Abstract: A process for upgrading a hydrocarbon-based composition that includes combining a supercritical water stream, a hydrogen stream, and a pressurized, heated hydrocarbon-based composition in a mixing device to create a combined feed stream. The process further includes introducing the combined feed stream into a supercritical water hydrogenation reactor operating at a temperature greater than a critical temperature of water and a pressure greater than a critical pressure of water, and at least partially converting the combined feed stream to an upgraded product.

Abstract: A process for treating a disulfide oil composition that includes combining a supercritical water stream, a hydrogen stream, and a disulfide oil composition in a mixing device to create a combined disulfide feed stream; introducing the combined disulfide feed stream into a supercritical water hydrogenation reactor operating at a temperature greater than a critical temperature of water and a pressure greater than a critical pressure of water; and at least partially converting the combined disulfide feed stream to an upgraded disulfide product.

Abstract: Embodiments of the disclosure provide a system and method for producing a linear alpha olefin. A disulfide, a hydrogen donating compound, and water are combined to produce a mixture. The mixture is introduced to a reactor operated at a pressure equal to or greater than 22.06 MPa and a temperature equal to or greater than 374 deg. C. to produce an effluent stream. The effluent stream is separated to produce a product stream including the linear alpha olefin. The disulfide can be a compound of formula R—S—S—R? where R is a first alkyl group having carbon atoms ranging from 1 to 12 and R? is a second alkyl group having carbon atoms ranging from 5 to 12. The hydrogen donating compound can include a partially hydrogenated multi-ring aromatic compound.

Abstract: The present subject matter describes a method and apparatus for operating a delayed coker. The method comprises contacting a vapour produced in a delayed coker-drum with a catalyst maintained in form of a bed, and maintaining a level of said catalyst-bed within pre-defined limits during catalytic-cracking of the vapour. Thereafter, the cracked-vapour is routed to a coker-fractionator column to trigger conversion into one or more hydrocarbon products.

Abstract: Disclosed is a process for the upgrading and demetallizing of heavy oils and bitumens. A crude heavy oil and/or bitumen feed is supplied to a solvent extraction process 104 wherein DAO and asphaltenes are separated. The DAO is supplied to an FCC unit 106 having a low conversion activity catalyst for the removal of metals contained therein. The demetallized distillate fraction is supplied to a hydrotreater 110 for upgrading and collected as a synthetic crude product stream. The asphaltene fraction can be supplied to a gasifier 108 for the recovery of power, steam and hydrogen, which can be supplied to the hydrotreater 110 or otherwise within the process or exported. An optional coker unit 234 can be used to convert excess asphaltenes and/or decant oil to naphtha, distillate and gas oil, which can be supplied to the hydrotreater 220.

Abstract: A hydrocarbon feedstock upgrading method is provided. The method includes supplying the hydrocarbon feedstock, water and a pre-heated hydrogen donating composition to a hydrothermal reactor where the mixed stream is maintained at a temperature and pressure greater than the critical temperatures and pressure of water in the absence of catalyst for a residence time sufficient to convert the mixed stream into a modified stream. The hydrogen donating composition is pre-heated and maintained at a temperature of greater than about 50° C. for a period of at least about 10 minutes. The modified stream includes upgraded hydrocarbons relative to the hydrocarbon feedstock. The modified stream is then separated into a gas stream and a liquid stream and the liquid stream is separated into a water stream and an upgraded hydrocarbon product stream.

Abstract: A delayed coking process includes: a. introducing a fresh hydrocarbon feedstock containing undesirable sulfur and/or nitrogen compounds for preheating into the lower portion of a coking unit product fractionator; b. introducing at least a portion of an intermediate fraction derived from the fractionator and at least one adsorbent material that selectively adsorbs sulfur- and/or nitrogen-containing compounds into a mixing zone to form an adsorbent slurry stream; c. discharging a bottoms fraction from the fractionator; d. adding all or a portion of the slurry stream to the bottoms fraction to form a mixed coking unit feedstream; e. heating the mixed feedstream in the coking unit furnace to a predetermined coking temperature; and f. passing the heated mixed feedstream to a drum of the delayed coking to produce a delayed coking product stream while depositing the adsorbent material having adsorbed sulfur and/or nitrogen compounds with the coke in the coking drum.

