Classifications

• • B—PERFORMING OPERATIONS; TRANSPORTING
  • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
  • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
  • B01J8/00—Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes
  • B01J8/18—Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes with fluidised particles
  • B01J8/1818—Feeding of the fluidising gas
  • B01J8/1827—Feeding of the fluidising gas the fluidising gas being a reactant
• • B—PERFORMING OPERATIONS; TRANSPORTING
  • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
  • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
  • B01J29/00—Catalysts comprising molecular sieves
  • B01J29/90—Regeneration or reactivation
• • B—PERFORMING OPERATIONS; TRANSPORTING
  • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
  • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
  • B01J8/00—Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes
  • B01J8/18—Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes with fluidised particles
  • B01J8/1845—Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes with fluidised particles with particles moving upwards while fluidised
  • B01J8/1863—Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes with fluidised particles with particles moving upwards while fluidised followed by a downward movement outside the reactor and subsequently re-entering it
• • B—PERFORMING OPERATIONS; TRANSPORTING
  • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
  • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
  • B01J8/00—Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes
  • B01J8/18—Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes with fluidised particles
  • B01J8/1872—Details of the fluidised bed reactor
• • 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
• • B—PERFORMING OPERATIONS; TRANSPORTING
  • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
  • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
  • B01J38/00—Regeneration or reactivation of catalysts, in general
  • B01J38/04—Gas or vapour treating; Treating by using liquids vaporisable upon contacting spent catalyst
  • B01J38/12—Treating with free oxygen-containing gas
  • B01J38/30—Treating with free oxygen-containing gas in gaseous suspension, e.g. fluidised bed

Definitions

• This invention generally relates to a process for fluid catalytic cracking and an apparatus related thereto.
• Fluid catalytic cracking can be a catalytic conversion process for cracking heavy hydrocarbons into lighter hydrocarbons by bringing the heavy hydrocarbons into contact with a catalyst composed of finely divided particulate material in a fluidized reaction zone.
• Most FCC units use a zeolite-containing catalyst having high activity and selectivity.
• coke substantial amounts of highly carbonaceous material, referred to as coke, may be deposited on the catalyst forming spent catalyst.
• a high temperature regeneration burns the coke from the spent catalyst.
• the regenerated catalyst may be cooled before being returned to the reaction zone.
• spent catalyst is continually removed from the reaction zone and replaced by essentially coke-free catalyst from the regeneration zone.
• the basic components of the FCC process include a riser, a reaction vessel, and a regenerator.
• a distributor may inject a hydrocarbon feed that can contact the catalyst and be cracked into lighter hydrocarbons.
• a lift gas may be used to accelerate catalyst in a lower section of the riser below or during introduction of the feed.
• the lift velocity can refer to the velocity of the gas and the lifted catalyst just before feed distribution into the riser.
• Catalyst and hydrocarbon feed may be transported upwardly in the riser by the expansion of the gases that may result from the vaporization of the hydrocarbons.
• coke accumulates on the catalyst particles as a result of the cracking reaction.
• the reaction vessel may disengage spent catalyst from product vapors.
• a catalyst stripper can remove adsorbed hydrocarbons from the surface of the catalyst.
• the regenerator burns the coke from the catalyst and recycles the regenerated catalyst into the riser.
• Fluid catalytic cracking riser hydrodynamics can be improved to approach plug flow by injection of a vapor downstream of a primary feed injection zone. Improving riser hydrodynamics may result in a higher conversion of the feedstock and improved product selectivities. Often, a feedstock is in a gas phase and velocities tend to be highest in the center of the riser and much lower near the riser wall. As such, current fluid catalytic cracking risers may contain a higher density of catalyst along a riser wall. This uneven density and velocity profile at any given elevation may result in overcracking at the riser wall and lower conversion at the center of the riser.
• injection of a gas, such as steam or fuel gas, downstream of the primary feed injection zone may improve mixing of the catalyst and gas feedstock and can result in improved conversion and improved selectivities.
