Multi-zone catalytic cracking of crude oil

Abstract

A method of treating a hydrocarbon feed can include fractionating the hydrocarbon feed into a light stream and a heavy stream, where the light stream includes hydrocarbons boiling at less than 370 DEG C and the heavy stream includes hydrocarbons boiling at greater than 370 DEG C, hydrotreating the heavy stream to form a hydrotreated heavy stream, feeding the light stream to a first fluidized catalytic cracking (FCC) reaction zone, and feeding the hydrotreated heavy stream to a second fluidized catalytic cracking (FCC) reaction zone. The method includes feeding a hydrotreated heavy stream to a first fluidized catalytic cracking (FCC) reaction zone to produce a light product stream comprising light olefins, and feeding the hydrotreated heavy stream to a second FCC reaction zone to produce a heavy product stream comprising light olefins, where the first FCC reaction zone operates under more harsh operating conditions than the second FCC reaction zone.

Description

[0001] CROSS-REFERENCE TO RELATED APPLICATIONS

[0002] This application claims priority to U.S. patent application No. 18 / 163,390, filed on February 2, 2023, entitled “Multi-Zone Catalytic Cracking of Crude Oil,” the entire contents of which are incorporated herein by reference. Technical Field

[0003] The present disclosure relates to processes for processing petroleum-based materials, particularly processes for cracking hydrocarbon feeds to produce light olefins. Background Art

[0004] The growing global demand for light chemical intermediates remains a major challenge for many integrated refineries. In particular, the production of valuable light olefins, such as ethylene and propylene, has attracted increasing attention, as pure olefin streams are considered building blocks for polymer synthesis. The production of light olefins depends on several process variables, such as feed type, operating conditions, and catalyst type. Although there are options available for producing higher yields of propylene and light olefins, considerable research activity in this area is still ongoing.

[0005] Light olefins are generally produced by thermal cracking (or steam cracking) of petroleum gas and distillates (such as naphtha, kerosene or gas oil). Light olefins can also be produced by fluid catalytic cracking processes. Typically, hydrocarbon feeds for fluid catalytic cracking processes range from hydrocracked bottoms to heavy feed fractions (such as vacuum gas oil and atmospheric residue); however, the supply of these hydrocarbon feeds is limited, at least in part due to limitations of standard fluid catalytic cracking processes. Summary of the Invention

[0006] Therefore, there is a continuing need for an integrated process capable of producing intermediate compounds from available hydrocarbon feeds, such as crude oil. The method of the present disclosure comprises fractionating the hydrocarbon feed into a plurality of streams, contacting one of the streams with one or more hydrotreating catalysts to form a hydrotreated effluent. The method of the present disclosure further comprises contacting the hydrotreated effluent and the other streams with a fluid catalytic cracking (FCC) catalyst composition. In particular, the method of the present disclosure comprises: fractionating the hydrocarbon feed into a light stream and a heavy stream; hydrotreating the heavy stream; and introducing the light stream and the hydrotreated heavy stream into separate fluid catalytic cracking units (FCCs). The light stream and the hydrotreated heavy stream can then be exposed to different severities within their respective FCCs, as appropriate for their respective compositions.

[0007] According to at least one embodiment of the present disclosure, a method for processing a hydrocarbon feed may include: fractionating the hydrocarbon feed into a light stream and a heavy stream; hydrotreating the heavy stream to form a hydrotreated heavy stream; feeding the light stream to a first fluid catalytic cracking (FCC) reaction zone to produce a light product stream comprising light olefins; and feeding the hydrotreated heavy stream to a second fluid catalytic cracking (FCC) reaction zone to produce a heavy product stream comprising light olefins. The light stream may include hydrocarbons boiling at less than 370° C., and the heavy stream includes hydrocarbons boiling at greater than 370° C. The first FCC reaction zone may operate at more severe operating conditions than the second FCC reaction zone.

[0008] Additional features and advantages of the embodiments of the present disclosure will be set forth in the detailed description that follows, and in part will be readily apparent to those skilled in the art from the detailed description or learned by practicing the embodiments of the present disclosure.

[0009] BRIEF DESCRIPTION OF THE DRAWINGS

[0010] The following detailed description of the present disclosure may be better understood when read in conjunction with the following drawings, in which:

[0011] Figure 1 A generalized flow diagram of a system for converting a hydrocarbon feed to produce olefins according to one or more aspects of the present disclosure is schematically depicted.

[0012] When describing Figure 1 The simplified schematic diagram does not include many valves, temperature sensors, electronic controllers, etc. that may be used and are familiar to those of ordinary skill in the art. In addition, it does not include the Figure 1 Accompanying components in those systems are shown, such as air supply, heat exchangers, surge tanks, etc. However, one of ordinary skill in the art understands that these components are within the scope of the present disclosure.