Abstract: Undesirable components of traditional coking processes are selectively cracked or coked in the coking vessel by injecting an additive into the vapors in the coking vessel. The additive contains catalyst(s), seeding agent(s), excess reactant(s), quenching agent(s), carrier(s), or any combination thereof to modify reaction kinetics to preferentially crack (or coke) these undesirable components that typically have a high propensity to coke, and are often precursors to coke in the coking process. These undesirable components can also be very problematic in downstream catalytic cracking processes, significantly contributing to coke on catalyst and catalyst deactivation. Exemplary embodiments of the present invention also provide methods to (1) decrease coke production, (2) increase liquid transportation fuels, (3) control the coke crystalline structure, and (4) control the quantity and quality of volatile combustible materials (VCMs) in the resulting coke.

Abstract: The process relates to the use of any naphtha-range stream containing a portion of C8+ aromatics combined with benzene, toluene, and other non-aromatics in the same boiling range to produce toluene. By feeding the A8+ containing stream to a dealkylation/transalkylation/cracking reactor to increase the concentration of toluene in the stream, a more suitable feedstock for the methylation reaction can be produced. This stream can be obtained from a variety of sources, including the pygas stream from a steam cracker, “cat naphtha” from a fluid catalytic cracker, or the heavier portion of reformate.

Abstract: Disclosed is a method of manufacturing high quality lube base oil (Group III) from unconverted oil having various properties obtained in a variety of hydrocrackers using improved catalytic dewaxing and hydrofinishing, the method including producing unconverted oil of at least one kind in the same or different hydrocrackers; subjecting the unconverted oil to vacuum distillation; supplying all or part of the distillate fractions to a catalytic dewaxing reactor; supplying the dewaxed oil fraction to a hydrofinishing reactor; and stripping the hydrofinished light oil fraction, wherein make-up hydrogen is supplied upstream of the hydrofinishing reactor to increase hydrogen partial pressure, thereby enabling high quality base oil to be manufactured at high yield under optimal process conditions using unconverted oil produced by hydrocracking under various conditions.

Abstract: Systems and methods are provided for use of coking and slurry hydroconversion for conversion of heavy oil feeds. The combination of coking and slurry hydroconversion allows for improved yield of liquid products while reducing or minimizing the consumption of hydrogen in slurry hydroconversion reaction stages. Coking and slurry hydroconversion can be combined by segregating feeds based on Conradson carbon residue. Alternatively, slurry hydroconversion can be used to process unconverted bottoms from a coking process.

Abstract: Heavy gas oil components, coking process recycle, and heavier hydrocarbons in the delayed coking process are cracked in the coking vessel by injecting a catalytic additive into the vapors above the gas/liquid-solid interface in the coke drum during the coking cycle. The additive comprises cracking catalyst(s) and quenching agent(s), alone or in combination with seeding agent(s), excess reactant(s), carrier fluid(s), or any combination thereof to modify reaction kinetics to preferentially crack these components. The quenching effect of the additive can be effectively used to condense the highest boiling point compounds of the traditional recycle onto the catalyst(s), thereby focusing the catalyst exposure to these target reactants. Exemplary embodiments of the present invention can also provide methods to (1) reduce coke production, (2) reduce fuel gas production, and (3) increase liquids production.

Abstract: A process for upgrading unconventional or heavy oils such as, tar sands, shale oil, or bitumen. This process may include a coking scheme in which oil-containing solids, of suitable size, are fed directly into the riser of an FCC unit. Contacting a hot stream of solids causes vaporization and produces a gaseous product stream. The gaseous product may be separated out in a separating vessel and coked or unconverted oil-containing solids may be transferred to a gasifier for combustion at high temperatures to remove the coke and residual oil. Syngas from the gasifier may be converted to hydrogen using a water gas shift reaction. The hydrogen may be used for hydroprocessing.

Abstract: A reactor process added to a coking process to modify the quantity or yield of a coking process product and/or modify certain characteristics or properties of coking process products.

