EP0382289B1 - Procédé de craquage catalytique d'hydrocarbures - Google Patents

Procédé de craquage catalytique d'hydrocarbures Download PDF

Info

Publication number
EP0382289B1
EP0382289B1 EP90200225A EP90200225A EP0382289B1 EP 0382289 B1 EP0382289 B1 EP 0382289B1 EP 90200225 A EP90200225 A EP 90200225A EP 90200225 A EP90200225 A EP 90200225A EP 0382289 B1 EP0382289 B1 EP 0382289B1
Authority
EP
European Patent Office
Prior art keywords
catalyst
cracking
boiling
hydrocarbon
heavy
Prior art date
Legal status (The legal status 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 status listed.)
Expired - Lifetime
Application number
EP90200225A
Other languages
German (de)
English (en)
Other versions
EP0382289A1 (fr
Inventor
Alan R Goelzer
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Stone and Webster Engineering Corp
Original Assignee
Stone and Webster Engineering Corp
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 Stone and Webster Engineering Corp filed Critical Stone and Webster Engineering Corp
Publication of EP0382289A1 publication Critical patent/EP0382289A1/fr
Application granted granted Critical
Publication of EP0382289B1 publication Critical patent/EP0382289B1/fr
Anticipated expiration legal-status Critical
Expired - Lifetime legal-status Critical Current

