981-10-30 1983-05-06 Texaco Development Corp Procede de commande de la temperature d'un regenerateur dans un processus de craquage catalytique fluidifie assurant une combustion pratiquement complete du coke et de l'oxyde de carbone
FR2624877A1 (fr) * 1987-12-22 1989-06-23 Inst Francais Du Petrole Procede et dispositif pour le craquage catalytique de charges lourdes comportant un second strippage en lit fluide
FR2627187A1 (fr) * 1988-02-15 1989-08-18 Inst Francais Du Petrole Procede de craquage a l'etat fluide d'une charge d'hydrocarbures
US4940802A (en) * 1987-12-08 1990-07-10 Tosoh Corporation 4,4'-bis(phthalimido)diphenyl sulfone compounds, processes for their production and flame retardant polymer compositions containing them
US5365006A (en) * 1990-07-02 1994-11-15 Exxon Research And Engineering Company Process and apparatus for dehydrogenating alkanes

Citations (6)

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Publication number Priority date Publication date Assignee Title
US2994659A (en) * 1959-10-16 1961-08-01 Kellogg M W Co Method and apparatus for conversion of hydrocarbons
US3135700A (en) * 1959-12-01 1964-06-02 Exxon Research Engineering Co Method and apparatus for catalyst regeneration
US3527694A (en) * 1968-12-09 1970-09-08 Exxon Research Engineering Co Fluid solids system
US4035153A (en) * 1976-05-07 1977-07-12 Texaco Inc. Fluidized cracking catalyst regeneration apparatus
US4062761A (en) * 1975-11-28 1977-12-13 Exxon Research And Engineering Company Method for varying the catalyst circulation rate in a fluid catalytic cracking process
US4062759A (en) * 1976-05-07 1977-12-13 Texaco Inc. Fluidized catalytic cracking regeneration process

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2994659A (en) * 1959-10-16 1961-08-01 Kellogg M W Co Method and apparatus for conversion of hydrocarbons
US3135700A (en) * 1959-12-01 1964-06-02 Exxon Research Engineering Co Method and apparatus for catalyst regeneration
US3527694A (en) * 1968-12-09 1970-09-08 Exxon Research Engineering Co Fluid solids system
US4062761A (en) * 1975-11-28 1977-12-13 Exxon Research And Engineering Company Method for varying the catalyst circulation rate in a fluid catalytic cracking process
US4035153A (en) * 1976-05-07 1977-07-12 Texaco Inc. Fluidized cracking catalyst regeneration apparatus
US4062759A (en) * 1976-05-07 1977-12-13 Texaco Inc. Fluidized catalytic cracking regeneration process

Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR2515680A1 (fr) * 1981-10-30 1983-05-06 Texaco Development Corp Procede de commande de la temperature d'un regenerateur dans un processus de craquage catalytique fluidifie assurant une combustion pratiquement complete du coke et de l'oxyde de carbone
US4940802A (en) * 1987-12-08 1990-07-10 Tosoh Corporation 4,4'-bis(phthalimido)diphenyl sulfone compounds, processes for their production and flame retardant polymer compositions containing them
FR2624877A1 (fr) * 1987-12-22 1989-06-23 Inst Francais Du Petrole Procede et dispositif pour le craquage catalytique de charges lourdes comportant un second strippage en lit fluide
EP0322276A1 (fr) * 1987-12-22 1989-06-28 Institut Français du Pétrole Procédé et dispositif pour le craquage catalytique de charges lourdes comportant un second strippage en lit fluide
FR2627187A1 (fr) * 1988-02-15 1989-08-18 Inst Francais Du Petrole Procede de craquage a l'etat fluide d'une charge d'hydrocarbures
US5365006A (en) * 1990-07-02 1994-11-15 Exxon Research And Engineering Company Process and apparatus for dehydrogenating alkanes

Also Published As

Publication number Publication date
ES493507A0 (es) 1981-05-16
EP0023402B1 (fr) 1984-05-02
ES8105025A1 (es) 1981-05-16
DE3067687D1 (en) 1984-06-07
CA1157796A (fr) 1983-11-29

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