Abstract: Undesirable gas oil components are selectively cracked or coked in a coking vessel by injecting an additive into the vapors of traditional coking processes in the coking vessel prior to fractionation. The additive contains catalyst(s), seeding agent(s), excess reactant(s), quenching agent(s), carrier(s), or any combination thereof to modify reaction kinetics to preferentially crack or coke these undesirable components that typically have a high propensity to coke. Exemplary embodiments of the present invention also provide methods to control the (1) coke crystalline structure and (2) the quantity and quality of volatile combustible materials (VCMs) in the resulting coke. That is, by varying the quantity and quality of the catalyst, seeding agent, and/or excess reactant the process may affect the quality and quantity of the coke produced, particularly with respect to the crystalline structure (or morphology) of the coke and the quantity & quality of the VCMs in the coke.

Abstract: Heavy gas oil components, coking process recycle, and heavier hydrocarbons in the delayed coking process are cracked in the coking vessel by injecting a catalytic additive into the vapors above the gas/liquid-solid interface in the coke drum during the coking cycle. The additive comprises cracking catalyst(s) and quenching agent(s), alone or in combination with seeding agent(s), excess reactant(s), carrier fluid(s), or any combination thereof to modify reaction kinetics to preferentially crack these components. The quenching effect of the additive can be effectively used to condense the highest boiling point compounds of the traditional recycle onto the catalyst(s), thereby focusing the catalyst exposure to these target reactants. Exemplary embodiments of the present invention can also provide methods to (1) reduce coke production, (2) reduce fuel gas production, and (3) increase liquids production.

Abstract: A delayed coking process includes: a. introducing a fresh hydrocarbon feedstock containing undesirable sulfur and/or nitrogen compounds for preheating into the lower portion of a coking unit product fractionator; b. introducing at least a portion of an intermediate fraction derived from the fractionator and at least one adsorbent material that selectively adsorbs sulfur- and/or nitrogen-containing compounds into a mixing zone to form an adsorbent slurry stream; c. discharging a bottoms fraction from the fractionator; d. adding all or a portion of the slurry stream to the bottoms fraction to form a mixed coking unit feedstream; e. heating the mixed feedstream in the coking unit furnace to a predetermined coking temperature; and f. passing the heated mixed feedstream to a drum of the delayed coking to produce a delayed coking product stream while depositing the adsorbent material having adsorbed sulfur and/or nitrogen compounds with the coke in the coking drum.

Abstract: Gas oil components, coking process recycle, and heavier hydrocarbons are cracked or coked in the coking vessel by injecting an additive into the vapors of traditional coking processes in the coking vessel. The additive contains catalyst(s), seeding agent(s), excess reactant(s), quenching agent(s), carrier(s), or any combination thereof to modify reaction kinetics to preferentially crack or coke these components. Modifications of the catalysts in the additive improve performance for certain desired outcomes. One exemplary embodiment of the present invention uses the olefin production capabilities from newly developed catalysts to increase the production of light olefins (e.g. ethylene, propylenes, butylenes, pentenes) for alkylation process unit feed, the production of oxygenates, and petrochemical feedstocks, such as plastics manufacture. Another exemplary embodiment of the present invention is the use of the olefin production from newly developed catalysts to improve the coker naphtha quality.

Abstract: Process for the production of a hydrocarbon fraction with a high octane number and a low sulfur content from a hydrocarbon feedstock, comprising at least the following stages: 1) a hydrodesulfurization stage of the hydrocarbon feedstock, and 2) at least one stage for extracting aromatic compounds on all or part of the effluent that is obtained from the hydrodesulfurization stage, whereby said extraction leads to a paraffin-enriched raffinate and an aromatic compound-enriched extract sent to a gasoline pool to improve its octane number, wherein a portion of the paraffinic raffinate can be used in a mixture with the aromatic extract; another portion can be used as a petrochemistry base either for producing aromatic compounds or for producing olefins.

Abstract: A reactor process added to a coking process to modify the quantity or yield of a coking process product and/or modify certain characteristics or properties of coking process products.

Abstract: The invention relates to materials used as electrodes and/or catalysts, as well as methods associated with the same. The materials may comprise an alloy or intermetallic compound of a transition metal (e.g., Ni) and a metal additive (e.g., Sn). The transition metal and additive are selected to provide improved electrode and/or catalytic performance. For example, the materials of the invention may have a high catalytic activity, while being less susceptible to coking than certain conventional electrode/catalytic materials. These performance advantages can simplify the equipment used in certain applications, as well as reducing energy and capital requirements. Furthermore, the materials may be manufactured using traditional ceramic processing methods, without the need for complex, unconventional fabrication techniques. The materials are particularly suitable for use in fuel cells (e.g., SOFCs electrodes) and in reactions that use or produce synthesis gas.