[0013] Reference will now be made in detail to various aspects, some of which are illustrated in the accompanying drawings. DETAILED DESCRIPTION

[0014] The present disclosure relates to methods and catalysts for upgrading hydrocarbon feeds, such as crude oil, to produce higher value chemical products and intermediates, such as, but not limited to, light olefins, aromatic compounds, and combinations thereof, by hydrotreating and fluid catalytic cracking (FCC). The methods and FCC catalyst compositions of the present disclosure enable efficient cracking of feed streams, such as those comprising crude oil, by utilizing the different severities required to crack each stream and by hydrotreating the heavier streams.

[0015] definition

[0016] As used in this disclosure, the term "API" refers to the American Petroleum Institute.

[0017] As used in this disclosure, the term "ASTM" refers to the American Society for Testing and Materials.

[0018] As used in this disclosure, the term "cracking" refers to a chemical reaction in which a molecule having carbon-carbon bonds is broken into more than one molecule by breaking one or more carbon-carbon bonds; in which a compound including a cyclic moiety (such as an aromatic hydrocarbon) is converted into a compound that does not include a cyclic moiety; or in which a molecule having a carbon-carbon double bond is reduced to a carbon-carbon single bond. As used in this disclosure, the term "catalytic cracking" refers to cracking performed in the presence of a catalyst. Some catalysts can have multiple forms of catalytic activity, and invoking a catalyst by one specific function does not render the catalyst inactive for other functions.

[0019] As used in this disclosure, the term "catalyst" refers to any substance that increases the rate of a particular chemical reaction, such as a cracking reaction.

[0020] As used herein, "coke" refers to the solid residue produced when hydrocarbons undergo severe oxidation and thermal decomposition. Coke may be deposited on the catalyst, reactor surfaces, or both. In either location, coke can contaminate the surface, hinder the reaction, and require costly removal.

[0021] As used in this disclosure, the term "crude oil" refers to a mixture of petroleum liquids and gases, including impurities, such as sulfur-containing compounds, nitrogen-containing compounds, and metallic compounds, that is extracted directly from an underground formation or received from a desalting unit, without having any fractions separated by distillation, such as naphtha.

[0022] As used in this disclosure, the term "directly" refers to the delivery of a material (such as an effluent) from a first component of a system to a second component of the system without passing the material through any intermediate component or system that is operable to change the composition of the material. Similarly, the term "directly" also refers to the introduction of a material (such as a feed) into a component of a system without passing the material through any preliminary component that is operable to change the composition of the material. Intermediate or preliminary components or systems that are operable to change the composition of the material may include reactors and separators, but are generally not intended to include heat exchangers, valves, pumps, sensors, or other auxiliary components required to operate a chemical process. In addition, merging two streams together upstream of a second component, rather than delivering each stream separately to the second component, is not considered an intermediate or preliminary component that is operable to change the composition of the material.

[0023] As used in this disclosure, the terms "downstream" and "upstream" refer to the positioning of a component or system relative to the direction of material flow through the system. For example, if material flowing through a system encounters a first component before encountering a second component, the second component can be considered "downstream" of the first component. Similarly, if material flowing through a system encounters the first component before encountering the second component, the first component can be considered "upstream" of the second component.

[0024] As used in this disclosure, the term "effluent" refers to the stream delivered from a reactor, reaction zone or separator after a specific reaction or separation. Typically, the effluent has a composition different from the stream entering the reactor, reaction zone or separator. It should be understood that when the effluent is delivered to another component or system, only a portion of the effluent can be delivered. For example, a tail stream may take away some effluent, which means that only a portion of the effluent can enter a downstream component or system. The terms "reaction effluent" and "reactor effluent" particularly refer to the stream delivered from a reactor or reaction zone.

[0025] As used in this disclosure, the term "high severity conditions" refers to operating conditions of a fluid catalytic cracking system (FCC), which include a temperature greater than or equal to 580°C or from 580°C to 750°C, a catalyst to oil ratio greater than or equal to 1:1 or from 1:1 to 60:1, and a residence time less than or equal to 60 seconds or from 0.1 seconds to 60 seconds, each of which may be more severe than typical operating conditions of a fluid catalytic cracking system.

[0026] As used in this disclosure, the term "catalyst to oil ratio" or "CTO weight ratio" refers to the weight ratio of catalyst to a process stream comprising hydrocarbons.

[0027] The term "residence time" refers to the amount of time that the reactants are in contact with the catalyst under reaction conditions, such as at the reaction temperature.

[0028] As used in this disclosure, the term "reactor" refers to any vessel, container, conduit, etc., in which a chemical reaction (such as catalytic cracking) occurs between one or more reactants, optionally in the presence of one or more catalysts. A reactor may include one or more "reaction zones" disposed within the reactor. The term "reaction zone" refers to an area of ​​a reactor where a specific reaction occurs.