• a gas such as steam or fuel gas
• One exemplary embodiment may be a process for fluid catalytic cracking.
• the process can include providing a stream through a plurality of distributors to a riser terminating in a reaction vessel.
• the plurality of distributors includes a first distributor set having at least two distributors positioned around a perimeter of the riser, a second distributor set having at least two distributors positioned around the perimeter of the riser, and a third distributor set having at least two distributors positioned around the perimeter of the riser.
• the third distributor set is positioned above the second distributor set and the second distributor set is positioned above the first distributor set.
• the at least two distributors of the third distributor set can be radially staggered from the at least two distributors of the second distributor set and the at least two distributors of the second distributor set may be radially staggered from the at least two distributors of the first distributor set.
• the fluid catalytic cracking apparatus may include a riser, which, in turn, may include a first distributor set including at least two distributors positioned around a perimeter of the riser at a first elevation, a second distributor set including at least two distributors positioned around the perimeter of the riser at a second elevation, and a third distributor set including at least two distributors positioned around the perimeter of the riser at a third elevation.
• a first vertical distance between the first and second distributor sets is less than a second vertical distance between the second and third distributor sets.
• a further exemplary embodiment may be a fluid catalytic cracking apparatus.
• the fluid catalytic cracking apparatus can include a riser, which, in turn, may include a first distributor set including at least two distributors positioned around a perimeter of the riser at a first elevation, a second distributor set including at least two distributors positioned around the perimeter of the riser at a second elevation, and a third distributor set including at least two distributors positioned around the perimeter of the riser at a third elevation.
• the at least two distributors of the first distributor set are radially staggered from the at least two distributors of the second distributor set and the at least two distributors of the second distributor set are radially staggered from the at least two distributors of the third distributor set.
• the embodiments provided herein can provide multiple sets of gas distributors at several elevations downstream of a primary distributor.
• the vertical distance between the sets of various gas distributors can increase as one moves downstream up the riser.
• the number of gas distributors may be the same or different as the number of primary feed gas distributors and their positions may be radially staggered.
• the radial positions of gas distributors should be rotated as one moves downstream, i.e. up the riser, from one distributor set to the next.
• the number of gas distributors in each set can be decreased further up the riser.
• each gas distributor independently, can be orientated 10° 170° from vertical.
• the term "stream” can include various hydrocarbon molecules, such as straight-chain, branched, or cyclic alkanes, alkenes, alkadienes, and alkynes, and optionally other substances, such as gases, e.g., hydrogen, or impurities, such as heavy metals, and sulfur and nitrogen compounds.
• the stream can also include aromatic and non- aromatic hydrocarbons.
• the hydrocarbon molecules may be abbreviated CI, C2, C3...Cn where "n” represents the number of carbon atoms in the one or more hydrocarbon molecules.
• a superscript "+” or “-” may be used with an abbreviated one or more hydrocarbons notation, e.g., C3 + or C3 ⁇ , which is inclusive of the abbreviated one or more hydrocarbons.
• C3 means one or more hydrocarbon molecules of three carbon atoms and/or more.
• a stream can include one or more fiuids other than or in addition to hydrocarbons, such as air, nitrogen, and steam.
• zone can refer to an area including one or more equipment items and/or one or more sub-zones.
• Equipment items can include one or more reactors or reactor vessels, heaters, exchangers, pipes, pumps, compressors, and controllers. Additionally, an equipment item, such as a reactor, dryer, or vessel, can further include one or more zones or sub-zones.
• Coupled can mean two items, directly or indirectly, joined, fastened, associated, connected, or formed integrally together either by chemical or mechanical means, by processes including stamping, molding, or welding. What is more, two items can be coupled by the use of a third component such as a mechanical fastener, e.g. a screw, a nail, a staple, or a rivet; an adhesive; or a solder.
• a mechanical fastener e.g. a screw, a nail, a staple, or a rivet
• an adhesive e.g. a solder
• FCC fluid catalytic cracking
• the term "spent catalyst” can refer to catalyst particles having accumulated coke as a result of a cracking reaction.