Abstract: The present invention relates to an improved delayed coking process. A coker feed, such as a vacuum resid, is treated with (i) a metal-containing agent and (ii) an oxidizing agent. The feed is treated with the oxidizing agent at an oxidizing temperature. The oxidized feed is then pre-heated to coking temperatures and conducted to a coking vessel for a coking time to allow volatiles to evolve and to produce a substantially free-flowing coke. A metals-containing composition is added to the feed at at least one of the following points in the process: prior to the heating of the feed to coking temperatures, during such heating, and/or after such heating.

Abstract: A process is provided for producing petroleum coke that is high in strength and sufficiently small in thermal expansion coefficient and sufficiently suppressed from puffing. The process includes coking a feedstock containing a first heavy oil having a sulfur content of 1.0 percent by mass or less, a nitrogen content of 0.5 percent by mass or less, and an aromatic index of 0.1 or greater, produced by hydrodesulfurizing a heavy oil with a sulfur content of 1 percent by mass or more under conditions (1) where the total pressure is 10 MPa or greater and less than 16 MPa and the hydrogen partial pressure is 5 MPa or greater and 16 MPa or less or conditions (2) where the total pressure is 20 MPa or greater and 25 MPa or less and the hydrogen partial pressure is greater than 20 MPa and 25 MPa or less, and a second heavy oil with an aromatic index of 0.3 or greater and an initial boiling point of 150° C. or higher.

Abstract: A hydrocarbon feedstock upgrading method is provided. The method includes supplying the hydrocarbon feedstock, water and a pre-heated hydrogen donating composition to a hydrothermal reactor where the mixed stream is maintained at a temperature and pressure greater than the critical temperatures and pressure of water in the absence of catalyst for a residence time sufficient to convert the mixed stream into a modified stream. The hydrogen donating composition is pre-heated and maintained at a temperature of greater than about 50° C. for a period of at least about 10 minutes. The modified stream includes upgraded hydrocarbons relative to the hydrocarbon feedstock. The modified stream is then separated into a gas stream and a liquid stream and the liquid stream is separated into a water stream and an upgraded hydrocarbon product stream.

Abstract: A method for recovering NH3 present in a sour water stream containing odiferous compounds such as pyridines, indoles, ketones and mercaptans produced during an upgrading process for upgrading bitumen from oil sands into synthetic crude comprising treating the sour water stream in a sour water treatment unit to produce a NH3-rich stream and a H2S-rich stream; and hydrotreating the NH3-rich stream in a hydrotreater in the presence of hydrogen to remove the odiferous compounds such as pyridines, indoles, ketones and mercaptans and produce a treated NH3-rich stream.

Abstract: A process for upgrading unconventional or heavy oils such as, tar sands, shale oil, or bitumen. This process may include a coking scheme in which oil-containing solids, of suitable size, are fed directly into the riser of an FCC unit. Contacting a hot stream of solids causes vaporization and produces a gaseous product stream. The gaseous product may be separated out in a separating vessel and coked or unconverted oil-containing solids may be transferred to a gasifier for combustion at high temperatures to remove the coke and residual oil. Syngas from the gasifier may be converted to hydrogen using a water gas shift reaction. The hydrogen may be used for hydroprocessing.

Abstract: A method for thermally cracking a hydrocarbonaceous feed wherein the feed is first processed in an atmospheric thermal distillation step to form a light gasoline and atmospheric residuum mixture. The light gasoline/residuum combination is gasified at least in part in a vaporization step, and the gasified product of the vaporization step is thermally cracked.

Abstract: An improved fluidized coking process wherein an effective amount of a basic material, preferably an alkali or alkaline-earth metal-containing compound, is added to the coking zone to mitigate agglomeration of the coke during the coking of a heavy hydrocarbonaceous feedstock to produce lower boiling products.

Abstract: In an embodiment, the invention relates to a method for reducing coke agglomeration in petroleum streams derived from coking processes. In a preferred embodiment, the invention relates to a method for mitigating filter fouling from a coker gas oil by using a pusher gas substantially free of molecular oxygen.

Abstract: In an embodiment, the invention relates to a method for reducing coke agglomeration in petroleum streams derived from coking processes. In a preferred embodiment, the invention relates to a method for mitigating filter fouling from a coker gas oil wherein an oxygen scavenger is employed to remove molecular oxygen and peroxides.