Links

Images

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
    • 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
    • C10G51/00—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more cracking processes only
    • C10G51/06—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more cracking processes only plural parallel stages only
    • 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 field of fluidized catalytic cracking of hydrocarbon feedstocks.
  • this invention relates to an improved process and apparatus for catalytically cracking hydrocarbon feedstocks at elevated temperatures wherein catalyst regeneration is conducted in two steps comprising separate relatively low and high temperature regeneration stages and where feedstocks to said method are controlled to obtain a desired product distribution and improved yields of high octane blending stock, C3-C4 olefins and light cycle oil/distillate.
  • this invention relates to an improved process and apparatus of catalytically cracking hydrocarbon feedstocks which relates catalyst activity and selectivity to processing parameters to improve the conversion of available refinery materials.
  • Combination fluidized catalytic cracking (FCC)-regeneration processes wherein hydrocarbon feedstocks are contacted witn a continuously regenerated freely moving finely divided particulate catalyst material under conditions permitting conversion into such useful products as olefins, fuel oils, gasoline and gasoline blending stocks are well known.
  • FCC processes for the conversion of high boiling portions of crude oils comprising vacuum gas oils and heavier components customarily referred to as residual oils, reduced crude oils, vacuum resids, atmospheric tower bottoms, topped crudes or simply heavy hydrocarbons and the like have been of much interest in recent years especially as demand has exceeded the availability of more easily cracked light hydrocarbon feedstocks.
  • the cracking of such heavy hydrocarbon feedstocks which comprise very refractory components, e.g. polycyclic aromatics and asphaltenes and the like, capable of depositing relatively large amounts of coke on the catalyst during cracking, and which typically requires severe operating conditions including very high temperatures has presented problems associated with plant construction materials and catalyst impairment.
  • US-A- 4 601 814 includes a naphtha recycle (25% by volume of fresh feed) injected at a point upstream the feed injection point, which is a cooler zone than the mix zone temperature, so that the naptha recycle is cracked only minimally, the catalyst/oil ratio is increased and conversion of the fresh feed is increased but by 3% to 4% by volume, such increase predominantly involving an increase in the gasoline yield, the increases in the C3 and C4 yields being smaller.
  • a naphtha recycle (25% by volume of fresh feed) injected at a point upstream the feed injection point, which is a cooler zone than the mix zone temperature, so that the naptha recycle is cracked only minimally, the catalyst/oil ratio is increased and conversion of the fresh feed is increased but by 3% to 4% by volume, such increase predominantly involving an increase in the gasoline yield, the increases in the C3 and C4 yields being smaller.
  • a combination fluidized catalytic cracking-regeneration operation wherein catalyst regeneration is successively carried out in separate relatively lower regeneration zones each independently operating under selected conditions to provide hot, fully regenerated catalyst with very limited catalyst impairment per catalyst regeneration cycle.
  • Such hot regenerated catalyst is then employed in the high temperature, high selective catalytic cracking and simultaneous conversion of both high and low boiling components contained in heavy hydrocarbon feeds.
  • FCC Fluidized Catalyst Cracking
  • Catalytic cracking of such feeds tends to oppose selectively to lower boiling components for use as gasoline blending stocks, or as precursors for synthesizing gasoline blending stocks, especially those of higher octane values.
  • the polynuclear compounds not only crack at a slower rate, but will also have a much higher selectivity to C2 and lighter gases and coke production, while the mono- and di-aromatics and the alkyl side chains of naphthene components tend not only to crack at a faster rate, but also tend to exhibit a higher selectivity to gasoline and desired light olefins such as propylene, butenes, pentenes and hexenes. Therefore, as such heavier hydrocarbon feed undergoes cracking the heavier hydrocarbon feed components should be subjected to a reduced residence time at extremely high temperatures in order to limit the cracking thereof as much as possible to paraffinic side chains and mono- and di-aromatics in general to reduce excessive coke production.
  • gasoline selectivity is optimized by more severe catalytic cracking operations of light hydrocarbon feeds, e.g. higher catalyst-to-oil ratios, longer residence times and relatively higher temperatures, than are desirable in the cracking of heavier feeds.
  • gasoline/light olefins and light cycle oil products may be desired in order to produce large quantities of high octane gasoline and gasoline precursors while simultaneously producing increased quantities of fuel oil distillates and diesel fuel. This is especially so in light of current environmental concerns which have necessitated a reduction in pollution by-products of combustion from automobiles from the use of leaded gasoline products. Therefore, unleaded gasoline blend stocks having a high octane number are much in demand.
  • US-A-3 801 493 (cracking virgin gas oil, topped crude and the like, and slack wax in separate risers to recover, inter alia, a light cycle gas oil fraction for use in furnace oil and a high octane naphtha fraction suitable for use in motor fuel, respectively); US-A-3 751 359 (cracking virgin gas oil and intermediate cycle gas oil recycle in separate respective feed and recycle risers); US-A-3 448 037 (wherein a virgin gas oil and a cracked cycle gas oil, e.g.
  • the invention therefore, provides:
  • a major advantage provided by the present invention is the flexibility to simultaneously select operating conditions specifically suited to achieve the optimum desired conversion of available refinery materials and selected hydrocarbon feedstocks to desired products.
  • the novel arrangement of apparatus and processing concepts of this invention substantially obviates problems related to high regenerator and catalyst temperatures encountered in catalytic cracking of high boiling hydrocarbon feedstocks, generally referred to as heavy hydrocarbons herein and boiling initially at least 400°F or higher, to produce gasoline and lower and higher boiling hydrocarbon components.
  • conditions favorable for cracking such feedstocks can be encouraged in a respective riser reactor.
  • FIGURE is an elevational schematic of the process and apparatus of the present invention shown in a combination fluidized catalytic cracking-regeneration operation wherein two respective riser reactors are provided for independently catalytically cracking heavy hydrocarbon feeds and lighter naphtha feeds, wherein catalyst regeneration is successively conducted in two separate relatively lower and higher temperature zones.
  • the catalytic cracking process of this invention relates to the cracking of economically obtained heavy hydrocarbon feedstocks generally referred to as gas oils, residual oils, gas oils comprising residual components, reduced crude, topped crude, and high boiling residual hydrocarbons comprising metallo-organic compounds and the like.
  • gas oils residual oils
  • gas oils comprising residual components
  • reduced crude reduced crude
  • topped crude high boiling residual hydrocarbons comprising metallo-organic compounds and the like.
  • portions of crude oil such as a gas oil with or without a higher boiling hydrocarbon feed portion which may comprise metallo-organic compounds, and essentially all other heavy hydrocarbon feedstocks having a Conradson carbon of at least 2 weight percent and boiling initially at least 204°C (400°F), with approximately 20 weight percent or more of the components therein boiling at 538°C (1000°C) or above.