• KPa kilopascal
• vapor can mean a gas or a dispersion that may include or consist of one or more hydrocarbons.
• the term "radially staggered” means that at least 50% of the distributors from a first distributor set at a first elevation on a riser are offset from at least 50% of the distributors of an adjacent distributor set at a different elevation and 50% or less of the distributors of the first distributor set are aligned with any of the distributors of the adjacent distributor set as viewed directly above or below the riser.
• none of the distributors from adjacent sets are aligned as viewed directly above or below the riser, but if adjacent sets have different numbers of distributors, one or two distributors from each set may be aligned, while the remaining distributors are offset.
• FIG. 1 is a schematic depiction of an exemplary fluid catalytic cracking apparatus
• FIG. 2 is a front, elevational view of a portion of an exemplary riser.
• FIG. 3 is a cross-sectional view along line 3-3 in FIG. 2.
• FIG. 4 is a cross-sectional view along line 4-4 in FIG. 2.
• FIG. 5 is a cross-sectional view along line 5-5 of FIG. 2.
• FIG. 6 is a cross-sectional view along line 6-6 of FIG. 2.
• FIG. 7 is a cross-sectional view along line 7-7 of FIG. 2.
• an FCC apparatus 100 may be used in an FCC process.
• the FCC apparatus 100 can include a regenerator 120 and a riser-reactor 200.
• the riser-reactor 200 may include a reaction vessel 220, a stripping zone 260, and a riser 280.
• the feed can have a boiling point range of 180° to 800°C.
• the feed can be at least one of a gas oil, a vacuum gas oil, an atmospheric gas oil, an atmospheric residue, and a vacuum residue.
• the feed may be at least one of a heavy cycle oil and a slurry oil.
• the feed may have a temperature of 140° to 430°C, preferably 200° to 290°C.
• the feed may be injected through a plurality of distributors 300, particularly only those of a first distributor set 320.
• the plurality of distributors 300 can further include a second distributor set 340, a third distributor 360, a fourth distributor set 380, and a fifth distributor set 400.
• a lift gas, including one or more C1-C4 hydrocarbons, and/or steam may be provided, independently, to the second distributor set 340, the third distributor 360, the fourth distributor set 380, and the fifth distributor set 400.
• the feed, lift gas and/or steam can be provided to any of the distributors of the plurality of distributors 300.
• the plurality of distributors 300 is discussed in further detail hereinafter.
• the feed including one or more hydrocarbons may be contacted with a lift gas stream 50 and catalyst.
• the zeolitic molecular sieves used in typical FCC gasoline mode operation may have a large average pore size.
• molecular sieves with a large pore size have pores with openings of greater than 0.7 nm in effective diameter defined by greater than 10 and typically 12 membered rings.
• Suitable large pore molecular sieves may include synthetic zeolites such as X-type and Y-type zeolites, mordenite and faujasite.
• low rare earth content denotes less than or equal to 1.0%, by weight, rare earth oxide on the zeolitic portion of the catalyst.
• Catalyst additives may be added to the catalyst composition during operation.
• the riser 280 may operate with a catalyst to oil weight ratio of 4: 1 to 12: 1, preferably 4: 1 to 10: 1.
• steam may be provided to the riser 280 instead of the feed, and may be provided in an amount of 3 to 15%, preferably 4 to 12%, by weight, of the hydrocarbon feed.
• the lift gas stream 50 includes an inert gas such as steam or a fuel gas provided by the lift gas distributor.
• the lift velocity typically does not exceed 10 meters per second.
• the feed may be cracked in the riser 280 in the presence of catalyst to form a cracked stream.
• the plurality of distributors 300 may be located at different radial positions to improve feedstock distribution in the riser 280 and mixing with catalyst.
• the feed pressure drop across a single distributor may be 170 to 800 KPa, preferably 300 to 520 KPa.
• the steam may be added to hydrocarbon feed prior to ejection from the distributor, and may be 0.5 to 7%), by weight, and preferably 1 to 6%, by weight, based on the weight of the hydrocarbon feed from the distributor.