Abstract: The process has to do with a circuit involving a fluidized bed coker reactor working in tandem with a fluidized bed coke burner. The burner is operated at a reduced temperature in the range 550° C.-630° C. Simultaneously, the coke circulation rate is increased to ensure the heat requirement of the reactor is met. It is found that sulphur emissions from the burner are significantly reduced.

Abstract: A process for producing normally gaseous olefins from two different process units sharing common downstream quench and fractionation facilities, wherein one of the process units is a short contact time mechanically fluidized vaporization unit for processing petroleum residual feedstocks and the other is a conventional steam cracking unit.

Abstract: The invention relates to a process for recycling waste which consists essentially of one or more plastics comprising polyvinyl chloride (PVC), in which:the waste is mixed with a heavy oil, in a reactor under an inert atmosphere, at an internal temperature of at least 300.degree. C., and the hydrogen chloride (HCl) which is evolved is collected;the contents of the reactor are then cracked at a temperature of at least 400.degree. C., and at least part of the gases which are evolved are extracted from the reactor;the contents of the reactor are then cooled and the residual solid product is collected.HCl, coke, hydrocarbon gases and various oils are thus mainly obtained.

Abstract: An improved fluidized bed coking process wherein a residuum feedstock is introduced into a first stage comprised of a short vapor contact time reactor containing a horizontal moving bed of fluidized hot particles. Carbonaceous material is deposited onto the hot particles on contact with the hot particles, and a vapor product is produced. The hot particles, containing the carbonaceous deposits, are fed to a second stage fluidized bed coking process.

Abstract: The present invention relates to an integrated fluid coking/hydrogen production process. The fluid coking unit is comprised of a fluid coker reactor, a heater, and a gasifier. Solids from the fluidized beds are recycled between the coking zone and the heater and between the heater and the gasifier. A separate stream of hot solids from the gasifier is passed to the scrubbing zone of the reactor. Methane and steam are introduced into the stream of hot solids passing from the gasifier to the scrubbing zone. The hot particles act to catalyze the conversion of methane to carbon monoxide and hydrogen in the presence of steam.

Abstract: The air reactivity of calcined petroleum coke is reduced by maintaining the amount of sodium in at least a portion of the water streams contacting the petroleum coke at a value below about 100 parts per million.

Abstract: The present invention relates to an integrated fluid coking/paraffin dehydrogenation process. The fluid coking unit is comprised of a fluid coker reactor, a heater, and a gasifier. Solids from the fluidized beds are recycled between the coking zone and the heater and between the heater and the gasifier. A separate stream of hot solids from the gasifier is passed to a satellite reactor. A light paraffin stream is introduced into directly into this stream of hot solids passing to the satellite reactor or into the satellite reactor. The hot particles act to catalyze the dehydrogenation of the paraffins to olefins.

Abstract: An integrated fluid coking/paraffin dehydrogenation process. The fluid coking unit is comprised of a fluid coker reactor, a heater, and a gasifier. Solids from the fluidized beds are recycled between the coking zone and the heater and between the heater and the gasifier. A separate stream of hot solids from the gasifier is passed to the scrubbing zone after first being reduced in temperature by introduction of an effective amount of diluent, such as steam. A light paraffin stream is introduced into this stream of hot solids between the point where the diluent is added and the scrubbing zone. The hot particles act to catalyze the dehydrogenation of paraffins to olefins.

Abstract: An integrated fluid coking/paraffin dehydrogenation process. The fluid coking unit is comprised of a fluid coker reactor, a heater, and a gasifier. Solids from the fluidized beds are recycled between the coking zone and the heater and between the heater and the gasifier. A separate stream of hot solids from the gasifier is passed to the scrubbing zone or to a satellite fluidized reactor. A first stream containing an effective amount of C.sub.1 to C.sub.2 paraffins is introduced into this stream of hot solids between the point where the diluent is added and the scrubbing zone. The hot particles act to catalyze the dehydrogenation of paraffins to olefins. A second stream containing C.sub.3 to C.sub.10 paraffins is introduced downstream of the introduction of said first stream.