  • Products obtained from cracking such feedstocks include but are not limited to gasoline and gasoline boiling range products boiling from C5 to 218,8°C (425°F), light cycle oil boiling in the range from 218,8°C (425°F) to 316-371°C (600/670°F), a heavy cycle oil product inclusive of product higher boiling than light cycle oil and boiling up to 427°C (800°F) and above, and a slurry oil boiling from 371°C (670°F) up to 521°C (970°F). Additionally, a heavy cracked naphtha is produced and drawn down as the front end of the light cycle oil distillate or produced separately, and which boils in the range from 166°C (330°F) to 218,8°C (425°F).
  • the process of this invention also relates to the cracking of light, heavy and intermediate virgin naphthas boiling in the range from 38°C to 232°C (100°F to 450°F) and heavy FCC naphthas boiling in the range from 66°C to 218,8°C (150°F to 425°F), to produce, among other things, high octane gasoline, light olefins for alkylation or other reactions to produce high octane blending stock or for petrochemical manufacture, and a common light cycle oil stream.
  • the heavy hydrocarbon feedstock typically comprising a mixture of vacuum gas oils and residual oils is introduced into a first elongated riser reactor and mixed therein with a highly active freshly regenerated cracking catalyst at a temperature at least above 704°C (1300°F).
  • the hydrocarbon feed is preferably first mixed with steam or other gas at such temperature and conditions as to form a highly atomized feedstream, which is then mixed with the hot regenerated catalyst to form a generally vaporous hydrocarbon-catalyst suspension.
  • a suspension separation device or disengaging vessel arrangement containing, for example, separator cyclones employed at the riser discharge separates entrained catalyst from vaporous hydrocarbon feed material including cracked products of conversion.
  • a naphtha feed is introduced into a second elongated riser reactor under conditions to obtain mixing therein with hot freshly regenerated cracking catalyst at a temperature at least above 704°C (1300°F) and under conditions so as to form a vaporous hydrocarbon-catalyst suspension which after catalytic conversion of naphtha feed material flows from the riser discharge into the disengagement device to separate entrained catalyst from vaporous material and additional cracked products of conversion.
  • the combined vaporous hydrocarbon products leaving the separator cyclones are then separated in a downstream fractionation column to products more fully discussed hereinbelow.
  • the spent catalyst particles recovered from each respective riser reactor in the cracking operation are thereafter stripped of entrained hydrocarbon material via treatment with steam or some other suitable stripping gas at an elevated temperature in the range of 471°C (880°F) to 566°C (1050°F), and then successively passed to first and second (relatively lower and higher temperature) catalyst regeneration zones, such as fully described, for example, in US-A-4 664 778, US-A-4 601 814; US-A-4 336 160; US-A-4 332 674; and US-A-4 331 533.
  • the stripped spent catalyst is passed to a dense fluid bed of catalyst in a first catalyst regeneration zone maintained under oxygen and temperature restricted conditions below 704°C (1300°F), and preferably not above 682°C (1260°F).
  • Combustion of hydrocarbonaceous material or coke deposited on the spent catalyst in the first regeneration zone is conducted at relatively mild temperatures and conditions sufficient to burn substantially all the hydrogen present in the coke deposits and a portion of the carbon.
  • the regenerator temperature is thus preferably restricted to a temperature and conditions which do not accelerate catalyst deactivation by exceeding the hydrothermal stability of the catalyst or the metallurgical limits of a conventional low temperature regenerator operation.
  • Flue gases relatively rich in carbon monoxide are recovered from the first regenerator zone and can be directed, for example, to a carbon monoxide boiler or incinerator and flue gas cooler to generate steam by promoting a more complete combustion of available carbon monoxide therein, prior to combination with other process flue gas streams. Such combined streams can then be passed through a power recovery prime mover section to generate process compressed air.
  • a partially regenerated catalyst of limited temperature and comprising carbon residue is recovered from the first regenerator zone substantially free of hydrogen in the coke, and is passed to a second separate unrestrained higher temperature catalyst regeneration zone wherein the remaining relatively carbon-rich coke deposits are substantially completely burned to carbon dioxide at an elevated catalyst temperature preferably within the range of 704°C to 871°C (1300°F to 1600°F), and possibly up to 982°C (1800°F), in an environment with minimal steam from combustion of water or other sources.
  • the second regeneration zone is designed to limit catalyst residence time therein at the high temperature while attaining a carbon burning rate required to achieve a residual carbon on recycled hot catalyst particles less than about 0,05 weight percent and more preferably less than about 0,03 weight percent.
  • Hot flue gases obtained from the second regeneration zone can be fed to external cyclones for recovery of entrained catalyst fines before further utilization, for example, in combining with the prior combusted first regeneration zone flue gas in the manner set forth above.
  • the hot fully regenerated catalyst particles are then passed through respective catalyst collecting zones and conduits to the first and second riser reactors for further cracking operation in the manner described hereinabove.
  • the subject apparatus to carry out the process of this invention is thus a combination catalyst-regeneration operation comprising separate first and second, relatively lower and higher temperature, catalyst regeneration zones operated under conditions such as described above, thereby supplying hot regenerated catalyst to first and second elongated riser reactors for independently catalytically cracking respective hydrocarbon feeds under operating parameters permitting selective conversion to desired products.
  • a fractional distillation zone is also provided for receiving the cracked product mixture from said first and second riser reactors to separate products therein.
  • first and second elongated hydrocarbon riser reactors 8 and 108 are provided wherein a fresh high boiling heavy hydrocarbon feed to be catalytically cracked, typically comprising a gas oil or residual oil or a mixture thereof, is introduced into a lower portion of first riser reactor 8 by conduit means 4 through a multiplicity of streams in the riser cross section charged through a plurality of horizontally spaced apart feed injection nozzles indicated by injection nozzle 6.
  • feed injection nozzles are preferably atomizing feed injection nozzles of the type described, for example, in US-A-4, 434, 049, or some other suitably high energy injection source.
  • Steam, fuel gas, carbon dioxide or some other suitable gas can be introduced into the feed injection nozzles through conduit means 2 as an aerating, fluidizing or diluent medium to facilitate atomization or vaporization of the hydrocarbon feed.
  • Hot regenerated catalyst is introduced into the riser reactor 8 lower portion by conduit means 10 and caused to flow upwardly and become commingled with the multiplicity of hydrocarbon feed streams in the riser reactor 8 cross section, and in an amount sufficient to form a high temperature vaporized mixture or suspension with the hydrocarbon feed.
  • the high temperature suspension thus formed and comprising hydrocarbons, diluent, fluidizing gas and the like and suspended (fluidized) catalyst thereafter passes through riser 8 which is operated in a manner known to those skilled in the art.
  • Cracking conditions preferably include nominal residence times of from 1 to 4 seconds, with a riser temperature profile of regenerated catalyst temperatures from 704°C to 871°C (1300°F to 1600°F), feed preheat temperatures from 121°C to 399°C (250°F to 750°F), mix-zone outlet temperatures from 538°C to 593°C (1000°F to 1100°F), catalytic zone inlet temperatures from 482°C (900°F) to 593°C (1100°F), and riser reactor outlet temperatures from 466°C to 554°C (870°F to 1030°F), and riser pressures ranging from 1,035 bar to 2,76 bar (15 to 40 psig).
  • Catalyst-to-oil ratios based on total feed can range from 5 to 10, with coke on regenerated catalyst ranging from 0.3 to 1.2 weight percent.