[0029] As used in this disclosure, the terms "separation unit" and "separator" refer to any separation device that at least partially separates one or more chemical components in a mixture from one another. For example, a separation system selectively separates different chemical components from one another to form one or more chemical fractions. Examples of separation systems include, but are not limited to, a distillation column, a fractionator, a flash tank, a knockout drum, a knockout drum, a centrifuge, a filter unit, a collector, a scrubber, an expansion unit, a membrane, a solvent extraction unit, a high-pressure separator, a low-pressure separator, or a combination of these. The separation methods described in this disclosure may not completely separate all of one chemical component from all of another chemical component. Rather, the separation methods described in this disclosure "at least partially" separate different chemical components from one another, and separation may include only partial separation even if not explicitly stated.

[0030] As used herein, the term "light olefin" refers to an olefin having 2 to 4 carbon atoms (containing at least one double bond), such as an olefin having 2, 3, or 4 carbon atoms. For example, light olefins may include ethylene, propylene, isopropylene, and butene.

[0031] It should be further understood that a stream can be named according to a component of the stream, and the component used to name the stream can be the major component of the stream (e.g., comprising from 50%, 70%, 90%, 95%, 99%, 99.5%, or 99.9% by weight of the contents of the stream to 100% by weight of the contents of the stream). It should also be understood that when a stream comprising a component is disclosed as being delivered from one system component to another system component, the component of the stream is disclosed as being delivered from that system component to the other system component. For example, a disclosed "heavy oil stream" being delivered to a first system component or from a first system component to a second system component should be understood to equivalently disclose the delivery of "heavy oil" to the first system component or from the first system component to the second system component.

[0032] The composition of the feed stream and the processing variables of the FCC system play an important role in the reaction yield and heat balance in the system. Conventional FCC systems and methods may require expensive refining to produce suitable feed streams. This extra expensive refining may include separating and processing one or more fractions of the hydrocarbon feed before the refined conventional feed is introduced into the FCC system. These extra processing steps are energy intensive and have reduced the feasible feed amount from existing hydrocarbon sources. Previous systems and methods that have been developed have directly converted crude oil into more valuable chemical products and intermediates through catalytic cracking in an attempt to overcome these limitations, such as by reducing or eliminating the processing steps required to produce suitable hydrocarbon feed before being introduced into the FCC system. However, pollutants, metals or both present in the heavy hydrocarbon feed (such as crude oil) can deactivate the catalyst, causing a reduction in yield and an increase in production costs.

[0033] Implementation Method

[0034] Thus, embodiments of the present disclosure relate to integrated processes for converting crude oil directly into higher value chemical products and intermediates, such as, but not limited to, olefins and aromatics, through a combination of hydroprocessing and FCC using the reaction configurations described herein.

[0035] Reference Figure 1 , a method 100 for processing a hydrocarbon feed 105 may include fractionating 110 the hydrocarbon feed 105 into a light stream 115 and a heavy stream 120, wherein the light stream 115 comprises hydrocarbons boiling below 370° C. and the heavy stream 120 comprises hydrocarbons boiling above 370° C. The heavy stream 120 may be hydrotreated 125 to form a hydrotreated heavy stream 130. The light stream 115 may be fed to a first FCC reaction zone 135, thereby producing a light product stream 140 comprising light olefins. The hydrotreated heavy stream 130 may be fed to a second FCC reaction zone 145, thereby producing a heavy product stream 150 comprising light olefins. The first FCC reaction zone 135 may be operated at more severe operating conditions than the second FCC reaction zone 145.

[0036] hydrocarbon feed

[0037] The hydrocarbon feed 105 of present method 100 can comprise crude oil, be basically made up of crude oil or be made up of crude oil, and crude oil is such as whole crude oil." crude oil " can be the crude hydrocarbon that has not previously experienced treatment (such as by one or more of distillation, cracking, hydrotreating, desalination or dehydration).In an embodiment, crude oil may have experienced at least some treatments, such as desalination, solid separation, washing or these combinations, but not yet experienced distillation.For example, crude oil may be the desalted crude oil through desalting.In an embodiment, before crude oil is introduced into method 100, crude oil may not be through the operation of pre-treatment, separation (such as distillation) or other hydrocarbon compositions that change crude oil.As used herein, " hydrocarbon composition " of crude oil refers to the composition of the hydrocarbon component of crude oil, does not comprise the non-hydrocarbon solids, salt, water or other non-hydrocarbon components that carry away.