• the injected feed mixes with the catalyst and moves up the riser 280 and enters the reaction vessel 220.
• the riser 280 may operate in a temperature range of 420° to 650°C, preferably 480° to 600°C.
• the pressure in the riser 280 may be 200 to 350 KPa.
• the blended catalyst and reacted feed vapors are then discharged from the top of the riser 280 through a riser outlet and separated into a cracked product vapor stream and a collection of catalyst particles covered with substantial quantities of coke and generally referred to as spent catalyst.
• Swirl arms 240 provided at the end of the riser 280, may further enhance initial catalyst and cracked hydrocarbon separation by imparting a tangential velocity to the exiting catalyst and cracked product vapor stream mixture.
• the swirl arms 240 are located in an upper portion of a separation chamber 250, and the stripping zone 260 is situated in the lower portion of the separation chamber 250. Catalyst separated by the swirl arms 240 may drop down into the stripping zone 260.
• the cracked product vapor stream including cracked hydrocarbons including gasoline and some catalyst may exit the separation chamber 250 via a gas conduit 230 in communication with one or more cyclones 210.
• the one or more cyclones 210 may remove remaining catalyst particles from a product vapor stream to reduce particle concentrations to very low levels.
• the product vapor stream may exit the top of the reaction vessel 220 as a product stream 204.
• the FCC apparatus 100 may convert a feed to gasoline and lighter products with 90%, by volume, of the gasoline product boiling at or below 193° C using ASTM D-86.
• the conversion may be 55 to 90%>, by volume, as produced.
• Catalyst separated by the one or more cyclones 210 may pass through at least one dipleg into a dense bed where catalyst may pass from the separation chamber 250 to the stripping zone 260.
• the stripping zone 260 removes adsorbed and entrained hydrocarbons from the catalyst by counter-current contact with steam over optional baffles 264. Steam may enter the stripping zone 260 through a line 268.
• a catalyst conduit 70 transfers coked catalyst to the regenerator 120.
• the regenerator 120 can include a regenerator distributor 130, a tee disengager 140, and one or more regenerator cyclones 150.
• the regenerator 120 may receive the coked catalyst and typically combusts the coke from the surface of the catalyst particles by contact with an oxygen-containing gas, often provided by an air stream 60. Generally, the oxygen- containing gas enters the bottom of the regenerator 120 via the regenerator distributor 130.
• the dry air rate to the regenerator 120 may be 3.6 to 6.3 kg/kg coke.
• the hydrogen in the coke may be 4 to 8%, by weight, and the sulfur in the coke may be 0.6 to 3.0%, by weight.
• Catalyst coolers may be used on the regenerator 120. Additionally, the regenerator 120 may be operated under partial carbon monoxide combustion conditions. Moreover, water or light cycle oil may be added to the bottom of the riser 280 to maintain the appropriate temperature range in the FCC apparatus 100.
• flue gases pass upwardly through the regenerator 120.
• a primary separator such as the tee disengager 140, initially separates catalyst from flue gas.
• Regenerator cyclones 150 remove entrained catalyst particles from the rising flue gas before the flue gas exits the vessel through an outlet 160 as a flue gas stream 164. Combustion of coke from the catalyst particles may raise the temperatures of the catalyst.
• the catalyst may pass, regulated by a control valve, through a regenerator standpipe 80 that can communicate with a bottom portion of riser 280. Regenerated catalyst from the regenerator standpipe 80 usually has a temperature of 640° to 760°C.
• the riser 280 can include the plurality of distributors 300, which are preferably feed nozzles. Any suitable tip design or hole pattern can be utilized. Desirably, a nozzle is utilized that provides a gas velocity of 15 to 50 meter per second.
• the distributor sets 320, 340, 360, 380, and 400 are at different elevations on the riser 280, which may be indicated as, respectively, a first elevation, a second elevation, a third elevation, a fourth elevation, and a fifth elevation.
• the distributor sets 320, 340, 360, 380, and 400 can provide hydrocarbons, e.g., feed or lift gas, and/or steam to the riser 280.