  • the amount of diluent added through conduit means 2 can vary depending upon the ratio of hydrocarbon to diluent desired for control purposes. If, for example, steam is employed as a diluent, it can be present in an amount of from about 2 to 8 percent by weight based on the hydrocarbon charge.
  • First riser reactor 8 effluent comprising a mixture of vaporized hydrocarbon and suspended catalyst particles including cracked products of catalytic conversion passes from the upper end of riser 8 through discharge through an initial separation in a suspension separator means indicated by 26 such as an inertial separator and/or passed to one or more cyclone separators 28 located in the upper portion of vessel 20 for additional separation of volatile hydrocarbons from catalyst particles.
  • a suspension separator means indicated by 26 such as an inertial separator and/or passed to one or more cyclone separators 28 located in the upper portion of vessel 20 for additional separation of volatile hydrocarbons from catalyst particles.
  • Separated vaporous hydrocarbons, diluent, stripping gasiform material and the like is withdrawn by conduit 90 for passage to product recovery equipment more fully discussed hereinbelow.
  • Spent catalyst from the cracking process separated by means 26 and cyclones 28 and having a hydrocarbonaceous product or coke from heavy hydrocarbon cracking and metal contaminants deposited thereon is collected as a bed of catalyst 30 in a lower portion of vessel 20.
  • Stripping gas such as steam is introduced to the lower bottom portion of the bed by conduit means 32.
  • Stripped catalyst is passed from vessel 20 into catalyst holidng vessel 34, through flow control valve V34 and conduit means 36 to a bed of catalyst 38 being regenerated in vessel 40, the first catalyst regeneration zone.
  • Oxygen-containing regeneration gas such as air is introduced to a bottom portion of bed 38 by conduit means 42 communicating with air distributor ring 44.
  • Regeneration zone 40 as operated in accordance with procedures known in the art is maintained under conditions as a relatively low temperature regeneration operation generally below 704°C (1300°F) and preferably below 682°C (1260°F) and under conditions selected to achieve at least a partial combustion and removal of carbon deposits and substantially all of the hydrogen associated with the deposited hydrocarbons material from catalytic cracking.
  • the combustion accomplished in the first regeneration zone 40 is thus accomplished under such conditions to form a carbon monoxide rich first regeneration zone flue gas stream.
  • Said flue gas stream is separated from entrained catalyst fines by one or more cyclone separating means, such as indicated by 46. Catalyst thus separated from the carbon monoxide rich flue gases by the cyclones is returned to the catalyst bed 38 by appropriate diplegs.
  • Carbon monoxide rich flue gases recovered from the cyclone separating means 46 in the first regeneration zone by conduit means 50 can be directed, for example, to a carbon monoxide boiler or incinerator and/or a flue gas cooler (both not shown) to generate steam by a more complete combustion of available carbon monoxide therein, prior to combination with other process flue gas streams and passage thereof through a power recovery prime mover section, in the manner discussed hereinabove.
  • the regeneration conditions are selected such that the catalyst is only partly regenerated in the removal of hydrocarbonaceous deposits therefrom such that sufficient residual carbon remains on the catalyst to achieve higher catalyst particle temperatures above 760°C (1400°F), preferably up to 871°C (1600°F), and up to 982°C (1800°F) as required upon more complete removal of the carbon from catalyst particles by combustion thereof with excess oxygen-containing regeneration gas in a second catalyst regeneration zone discussed hereinbelow.
  • Partially regenerated catalyst now substantially free of hydrogen in residual carbon deposits on the catalyst is withdrawn from a lower portion of bed 38 for transfer upwardly through riser 52 to discharge into the lower portion of a dense fluid bed of catalyst 54 in an upper separate second catalyst regeneration zone 58.
  • Lift gas such as compressed air is charged to the bottom inlet of riser 52 by a hollow stemplug valve 60 comprising flow control means (not shown).
  • Conditions in the second catalyst regeneration zone are operated in a manner known in the art to accomplish substantially complete carbon burning removal from the catalyst not removed in the first regeneration zone. Accordingly, regeneration gas such as air or oxygen enriched gas is charged to bed 54 by conduit means 62 communicating with an air distributor ring 64. As shown in the FIGURE, vessel 58 in the second regeneration zone is substantially free of exposed metal internals and separating cyclones such that the high temperature regeneration desired may be effected without posing temperature problems associated with materials of construction.
  • regeneration gas such as air or oxygen enriched gas
  • the second catalyst regeneration zone is usually a refractory lined vessel or manufactured from some other suitable thermally stable material known in the art wherein high temperature regeneration of catalyst is accomplished in the absence of hydrogen or formed steam, and in the presence of sufficient oxygen to effect substantially complete combustion of carbon monoxide in the dense catalyst bed 56 to form a carbon dioxide rich flue gas.
  • temperature conditions and oxygen concentration may be unrestrained and allowed to exceed 871°C (1600°F) and possibly reach as high as 982°C (1800°F) or as required to substantially complete carbon combustion.
  • temperatures are typically maintained between 704°C (1300°F) and 871°C (1600°F).
  • the temperature in vessel 58 in the second regeneration zone is thus not particularly restricted to an upper level except as possibly limited by the amount of carbon to be removed therewithin and heat balance restrictions of the catalytic cracking-regeneration operation.
  • the second regeneration zone 58 can be provided with a means (not shown) for removing heat from the regenerator therein enabling a lower regenerator temperature as desired to control such heat balance restrictions. Examples of heat removal means which are preferred include controllable catalyst coolers such as described in US-A-2 970 117 and US-A-4 064 039.
  • a portion of the catalyst in the regenerator is withdrawn from a lower port theroef, passed downwardly out of the regenerator, then lifted, for example, with air as a fluidized bed through an indirect water cooler steam generator, then lifted into an upper port of the regenerator.
  • the cooled catalyst can alternatively be reintroduced into a lower port of the regenerator.
  • the cooler can be sized accordingly.
  • Catalyst particles regenerated in zone 58 at a high temperature are withdrawn by refractory lined conduits 80 and 81 for passage to collection vessels 82 and 83, respectively, and thence by conduits 84 and 85 through flow control valves V84 and V85 to conduits 10 and 12 communicating with respective riser reactor as above discussed, and with a second riser reactor 108 more fully discussed hereinbelow.
  • Aerating gas can be introduced into a lower portion of vessels 82 and 83 by conduit means 86 communicating with a distributor ring within said vessels. Gaseous material withdrawn from the top portion of vessels 82 and 83 by conduit means 88 passes into the upper dispersed catalyst phase of vessel 58.
  • a naphtha feed stream to be catalytically cracked e.g., light, intermediate or heavy virgin naphtha along with selected cracked naphthas if desired, is introduced into a lower portion of the second elongated riser reactor 108 by conduit means 14 through a multiplicity of streams in the riser cross section charged through a plurality of horizontally spaced apart feed injection nozzles indicated by 16.
  • Such nozzles are preferably atomizing feed injection nozzles or similar high energy injection nozzles of the type described hereinabove.
  • hot freshly regenerated catalyst is introduced into the riser reactor 108 lower portion by conduit means 12 and caused to flow upwardly and become commingled with the multiplicity of hydrocarbon feed streams in the riser reactor 108 cross section, and in an amount surfficient to form a high temperature vaporized mixture or suspension with the hydrocarbon feed.