Abstract: An integrated fluid coking/paraffin dehydrogenation process. The fluid coking unit is comprised of a fluid coker reactor, a heater, and a gasifier. Solids from the fluidized beds are recycled between the coking zone and the heater and between the heater and the gasifier. A separate stream of hot solids from the gasifier is diluted with hot solids from the heater then passed to the scrubbing zone of the coker reactor. A light paraffin stream is introduced into this stream of hot solids between the point where the heater solids are introduced and the scrubbing zone. The hot particles act to catalyze the dehydrogenation of the paraffins to olefins.

Abstract: A hydrocarbonaceous feed, such as petroleum vacuum distillation bottoms, is upgraded by a combination coking and catalytic slurry hydroconversion process wherein a bottoms fraction from coking is passed to a slurry hydroconversion zone, and the bottoms fraction from the slurry hydroconversion zone is also passed thorugh a microfiltration system to remove catalyst particles.

Abstract: Delayed coking process in which improved liquid yield is achieved by varying the rate at which the heavy feedstock is fed to the coke drum. Tandem operation of two active coking drums is disclosed which permits feedrate variation without change of load on furnace.

Abstract: Synthesis gas is produced by the partial oxidation of a feedstock comprising petroleum coke containing metal sulfide compounds and metal oxy-sulfide compounds and having an ash that contains nickel, vanadium and silicon. In the process, a petroleum coke addition agent, such as elemental iron and/or iron compounds, is introduced into the upper section of a delayed coker and above the level of the nickel and vanadium ash-containing heavy liquid hydrocarbonaceous fuel being simultaneously introduced upwardly from the bottom of said delayed coker. By this means the petroleum coke addition agent is distributed uniformly across the surface of liquid hydrocarbonaceous material being coked and then uniformly distributed throughout the liquid fuel. In the delayed coker, a portion of the petroleum coke addition agent is reacted with a portion of the sulfur in the heavy liquid hydrocarbonaceous fuel to produce metal oxy-sulfides and metal sulfides.

Abstract: A carbonaceous feed, such as a heavy hydrocarbonaceous oil or coal and mixtures thereof, is upgraded by a combination coking and catalytic slurry hydroconversion process which may be integrated with a deasphalting process.

Abstract: This invention relates to a process for hydroconverting a hydrocarbon chargestock having the steps of: heating the chargestock to produce a minor amount of coke; contacting the coke within the chargestock with a minor effective amount of an oil-soluble metal compound, the metal being selected from the group consisting of Groups IV-B, V-B, VI-B, VII-B, and VIII of the Periodic Table of Elements, and mixtures thereof; contacting the metal compound and the coke within the chargestock with a hydrogen-containing gas under conditions to produce a solid catalyst within the chargestock capable of promoting hydroconversion of at least a portion of the chargestock; contacting the chargestock containing the catalyst with hydrogen under hydroconversion conditions; and recovering a hydroconverted substantially-hydrocarbon product.

Abstract: A carbonaceous feed, such as a heavy hydrocarbonaceous oil or coal and mixtures thereof, is upgraded by a combination coking and catalytic slurry hydroconversion process.

Abstract: A carbonaceous feed, such as a heavy hydrocarbonaceous oil or coal, and mixtures thereof, is upgraded by a combination coking and catalytic slurry hydroconversion process in which a catalyst precursor is added to the feed of the hydroconversion zone as a catalyst precursor concentrate prepared from a virgin hydrocarbonaceous oil and a thermally decomposable or oil dispersible metal compound.

Abstract: Arsenic is removed from green shale oil coke of high arsenic content by calcining the coke at 1500.degree. F. to 3000.degree. F. for 0.1 hr to 4 hr. The arsenic content is reduced from above about 150 to 300 ppm to below about 100 ppm, thereby making the coke suitable for use as a fuel, in electrodes for producing aluminum, or in steel making.

Abstract: A heavy high-sulfur hydrocarbonaceous feedstock is partially delayed coked and partially formcoked. The coke products are screened, with larger particles being calcined at desulfurizing temperatures and smaller particles being recycled to the formcoker. Overhead products from both coking operations are combined, fractionated, and desulfurized. The heaviest cut from the fractionator is combined with the feedstock as recycle.

Abstract: An integrated fluid coking and gasification process is provided in which a solid cracking catalyst is added to the coker chargestock and in which a partially gasified coke matrix comprising the cracking catalyst is recycled to the coker vapor phase product.