• the distributor set 320 provides feed
• the distributor sets 340, 360, 380, and 400 provide lift gas and/or steam to the riser 280.
• the riser 280 has a perimeter 284, such as a periphery, with various distributors 300 attached.
• each distributor set 320, 340, 360, 380, and 400 can be separated by an increasing vertical distance between the sets.
• the vertical distance may be determined, e.g., from the top of a first distributor to the bottom of a second distributor of an adjacent set above, as measured at the juncture of the top of the first distributor to the juncture of the bottom of the second distributor with the riser 280.
• the vertical distance between the distributor sets 320 and 340 can be exceeded by the vertical distance of the distributor sets 340 and 360.
• the vertical distance between the distributor sets 340 and 360 can exceed the vertical distance between the distributor sets 320 and 340 by at least a ratio of 1.3 : 1.
• the vertical distance between the distributor sets 360 and 380 can exceed the vertical distance between the distributor sets 320 and 340 by at least a ratio of 1.7: 1.
• the vertical distance between the distributor sets 380 and 400 can exceed the vertical distance between the distributor sets 320 and 340 by at least a ratio of 3.3: 1.
• the vertical distance between the distributor sets 320 and 340 can be 0.4 to 1.4 meter
• the vertical distance between the distributor sets 340 and 360 can be 0.7 to 1.7 meter
• the vertical distance between the distributor sets 360 and 380 can be 1.0 to 2.0 meter
• the vertical distance between the distributor sets 380 and 340 can be 2.5 to 3.5 meter.
• the vertical distance between the distributor sets can be increased to correspond to the increase in material traveling up the riser 280.
• the first distributor set 320 is depicted having five
• distributors namely distributors 322, 324, 326, 328, and 330.
• the distributors 322, 324, 326, 328, and 330 can be spaced evenly around the perimeter 284 of the riser 280.
• the distributors 322, 324, 326, 328, and 330 can be spaced apart by 72°. However, the distributors 322, 324, 326, 328, and 330 can be distributed unevenly around the perimeter 284 and be spaced apart by any suitable degree.
• each distributor 322, 324, 326, 328, and 330 can be orientated with respect to the perimeter 284 at any suitable angle.
• the distributor 326 can be orientated at a degree of 10° to 170°, 60° to 120°, 70° to 110°, or 100° to 110° with respect to a vertical ray 316 extending downward at the lower juncture of the distributor 326 with the riser 280.
• one preferred embodiment has a distributor pointing up 30° to pointing down 30° from horizontal, corresponding to 60° to 120° with respect to a vertical ray extending downward.
• the distributor 326 in this exemplary embodiment can be orientated 40° to 60° as measured from the vertical ray 316 extending downward.
• distributors pointing downward i.e., greater than 90° with respect to a vertical ray extending downward at the lower juncture of the distributor with the riser 280, can aid maintenance by allowing catalyst to drain from the distributor.
• the second distributor set 340 can include five distributors, namely distributors 342, 344, 346, 348, and 350. Similarly as the first distributor set 320, five distributors are depicted. However any suitable number of distributors can be utilized. In addition, these distributors may be distributed evenly around the perimeter 284, but any suitable arrangement and number of distributors can be utilized.
• the distributors 342, 344, 346, 348, and 350 of the second distributor set 340 can be radially staggered, in this case by 36°, with respect to the distributors 322, 324, 326, 328, and 330 of the first distributor set 320.
• the radially staggering of the sets is discussed in further detail below.
• the distributor 342 can define an angle of 100° to 110° with a vertical ray extending downward. Such an orientation can facilitate mixing of catalyst, gas, and hydrocarbons by injecting the gas counter-current to the flow of material in the riser 280 thereby inducing more turbulence.
• the other distributors 344, 346, 348, and 350 in the second distributor set 340 can be at the same or different angle.
• the angle of the distributors from each set can vary independently within a set or with respect to the other distributors in the other sets.