  • steam, fuel gas or some other suitable gas can be introduced into the feed injection nozzles through conduit means 2 to facilitate atomization and/or vaporization of the hydrocarbon feed, or as an aerating, fluidizing or diluent medium.
  • the high temperature suspension thus formed and comprising hydrocarbons, diluent, fluidizing gas and the like, and suspended (fluidized) catalyst thereafter passes through riser 108 which is preferably operated independently from the first riser reactor 8 in a manner to selectively catalytically crack relatively low boiling naphthas to desired products, including high octane gasoline and gasoline precursors, and light olefins.
  • Such cracking conditions in second riser reactor 108 to selectively produce desired cracked products from the naphtha feeds are well known.
  • heavy carbon laydown on the catalyst e.g. hydrocarbonaceous material or coke build up (which can be liberally contributed by heavy feed residual oils and the like) is a greater detriment to gasoline selectivity when cracking a relatively low boiling feed, such as virgin naphthas or heavy cracked naphthas, than with cracking a relatively high boiling feed, e.g. residual oil and the like, although it can be a detriment to both.
  • naphtha is preferably catalytically cracked in second riser 108 under conditions involving nominal residence times of from 1 to 10 seconds, with feed preheat temperatures from 104°C (220°F) to 371°C (700°F), riser reactor mix zone outlet temperatures from 39,1°C (102°F) to 649°C (1200°F), riser reactor catalytic zone inlet temperatures from 527°C (980°F) to 649°C (1200°F) and riser reactor outlet temperatures from 510°C to 566°C (950°F to 1050°F), with riser pressures ranging from 1,035 bar to 2,415 (15 to 35)psig), Catalyst-to-oil ratios in the second riser reactor based on total feed can range from 3 to 12 with coke make on regenerated catalyst ranging from 0,1 to 0,5 weight percent.
  • Effluent from the second riser reactor 108 therein comprising a vaporized hydrocarbon-catalyst suspension including catalytically cracked products of naphtha conversion passes from the upper end of riser 108 through dicharge through an initial separation in a suspension separator means indicated by 26 such as described hereinabove and/or passed to one or more cyclone separators 28 located in the upper portion of vessel 20 for additional separation of volatile hydrocarbons from catalyst particles, also as described above.
  • Separated vaporous hydrocarbons, diluent, stripping gasiform material and the like can be withdrawn by conduit 90 for combination with such material from the cracking operation in riser reactor 8, and for passage to product recovery equipment.
  • Spent catalyst from the cracking process in riser reactor 108 and separated by means 26 and cyclones 28 is collected in catalyst bed 30 and thence regenerated in the manner described hereinabove in the first and second regeneration zones.
  • the mixture comprising separated vaporous hydrocarbons and materials from hydrocarbon cracking from the cracking operations in riser reactors 8 and 108 is withdrawn by conduit means 90 and transfer conduit means 94 to the lower portion of a main fractional distillation column 98 wherein product vapor can be fractionated into a plurality of desired component fractions.
  • a gas fraction can be withdrawn via conduit means 100 for passage to a "wet gas" compressor 102 and subsequently through conduit 104 to a gas separation plant 106.
  • a light liquid fraction comprising FCC naphtha and lighter C3-C6 olefinic material is also withdrawn from a top portion of column 98 via conduit means 107 for passage to gas separation plant 106.
  • Liquid condensate boiling in the range of C5-221°C (C5-430°F) can be withdrawn from gas separation plant 106 by conduit means 110 for passage of a portion thereof back to the main fractional distillation column 98 as reflux to maintain a desired end boiling point of the naphtha product fraction in the range of 204°C-221°C (400°F-430°F).
  • Products produced in the gas separation plant 106 comprise a C3/C4 light olefin LPG fraction which can be passed via conduit means 111 for further processing into ethylene and propylene in processing means not shown, including an off gas comprising lighter boiling material including an off gas comprising lighter boiling material withdrawn in conduit means 112; a light FCC gasoline product boiling up to 82°C (180°F); an intermediate FCC gasoline product boiling in the range from 38°C (100°F) to 154°C (310°F); and a heavy FCC gasoline boiling in the range from 154°C (310°F) to 221°C 430°F, which can be withdrawn, generally, in conduit means 113.
  • a pump around conduit means 114 in communication with the upper portion of column 98 is provided for supplying at least a portion of a heavy FCC naphtha stream via conduit means 4, 116 and 14 to the feed injection nozzles 16 of the second riser reactor 108 where it is combined with the hot regenerated catalyst introduced by conduit 12 to form a suspension in the manner set forth hereinabove.
  • Heavy FCC naphtha can thus be recycled and recracked in such manner in the presence of the virgin naphtha feed introduced by conduit means 14 to simultaneously catalytically crack both virgin and heavy FCC naphthas under optimum conditions selective for producing high octane gasoline and gasoline feedstocks.
  • the heavy FCC naphtha may also be passed all or in part via conduit means 114 and 4 to feed injection nozzle 6 of the first riser reactor 8 where it is combined with the hot regenerated catalyst introduced by conduit means 10 to form a suspension in the presence of the heavy hydrocarbon feed for catalytic recracking in combination with cracking said heavy hydrocarbon feed and to optimize a desired product distribution.
  • the process and apparatus of the present invention also contemplates providing materials lighter and lower boiling than heavy FCC naptha to be catalytically recracked alone or in combination with recycled heavy FCC naphtha, virgin naphtha and/or heavy gas oil/residual hydrocarbon feeds.
  • Such material includes selected FCC gasoline cuts which can be withdrawn from the gas plant 106 via conduit means 108 and 114, and thereafter supplied to conduit means 4 and/or 14 for introduction into feed nozzles 6 and 16 of the first and second riser reactors, respectively, for such catalytic recracking.
  • a portion of the heavy FCC naphtha stream can also be passed through conduit means 114 to conduit means 160 as a lean oil material for gas generation plant 106.
  • a light cycle gas oil (LCO)/distillate fraction containing naphtha boiling range hydrocarbons is withdrawn from column 98 through conduit means 124, said LCO/distillate fraction having an initial boiling point in the range of 149°C (300°F) to 221°C (430°F), and an end point of 316°C (600°F) to 354°C (670°F).
  • the LCO/distillate fraction can be further processed in a stripper vessel (not shown) within which said LCO/distillate fraction is contacted with stripping vapors thereby stripping the lighter naphtha components from said fraction, and producing a stripped LCO/distillate stream which can thereafter be passed to a hydrotreater or other appropriate processing means for conversion into diesel blending stock.
  • Stripped vapors therefrom comprising naphtha boiling range material can be passed by means (not shown) from said stripper vessel back to the main product fractionator.
  • a non-distillate heavy cycle gas oil (HCO) fraction having an initial boiling range of 316°C (600°F) to 354°C (670°F) is withdrawn from column 98 at an intermediate point thereof, lower than said LCO/distillate fraction draw point, via conduit means 126.
  • HCO heavy cycle gas oil
  • at least a portion of the HCO stream can be passed to conduit 4 for recracking in riser reactor 8 in the manner herein provided.
  • a slurry oil containing non-distillate HCO boiling material is withdrwan via conduit means 132 at a temperature of 316°C (600°F) to 371°C (700°F).
  • a portion of said slurry oil can be passed from conduit 132 through a waste heat steam generator 134 wherein said portion of slurry oil is cooled to a temperature of 232°C (450°F).
  • the waste heat steam generator 134 From the waste heat steam generator 134, the cooled slurry oil flows as an additional reflux to the lower portion of column 98.
  • a second portion of the thus produced slurry oil withdrawn via conduit 136 flows as product slurry oil.