[0038] The hydrocarbon feed 105, such as crude oil, may have an American Petroleum Institute (API) gravity of 25 to 55. For example, the hydrocarbon feed 105 may have an API gravity of 45 to 55, 50 to 52, 25 to 35, 27 to 29, 30 to 32, 32 to 34, 27 to 32, or any subset thereof. At a temperature of 15 degrees Celsius, the hydrocarbon feed 105 may have a density greater than 0.8 grams per milliliter (g / ml), greater than 0.82 g / ml, greater than 0.84 g / ml, 0.86 g / ml, 0.88 g / ml, greater than 0.90 g / ml, greater than 0.91 g / ml, 0.8 g / ml to 1.0 g / ml, 0.84 g / ml to 0.96 g / ml, 0.86 g / ml to 0.93 g / ml, 0.88 g / ml to 0.92 g / ml, 0.9 g / ml to 0.92 g / ml, or any subset thereof. According to some embodiments, the hydrocarbon feed 105 may be Arabian heavy crude oil, Arabian medium crude oil, Arabian light crude oil, or Arabian extra light crude oil.

[0039] The hydrocarbon feed 105 may have an initial boiling point of 30° C. to 50° C. For example, the hydrocarbon feed 105 may have an initial boiling point of 30° C. to 45° C., 30° C. to 40° C., 30° C. to 35° C., 35° C. to 50° C., 40° C. to 50° C., 45° C. to 50° C., or any subset thereof. The initial boiling point may be determined according to standard test method ASTM D7169.

[0040] The hydrocarbon feed 105 may have an end boiling point (also referred to herein as "EBP" and "FBP") greater than 720 degrees Celsius. For example, the hydrocarbon feed 105 may have an end boiling point greater than 740°C, greater than 760°C, greater than 780°C, greater than 800°C, greater than 850°C, greater than 900°C, greater than 950°C, or greater than 1000°C. The hydrocarbon feed 105 may have an end boiling point less than 2000°C, less than 1800°C, less than 1600°C, less than 1400°C, less than 1200°C, less than 1000°C, less than 900°C, less than 800°C, less than 750°C, or any subset thereof. The end boiling point may be determined according to standard test method ASTM D7169.

[0041] At least 50 wt% of the hydrocarbon feed 105 may have a boiling point temperature greater than or equal to 300° C. For example, the hydrocarbon feed 105 may have a 50 wt% boiling point temperature of 300° C. to 500° C., 300° C. to 475° C., 300° C. to 450° C., 300° C. to 425° C., 300° C. to 400° C., 300° C. to 375° C., 350° C. to 500° C., 350° C. to 475° C., 350° C. to 450° C., 350° C. to 425° C., 350° C. to 400° C., 350° C. to 375° C., 375° C. to 500° C., 375° C. to 475° C., 375° C. to 450° C., 375° C. to 425° C., 375° C. to 400° C., or any subset thereof. The 50 wt% boiling point temperature may be determined according to standard test method ASTM D7169.

[0042] The hydrocarbon feed 105 may have a nitrogen concentration of less than or equal to 5,000 parts per million by weight (ppmw). For example, the hydrocarbon feed 105 may have a nitrogen concentration of less than 4,500 ppmw, less than 4,000 ppmw, less than 3,500 ppmw, less than 3,000 ppmw, less than 2,500 ppmw, less than 2,000 ppmw, 1,000 ppmw to 5,000 ppmw, 1,000 ppmw to 4,000 ppmw, 1,000 ppmw to 3,000 ppmw, 1,000 ppmw to 2,000 ppmw, or any subset thereof. The nitrogen concentration of the hydrocarbon feed 105 may be determined according to standard test method ASTM D4629.

[0043] The hydrocarbon feed 105 may have a paraffinic compound concentration of less than 50 wt.% per unit weight of the hydrocarbon feed 105. For example, the hydrocarbon feed 105 may have a paraffinic compound concentration of less than or equal to 40 wt.%, less than or equal to 35 wt.%, less than or equal to 30 wt.%, less than or equal to 25 wt.%, less than or equal to 20 wt.%, less than or equal to 15 wt.%, less than or equal to 10 wt.%, or even less than or equal to 5 wt.% per unit weight of the hydrocarbon feed 105. In an embodiment, the hydrocarbon feed 105 may have a paraffin compound concentration of 5 wt% to less than 50 wt%, 5 wt% to 40 wt%, 5 wt% to 35 wt%, 5 wt% to 30 wt%, 5 wt% to 25 wt%, 5 wt% to 20 wt%, 10 wt% to less than 50 wt%, 10 wt% to 40 wt%, 10 wt% to 35 wt%, 10 wt% to 30 wt%, 10 wt% to 25 wt%, or even 10 wt% to 20 wt% per unit weight of the hydrocarbon feed 105. The paraffin content of the hydrocarbon feed 105 may be determined according to ASTM 5443.