• the third distributor set 360 can include five distributors, namely a distributor 362, a distributor 364, a distributor 366, a distributor 368, and a distributor 370.
• the radial arrangement of distributors in the third distributor set 360 can be similar to the first distributor set 320.
• the angle with respect to vertical of each distributor of the third distributor set 360 can be similar or different to those of the second distributor set 340.
• the fourth distributor set 380 can include four distributors, namely a distributor 382, a distributor 384, a distributor 386, and a distributor 388, which can be positioned evenly around the perimeter 284 of the riser 280 although any suitable arrangement may be used including an uneven arrangement.
• the distributors 382, 384, 386, and 388 are separated by 90° from one distributor to the next.
• the vertical angle of each distributor 382, 384, 386, and 388, independently, can be as described above.
• a fifth distributor set 400 can include four distributors, namely distributors 402, 404, 406, and 408. Again, these distributors are distributed evenly around the perimeter 284, although any suitable arrangement may be utilized, including an uneven distribution. Moreover, each distributor 402, 404, 406, and 408 is separated from the others by 90°. The vertical angle of each distributor 402, 404, 406, and 408 can be as described above for the other distributors.
• Each distributor can be installed, independently, to protrude no more than 50 millimeters into the riser 280, although any suitable distance may be utilized. Such a minimal protrusion can provide some flow disruption but avoid erosion. Any suitable distributor orientation and elevation can be utilized with any particular riser.
• the distributors can be radially staggered with respect from one set to the next set.
• a set of distributors can be radially staggered with respect to an adjacent set.
• the second distributor set 340 can be radially staggered with respect to the first distributor set 320 and the third distributor set 360.
• the distributors 342, 344, 346, 348 and 350 are radially staggered by 18° with respect to respective distributors 322, 324, 326, 328, and 330 of the first distributor set 320.
• at least some of the distributors of the second distributor set 340 are radially offset with at least one distributor 362, 364, 366, 368, and 370 of the third distributor set 360.
• the four distributors 382, 384, 386 and 388 are radially staggered 45° with respect to the distributors 402, 404, 406, and 408 of the fifth distributor set 400. Additionally, at least some of the distributors 382, 384, 386, and 388 of the fourth distributor set 380 are radially staggered with respect to at least one distributor 362, 364, 366, 368, and 370 of the third distributor set 360, despite the fact that distributors 364 and 384 are aligned. With respect to the fifth distributor set 400, the four distributors 402, 404, 406 and 408 are radially staggered 45° with respect to respective distributors 382, 384, 386, and 388 of the fourth distributor set 380. It is contemplated that at least one distributor in a respective set may be radially staggered with respect to the closest distributor(s) in an adjacent set.
• the number of distributors in each set is, respectively, five, five, five, four, and four.
• any suitable number of distributor sets can be utilized, such as from 2-10 distributor sets.
• these distributors can be orientated in different numbered sets, such as a first set of five distributors, a second set of five distributors, a third set of four distributors, and a fourth set of four distributors; or a first set of eight distributors, a second set of eight distributors, a third set of five or six distributors, and a fourth set of five or six distributors.
• the embodiments disclosed herein can provide the proper flexibility for conducting fluid catalytic cracking.
• the riser-reactor 200 may include a mixing chamber forming an enlarged chamber coupled at or near the bottom of the riser 280 to enhance mixing of the catalyst to achieve a substantial thermal equilibrium.
• the mixing chamber has a greater diameter than the riser 280. If a mixing chamber is coupled to the riser 280, in one exemplary embodiment the distributor sets can be coupled only to the riser 280, and not the mixing chamber.

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• Chemical & Material Sciences (AREA)
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• Organic Chemistry (AREA)
• Chemical Kinetics & Catalysis (AREA)
• Combustion & Propulsion (AREA)
• Oil, Petroleum & Natural Gas (AREA)
• Materials Engineering (AREA)
• General Chemical & Material Sciences (AREA)
• Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
• Feeding, Discharge, Calcimining, Fusing, And Gas-Generation Devices (AREA)

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