Claims (5)

  1. Procédé de craquage catalytique en lit fluidisé et de régénération, pour le craquage d'alimentations hydrocarbonées et de leurs vapeurs à l'aide d'un catalyseur de craquage, réalisé dans un système comprenant une première et une seconde zones séparées de régénération du catalyseur, dans lequel ledit catalyseur est régénéré successivement dans la première et la seconde zones de régénération, par combustion des dépôts hydrocarbonés présents sur le catalyseur, en présence d'un gaz contenant de l'oxygène et dans des conditions permettant de produire un effluent gazeux de première zone de régénération contenant de 2 à 80 % en volume de monoxyde de carbone et un effluent gazeux de seconde zone de régénération riche en dioxyde de carbone et ne contenant pas plus de 1200 ppm de CO, la température valant de 593°C (1100 °F) à 704°C (1300°F) dans la première zone de régénération et de 704°C (1300°F) à 982°C (1800°F) dans la seconde zone de régénération,
    caractérisé en ce qu'il comporte les étapes consistant à :
    (a) craquer une première alimentation hydrocarbonée, comprenant du gazole, des matières dont le domaine d'ébullition est celui de l'huile noire, ou leurs mélanges, dans un premier réacteur allongé ascendant, en présence d'un catalyseur de craquage régénéré fourni par la seconde zone de régénération de catalyseur, à une température minimale de 704°C ( 1300°F), avec un rapport catalyseur/huile valant de 5 à 10 et un temps de séjour valant de 1 à 4 secondes, du coke se déposant sur ledit catalyseur en une quantité représentant moins de 1,2 % du poids de celui-ci, de façon à obtenir des produits gazeux de conversion de la première alimentation hydrocarbonée, comprenant une fraction lourde de naphta et des substances bouillant plus bas que ladite fraction lourde de naphta, une huile légère recyclée, une huile lourde recyclée, et des substances bouillant plus haut que ladite huile lourde recyclée, et, simultanément,
    (b) craquer une seconde alimentation hydrocarbonée, comprenant du naphta de première distillation, une substance dont le domaine d'ébullition est celui du naphta craqué intermédiaire et lourd, ou leurs mélanges, et dont le point d'ébullition vaut jusqu'à 232°C (450°F), dans un second réacteur allongé ascendant, en présence de catalyseur de craquage régénéré fourni par la seconde zone de régénération de catalyseur, à une température minimale de 704°C (1300°F), avec un rapport catalyseur/huile valant de 3 à 12 et un temps de séjour valant de 1 à 5 secondes, du coke se déposant sur ledit catalyseur en une quantité représentant moins de 0,5 % en poids de celui-ci, de façon à obtenir des produits gazeux de conversion de la seconde alimentation hydrocarbonée, comprenant une substance dont le domaine d'ébullition est celui de l'essence et qui présente une teneur élevée en composés aromatiques et un indice d'octane élevé, et une substance hydrocarbonée plus légère, à partir d'une substance de type huile légère recyclée, et
    (c) combiner les produits gazeux de conversion issus des premier et second réacteurs allongés ascendants, dans une zone commune de décharge, en y séparant des produits gazeux les particules de catalyseur entraînées et en faisant passer les produits de conversion réunis dans une zone de distillation fractionnée pour récupérer au moins une fraction de matière dont le domaine d'ébullition est celui de l'essence et une fraction de matière hydrocarbonée gazeuse plus légère, une fraction de matière dont le domaine d'ébullition est celui d'une huile légère recyclée et une fraction de matière dont le domaine d'ébullition est celui du naphta lourd, y compris une huile épaisse et des fractions de matière bouillant plus haut.
  2. Procédé conforme à la revendication 1, dans lequel au moins une portion de l'essence ou de la fraction de naphta lourd ou de leurs mélanges est recyclée et craquée à nouveau dans le second réacteur ascendant, dans le premier réacteur ascendant ou dans les deux réacteurs ascendants, le premier et le second.
  3. Procédé conforme à la revendication 2, dans lequel l'essence ou la fraction de naphta lourd, ou un mélange des deux, est recraqué en présence de naphta de première distillation afin d'améliorer son indice d'octane et sa teneur en composés aromatiques.
  4. Procédé conforme à la revendication 1, dans lequel la première alimentation hydrocarbonée comprend des matières hydrocarbonées lourdes, dont le résidu en carbone déterminé par l'essai Conradson vaut au moins 2 % en poids et dont le point d'ébullition initial vaut au moins 204°C (400°F), et qui contient au moins 20 % en poids de composant bouillant à une température d'au moins 538°C (1000°F), et la seconde alimentation hydrocarbonée comprend du naphta de première distillation, bouillant dans le domaine allant de -12,2°C (10°F) à 200°C (392°F), et des composants contenant du naphta lourd ou intermédiaire, ou un mélange de ceux-ci, bouillant jusqu'à 232°C (450°F).
  5. Procédé conforme à la revendication 1, qui comprend en outre le fait de craquer les alimentations hydrocarbonées ou leurs vapeurs à l'aide d'un catalyseur de craquage finement divisé, à l'état fluidisé, pour obtenir des produits craqués et des particules de catalyseur épuisé portant des dépôts hydrocarbonés, le fait de débarrasser les produits hydrocarbonés gazeux des particules de catalyseur, le fait d'envoyer le catalyseur souillé dans la première zone de régénération dans laquelle le catalyseur est partiellement régénéré par combustion de pratiquement la totalité des hydrocarbures associés aux dépôts hydrocarbonés présents sur le catalyseur, à une température maximale de 704°C (1300°F), en présence d'un gaz contenant de l'oxygène, sous une pression valant de 1,035 bar à 2,76 bars (15 à 40 psig) et en des proportions permettant d'obtenir un effluent gazeux de première zone de régénération contenant de 2 à 80 % en volume de monoxyde de carbone, et le fait d'envoyer ensuite le catalyseur partiellement régénéré dans la seconde zone de régénération dans laquelle le catalyseur est complètement régénéré par combustion de pratiquement la totalité des dépôts hydrocarbonés restant à la surface du catalyseur, à des températures valant de 704°C (1300°F) à 982°C (1800°F), en présence d'un gaz contenant de l'oxygène en des proportions permettant d'obtenir un effluent gazeux de seconde zone de régénération contenant au maximum 1200 parties par million en volume de monoxyde de carbone.
EP90200225A 1989-02-06 1990-01-31 Procédé de craquage catalytique d'hydrocarbures Expired - Lifetime EP0382289B1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US30732989A 1989-02-06 1989-02-06
US307329 1989-02-06