[0044] The hydrocarbon feed 105 may have an aromatics concentration of greater than or equal to 20 wt % per unit weight of the hydrocarbon feed 105. For example, the hydrocarbon feed 105 may have an aromatics concentration of greater than or equal to 30 wt %, greater than or equal to 40 wt %, or even greater than or equal to 50 wt % per unit weight of the hydrocarbon feed 105 as determined according to ASTM 5443. In embodiments, the hydrocarbon feed 105 may have an aromatics concentration of between 20 wt % and 90 wt %, between 20 wt % and 80 wt %, between 20 wt % and 70 wt %, between 30 wt % and 90 wt %, between 30 wt % and 80 wt %, between 30 wt % and 70 wt %, between 40 wt % and 90 wt %, between 40 wt % and 80 wt %, between 40 wt % and 70 wt %, between 50 wt % and 90 wt %, between 50 wt % and 80 wt %, between 50 wt % and 70 wt %, or any subset thereof, per unit weight of the hydrocarbon feed 105.

[0045] The hydrocarbon feed 105 may have a cycloparaffin concentration of greater than or equal to 25 wt% per unit weight of the hydrocarbon feed 105. For example, the hydrocarbon feed 105 may have a cycloparaffin concentration of 25 wt% to 60 wt%, 25 wt% to 50 wt%, 25 wt% to 40 wt%, 25 wt% to 35 wt%, 27 wt% to 60 wt%, 27 wt% to 50 wt%, 27 wt% to 40 wt%, 27 wt% to 35 wt%, or any subset thereof, per unit weight of the hydrocarbon feed 105. The concentration of cycloparaffins may be determined according to ASTM 5443.

[0046] In some embodiments, the hydrocarbon feed 105 may be a topped crude oil. As used herein, the term "topped crude oil" refers to crude oil from which lower boiling components have been removed by distillation, such as components having a boiling temperature below 180° C. or even below 160° C. The hydrocarbon feed 105 may comprise, consist of, or consist essentially of a topped crude oil having greater than or equal to 95%, greater than or equal to 98%, or even greater than or equal to 99% of its components having a boiling temperature greater than or equal to 160° C. or greater than or equal to 180° C., depending on the cut point temperature of the topping unit.

[0047] Fractional distillation

[0048] Fractionating 110 the hydrocarbon feed 105 to produce a light stream 115 and a heavy stream 120 can be performed in any separator. For example, the fractionating 110 step can include, but is not limited to, a distillation column, a fractionator, a flash tank, a knockout drum, a knockout drum, a centrifuge, a filter unit, a collector, a scrubber, an expansion unit, a membrane, a solvent extraction unit, a high pressure separator, a low pressure separator, or a combination of these.

[0049] Light Flow

[0050] Fractionating 110 the hydrocarbon feed 105 may produce a lights stream 115. The lights stream 115 may include hydrocarbons that boil at less than 370° C. Based on the total weight of the hydrocarbons in the lights stream 115, at least 50 wt%, at least 75 wt%, at least 80 wt%, at least 90 wt%, at least 95 wt%, at least 99 wt%, or even at least 99.9 wt% of the hydrocarbons in the lights stream 115 may boil at less than 370° C.

[0051] The light stream 115 may comprise at least 50 wt. % of all hydrocarbons initially boiling at a temperature less than 370° C. in the hydrocarbon feed 105. For example, the light stream 115 may comprise at least 75 wt. %, at least 80 wt. %, at least 90 wt. %, at least 95 wt. %, at least 99 wt. %, or even at least 99.9 wt. % of all hydrocarbons initially boiling at a temperature less than or equal to 370° C. in the hydrocarbon feed 105.

[0052] In some embodiments, the light stream 115 may comprise at least 75 wt%, at least 80 wt%, at least 90 wt%, at least 95 wt%, or at least 99 wt% of all hydrocarbons initially in the hydrocarbon feed 105 having a boiling point of 25°C to 200°C, 35°C to 200°C, or 45°C to 200°C.

[0053] The light stream 115 may comprise less than 5 wt% sulfur based on the total weight of the light stream 115. For example, the light stream 115 may comprise less than 2.5 wt%, less than 1 wt%, less than 0.5 wt%, less than 0.1 wt%, or even less than 0.01 wt% sulfur based on the total weight of the light stream 115.

[0054] Light stream 115 may contain less than 50 ppm nitrogen. For example, light stream 115 may contain less than 25 ppm, less than 15 ppm, less than 10 ppm, or even less than 5 ppm nitrogen.

[0055] The light stream 115 may contain less than 5 ppm nickel. For example, the light stream 115 may contain less than 2.5 ppm, less than 2 ppm, less than 1 ppm, or even less than 0.1 ppm nickel.

[0056] The light stream 115 may contain less than 5 ppm of vanadium. For example, the light stream 115 may contain less than 2.5 ppm, less than 2 ppm, less than 1 ppm, or even less than 0.1 ppm of vanadium.