Publications (2)

Publication Number Publication Date
EP0382289A1 EP0382289A1 (fr) 1990-08-16
EP0382289B1 true EP0382289B1 (fr) 1994-03-30

Family

ID=23189257

Family Applications (1)

Application Number Title Priority Date Filing Date
EP90200225A Expired - Lifetime EP0382289B1 (fr) 1989-02-06 1990-01-31 Procédé de craquage catalytique d'hydrocarbures

Country Status (6)

Country Link
EP (1) EP0382289B1 (fr)
JP (1) JPH0645787B2 (fr)
KR (1) KR930011920B1 (fr)
BR (1) BR9000490A (fr)
CA (1) CA2008978A1 (fr)
DE (1) DE69007649T2 (fr)

Families Citing this family (18)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5435906A (en) * 1992-08-20 1995-07-25 Stone & Webster Engineering Corporation Process for catalytically cracking feedstocks paraffin rich comprising high and low concarbon components
DE19602898A1 (de) * 1996-01-27 1997-07-31 Ruhr Oel Gmbh Verfahren zum katalytischen Kracken von Kohlenwasserstoffen
FR2770225B1 (fr) * 1997-10-24 2000-01-07 Total Raffinage Distribution Procede et dispositif de vaporisation selective des charges d'hydrocarbures en craquage catalytique
DE19805915C1 (de) * 1998-02-13 1999-09-23 Ruhr Oel Gmbh Verfahren zum Cracken von Kohlenwasserstoffen
WO1999055802A1 (fr) * 1998-04-28 1999-11-04 Exxon Research And Engineering Company Procede de mise en oeuvre pour craquage catalytique fluide
US6156189A (en) * 1998-04-28 2000-12-05 Exxon Research And Engineering Company Operating method for fluid catalytic cracking involving alternating feed injection
US20070129586A1 (en) * 2005-12-02 2007-06-07 Zimmermann Joseph E Integrated hydrocarbon cracking and product olefin cracking
FR2918070B1 (fr) * 2007-06-27 2012-10-19 Inst Francais Du Petrole Zone reactionnelle comportant deux risers en parallele et une zone de separation gaz solide commune en vue de la production de propylene
FR2932495B1 (fr) * 2008-06-17 2011-03-25 Inst Francais Du Petrole Dispositif de controle des conditions operatoires dans une unite de craquage catalytique a deux risers.
JP5368073B2 (ja) * 2008-12-11 2013-12-18 昭和シェル石油株式会社 ガソリンエンジン用燃料組成物の製造方法及びその製造方法に使用する自動車エンジン用燃料基材
WO2011051434A2 (fr) * 2009-11-02 2011-05-05 Shell Internationale Research Maatschappij B.V. Procédé de craquage
US20130130889A1 (en) * 2011-11-17 2013-05-23 Stone & Webster Process Technology, Inc. Process for maximum distillate production from fluid catalytic cracking units (fccu)
US10870802B2 (en) * 2017-05-31 2020-12-22 Saudi Arabian Oil Company High-severity fluidized catalytic cracking systems and processes having partial catalyst recycle
WO2019158635A1 (fr) * 2018-02-16 2019-08-22 Haldor Topsøe A/S Additifs d'élimination des sox et des nox contenant du cuivre destinés à être utilisés dans le processus de craquage catalytique fluide (fcc)
TW202104562A (zh) * 2019-04-03 2021-02-01 美商魯瑪斯科技有限責任公司 用於升級輕油系列材料之合併有固體分離裝置之分段流體化媒裂程序
CN111689829B (zh) * 2020-07-09 2023-03-10 青岛京润石化设计研究院有限公司 一种石油烃催化转化制乙烯的方法及其装置
CN115992004A (zh) * 2021-10-18 2023-04-21 青岛京润石化设计研究院有限公司 一种反应原料为烃类原料的催化转化制低碳烯烃和芳烃的反应方法及反应器
CN116196848A (zh) * 2021-12-01 2023-06-02 中国石油天然气股份有限公司 一种原料油和轻烃催化转化的装置和方法