[0057] The lights stream 115 may comprise from 50 wt% to 99 wt% paraffins based on the total weight of the lights stream 115. For example, the lights stream 115 may comprise from 60 wt% to 90 wt%, from 60 wt% to 80 wt%, from 65 wt% to 75 wt%, from 70 wt% to 75 wt%, or any subset thereof, based on the total weight of the lights stream 115.

[0058] The lights stream 115 may comprise from 1 wt% to 30 wt% cycloalkanes based on the total weight of the lights stream 115. For example, the lights stream 115 may comprise from 5 wt% to 25 wt%, from 10 wt% to 20 wt%, from 12.5 wt% to 17.5 wt%, or any subset thereof, based on the total weight of the lights stream 115.

[0059] The light stream 115 may comprise from 1 wt% to 25 wt% aromatics based on the total weight of the light stream 115. For example, the light stream 115 may comprise from 5 wt% to 20 wt%, from 10 wt% to 15 wt%, or any subset thereof, based on the total weight of the light stream 115.

[0060] Heavy Flow

[0061] Fractionating 110 the hydrocarbon feed 105 may produce a heavy stream 120. The heavy stream 120 may include hydrocarbons boiling above 370° C., such as hydrocarbons boiling between 370° C. and 900° C., between 370° C. and 800° C., between 370° C. and 700° C., between 370° C. and 600° C., or any subset thereof. For example, at least 50%, at least 60%, at least 70%, at least 80%, at least 90%, at least 95%, at least 99%, or even at least 99.9% by weight of the heavy stream 120, based on the total weight of the hydrocarbons in the heavy stream 120, may include hydrocarbons boiling at a temperature of at least 370° C.

[0062] The heavy stream 120 may comprise at least 50 wt.% of all hydrocarbons initially boiling at temperatures greater than 370° C. in the hydrocarbon feed 105. For example, the heavy stream 120 may comprise at least 75 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.%, at least 99 wt.%, or even at least 99.9 wt.% of all hydrocarbons initially boiling at temperatures greater than or equal to 370° C. in the hydrocarbon feed 105.

[0063] The heavy stream 120 may comprise less than 10 wt% sulfur based on the total weight of the heavy stream 120. For example, the heavy stream 120 may comprise less than 7.5 wt%, less than 5 wt%, less than 4 wt%, less than 3 wt%, less than 2.9 wt%, less than 2.8 wt%, less than 2.7 wt%, less than 2.6 wt%, less than 2.5 wt%, between 0.1 wt% and 10 wt%, between 0.5 wt% and 10 wt%, between 1 wt% and 10 wt%, between 2 wt% and 10 wt%, between 2 wt% and 5 wt%, between 2 wt% and 3 wt%, or any subset thereof, based on the total weight of the heavy stream 120.

[0064] The heavy stream 120 may contain less than 7500 ppm nitrogen. For example, the heavy stream 120 may contain less than 5000 ppm, less than 2500 ppm, less than 1500 ppm, less than 1000 ppm, less than 750 ppm, or less than 600 ppm nitrogen.

[0065] The heavy stream 120 may contain less than 500 ppm nickel. For example, the heavy stream 120 may contain less than 250 ppm, less than 10 ppm, less than 50 ppm, less than 25 ppm, less than 20 ppm, less than 15 ppm, less than 10 ppm, less than 5 ppm, less than 2.5 ppm, less than 1 ppm, or even less than 0.1 ppm nickel.

[0066] The heavy stream 120 may contain less than 500 ppm of vanadium. For example, the heavy stream 120 may contain less than 250 ppm, less than 10 ppm, less than 50 ppm, less than 25 ppm, less than 20 ppm, less than 15 ppm, less than 10 ppm, less than 5 ppm, less than 2.5 ppm, less than 1 ppm, or even less than 0.1 ppm of vanadium.

[0067] The heavy stream 120 may comprise from 15 wt% to 50 wt% paraffins, based on the total weight of the heavy stream 120. For example, the heavy stream 120 may comprise from 20 wt% to 45 wt%, from 25 wt% to 40 wt%, from 30 wt% to 35 wt%, or any subset thereof, based on the total weight of the heavy stream 120.

[0068] The heavy stream 120 may comprise from 5 wt% to 35 wt% cycloalkanes, based on the total weight of the heavy stream 120. For example, the heavy stream 120 may comprise from 10 wt% to 30 wt%, from 15 wt% to 25 wt%, from 17.5 wt% to 22.5 wt%, or any subset thereof, based on the total weight of the heavy stream 120.

[0069] The heavy stream 120 may comprise from 30 wt% to 65 wt% aromatics, based on the total weight of the heavy stream 120. For example, the heavy stream 120 may comprise from 35 wt% to 60 wt%, from 40 wt% to 55 wt%, from 45 wt% to 50 wt%, or any subset thereof, based on the total weight of the heavy stream 120.