Family Cites Families (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3617496A (en) * 1969-06-25 1971-11-02 Gulf Research Development Co Fluid catalytic cracking process with a segregated feed charged to separate reactors
US3886060A (en) * 1973-04-30 1975-05-27 Mobil Oil Corp Method for catalytic cracking of residual oils
US3928172A (en) * 1973-07-02 1975-12-23 Mobil Oil Corp Catalytic cracking of FCC gasoline and virgin naphtha
US4601814A (en) * 1983-05-27 1986-07-22 Total Engineering And Research Company Method and apparatus for cracking residual oils

Also Published As

Publication number Publication date
KR930011920B1 (ko) 1993-12-22
CA2008978A1 (fr) 1990-08-06
JPH0645787B2 (ja) 1994-06-15
DE69007649D1 (de) 1994-05-05
KR900013059A (ko) 1990-09-03
BR9000490A (pt) 1991-01-15
EP0382289A1 (fr) 1990-08-16
DE69007649T2 (de) 1994-08-25
JPH03197591A (ja) 1991-08-28

Similar Documents

Publication Publication Date Title
US5009769A (en) Process for catalytic cracking of hydrocarbons
US5565176A (en) Catalytically cracking paraffin rich feedstocks comprising high and low concarbon components
CA2657628C (fr) Craquage auxiliaire de naphte raraffinique, concurremment avec les operations de craquage catalytique fluide
US4336160A (en) Method and apparatus for cracking residual oils
KR101447299B1 (ko) Ｆｃｃ유닛 작동과 관련된 중질 오일 피드스트림을 경질 탄화수소 생성물 스트림으로 변환 및 회수 방법
EP0382289B1 (fr) Procédé de craquage catalytique d'hydrocarbures
TWI599400B (zh) 流體催化裂解方法及用於最大化輕質烯烴或最大化中間蒸餾物及輕質烯烴的裝置
JP5197597B2 (ja) 軽質及び混合軽質／重質供給物を用いた二重ライザーｆｃｃ反応器プロセス
US4090948A (en) Catalytic cracking process
US5087349A (en) Process for selectively maximizing product production in fluidized catalytic cracking of hydrocarbons
EP3077484B1 (fr) Procédé intégré de désasphaltage et de craquage catalytique fluide de production d'oléfines légères
US5435906A (en) Process for catalytically cracking feedstocks paraffin rich comprising high and low concarbon components
US5043058A (en) Quenching downstream of an external vapor catalyst separator
US7544333B2 (en) Device for cracking of hydrocarbons using two successive reaction chambers
US20130130889A1 (en) Process for maximum distillate production from fluid catalytic cracking units (fccu)
EP0369536B1 (fr) Procédé pour maximaliser sélectivement la production de produits dans le craquage catalytique fluidisé d'hydrocarbures
US5324419A (en) FCC to minimize butadiene yields
US20210207039A1 (en) Maximum olefins production utilizing multi-stage catalyst reaction and regeneration
JPS6337155B2 (fr)
US5073249A (en) Heavy oil catalytic cracking process and apparatus
US4980051A (en) Process and apparatus for preheating heavy feed to a catalytic cracking unit
US20040140246A1 (en) Process for upgrading fcc product with additional reactor
RU2811274C1 (ru) Способ каталитического крекинга
EP0232259B1 (fr) Procede et appareil de craquage des huiles residuaires

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

AK Designated contracting states

Kind code of ref document: A1

Designated state(s): DE FR GB IT NL

17P Request for examination filed

Effective date: 19900907

17Q First examination report despatched

Effective date: 19910628

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

ITF It: translation for a ep patent filed

Owner name: BARZANO' E ZANARDO MILANO S.P.A.

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): DE FR GB IT NL

REF Corresponds to:

Ref document number: 69007649

Country of ref document: DE

Date of ref document: 19940505

ET Fr: translation filed
PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: FR

Payment date: 19941229

Year of fee payment: 6

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: GB

Payment date: 19950124

Year of fee payment: 6

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: DE

Payment date: 19950127

Year of fee payment: 6

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: NL

Payment date: 19950131

Year of fee payment: 6

PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

26N No opposition filed
PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: GB

Effective date: 19960131

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: NL

Effective date: 19960801

GBPC Gb: european patent ceased through non-payment of renewal fee

Effective date: 19960131

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: FR

Effective date: 19960930

NLV4 Nl: lapsed or anulled due to non-payment of the annual fee

Effective date: 19960801

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: DE

Effective date: 19961001

REG Reference to a national code

Ref country code: FR

Ref legal event code: ST

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IT

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20050131