[0070] Hydrotreating unit

[0071] The heavy stream 120 can then be hydrotreated 125. Hydrotreating 125 the heavy stream 120 can include contacting the heavy stream 120 with one or more hydrotreating catalysts in a hydrotreating system. The hydrotreating system can be a single reactor or a series of directly connected reactors. The heavy stream 120 can be introduced directly into a hydrotreating unit after fractionation 110.

[0072] The heavy stream 120 may be hydrotreated 125 in one or more stages, such as a three-stage hydrotreater. The multiple stages of the hydrotreater may contain different catalysts in different reaction zones. For example, the catalysts may be arranged in different beds, placed in separate reactors, or mixed in a single reactor. The heavy stream 120 may contact one or more hydrotreating catalysts in a downward flow pattern.

[0073] Hydroprocessing 125 the heavy stream 120 may include exposing the heavy stream 120 to one or more hydroprocessing catalysts, such as a hydrodemetallization (also known as "HDM") catalyst, a hydrodesulfurization (also known as "HDS") catalyst, and a hydrodearomatization (also known as "HDA") catalyst. In some embodiments, the one or more hydroprocessing catalysts may include a hydrodenitrogenation catalyst, a hydrodeoxygenation catalyst, or both.

[0074] The one or more hydroprocessing stages can be arranged in any order. For example, the one or more hydroprocessing catalysts can be arranged so that the heavy stream 120 first contacts the HDM catalyst, then the HDS catalyst, and then the HDA catalyst. Alternatively, the one or more hydroprocessing stages can be arranged so that the heavy stream 120 contacts the HDM catalyst, then the HDA catalyst, and then the HDS catalyst; or contacts the HDS, HDA, and HDM catalysts; or contacts the HDS catalyst, then the HDM catalyst, and then the HDA catalyst; or contacts the HDA catalyst, then the HDS catalyst, and then the HDM catalyst; or contacts the HDA catalyst, then the HDM catalyst, and then the HDS catalyst. Without being limited by theory, it is believed that contacting the heavy stream 120 with the HDM and HDS catalysts before contacting the HDA catalyst can prevent or minimize deactivation of the HDA catalyst.

[0075] In alternative embodiments, only one or two of the one or more hydroprocessing stages and catalysts may be present. The one or more hydroprocessing catalysts may be arranged such that the heavy stream 120 contacts the HDM catalyst followed by the HDA catalyst; or contacts the HDA catalyst followed by the HDM catalyst; or contacts the HDS catalyst followed by the HDA catalyst; or contacts the HDA catalyst followed by the HDS catalyst; or contacts the HDM catalyst followed by the HDS catalyst; or contacts the HDS catalyst followed by the HDM catalyst.

[0076] In embodiments where the one or more hydroprocessing catalysts form a mixed bed, the heavy stream 120 may contact the one or more hydroprocessing catalysts in a random or synchronous manner.

[0077] The HDM catalyst may include any catalyst suitable for hydrodemetallization. For example, the HDM catalyst may include one or more metals from Groups 5, 6, or 8-10 of the IUPAC periodic table. In some embodiments, the HDM catalyst may include platinum. The HDM catalyst may further include a support material, and the metal may be disposed on the support material. The support material may be gamma-alumina or silica / alumina extrudates, spheres, cylinders, beads, pellets, and combinations thereof. In some embodiments, the HDM catalyst may include a gamma-alumina support having a surface area of ​​100 square meters per gram (m2). 2 / g) to 160m 2 / g, for example 100m 2 / g to 130m 2 / g, or 130m 2 / g to 160m 2 / g. In one embodiment, the HDM catalyst may comprise a molybdenum metal catalyst supported on an alumina support (sometimes referred to as a "Mo / Al2O3 catalyst"). It should be understood throughout this disclosure that the metals contained in any disclosed catalyst may exist as sulfides or oxides or even other compounds.

[0078] In some embodiments, the HDM catalyst may comprise: 0.5 wt% to 12 wt% molybdenum oxide or sulfide, such as 2 wt% to 10 wt% or 3 wt% to 7 wt% molybdenum oxide or sulfide; and 88 wt% to 99.5 wt% alumina, such as 90 wt% to 98 wt% or 93 wt% to 97 wt% alumina.

[0079] The HDM catalyst may have a relatively large pore volume, such as at least 0.8 cubic centimeters per gram (cm3). 3 / g) (e.g., at least 0.9 cm 3 / g or even at least 1.0 cm 3 / g). The pore size of the HDM catalyst can be predominantly macroporous (i.e., having a pore size greater than 50 nanometers (nm)). Without being limited by theory, it is believed that this pore structure and volume can provide a large capacity for the adsorption of metals and optional dopants on the surface of the HDM catalyst. In one embodiment, the HDM catalyst may include a dopant comprising one or more compounds including an element selected from the group consisting of boron, silicon, halogens, phosphorus, and combinations thereof.

[0080] An exemplary HDM catalyst may include KFR-22 from Albemarle Corporation.

[0081] The HDS catalyst may comprise one or more metals from Groups 5, 6, or 8-10 of the IUPAC Periodic Table. The HDS catalyst may comprise one or more metals from Group 6 of the IUPAC Periodic Table and one metal from Groups 8-10 of the IUPAC Periodic Table. Examples of Group 6 metals include molybdenum and tungsten, and examples of Group 8-10 metals include nickel and cobalt. The HDS catalyst may further comprise a support material, and the metals may be disposed on the support material. In some embodiments, the HDS catalyst may comprise Mo and Ni supported on an alumina support (sometimes referred to as a "Mo-Ni / Al2O3 catalyst"). The HDS catalyst may also contain a dopant selected from the group consisting of boron, phosphorus, halogens, silicon, and combinations thereof. In one or more embodiments, the HDS catalyst may comprise: 10 wt% to 18 wt% molybdenum oxide or sulfide, such as 11 wt% to 17 wt% or 12 wt% to 16 wt% molybdenum oxide or sulfide; 1 wt% to 7 wt% nickel oxide or sulfide, such as 2 wt% to 6 wt% or 3 wt% to 5 wt% nickel oxide or sulfide; and 75 wt% to 89 wt% alumina, such as 77 wt% to 87 wt% or 79 wt% to 85 wt% alumina.

[0082] HDS catalyst can have 140m 2 / g to 200m 2 / g of surface area, such as 140m 2 / g to 170m 2 / g, or 170m 2 / g to 200m 2 / g. HDS catalyst may have 0.5cm 3 / g to 0.7cm 3 / g of the median pore volume, such as 0.6 cm 3 / g. The HDS catalyst may generally comprise a mesoporous structure having a pore size ranging from 12 nm to 50 nm.

[0083] An exemplary HDS catalyst may include KFR-33 from Albemarle Corporation.

[0084] The HDA catalyst may comprise one or more metals from Groups 5, 6, 8, 9, or 10 of the IUPAC Periodic Table. In some embodiments, the HDA catalyst may comprise one or more metals from Groups 5 or 6 of the IUPAC Periodic Table and one or more metals from Groups 8, 9, or 10 of the IUPAC Periodic Table. In some embodiments, the HDA catalyst may comprise molybdenum or tungsten from Group 6 and nickel or cobalt from Groups 8, 9, or 10. The HDA catalyst may further comprise a support material, such as a zeolite, and the metals may be disposed on the support material. In one embodiment, the HDA catalyst may comprise a tungsten and nickel metal catalyst supported on a mesoporous zeolite support (sometimes referred to as a "W-Ni / mesoporous zeolite catalyst"). In another embodiment, the HDA catalyst may comprise a molybdenum and nickel metal catalyst supported on a mesoporous zeolite support (sometimes referred to as a "Mo-Ni / mesoporous zeolite catalyst"). The zeolite support material may not be limited to any particular type of zeolite. However, it is contemplated that zeolites such as Y, beta, AWLZ-15, LZ-45, Y-82, Y-84, LZ-210, LZ-25, silicalite, or mordenite framework zeolites may be suitable for use in the presently described HDA catalysts.

[0085] The support material of the HDA catalyst (such as a mesoporous zeolite) can be characterized as mesoporous by having an average pore size of 2 nm to 50 nm. Without being bound by theory, it is believed that the relatively large pore size (i.e., mesopore) allows larger molecules to diffuse inside the zeolite, which is believed to improve the reactivity and selectivity of the catalyst. Because the pore size is increased, aromatic molecules can diffuse more easily into the catalyst and aromatic cracking can be increased. For example, in some conventional embodiments, the feedstock converted by the hydrotreating catalyst can be: vacuum gas oil; light cycle oil from, for example, a fluid catalytic cracking reactor; or coker gas oil from, for example, a coking unit. The molecular size of the hydrocarbons in these oils is relatively small compared to the molecular size of the heavy oil that can be the feedstock of the present method and system. Heavy oil is generally unable to diffuse inside conventional zeolites and be converted at the active sites located inside the zeolite. Therefore, zeolites with larger pore size (i.e., mesoporous zeolites) can allow larger molecules of the heavy oil to overcome diffusion limitations and can promote the reaction and conversion of larger molecules of the heavy oil.

[0086] In one or more embodiments, the HDA catalyst may comprise: 18 wt% to 28 wt% tungsten sulfide or oxide, such as 20 wt% to 27 wt% or 22 wt% to 26 wt% tungsten or tungsten sulfide or oxide; 2 wt% to 8 wt% nickel oxide or sulfide, such as 3 wt% to 7 wt% or 4 wt% to 6 wt% nickel oxide or sulfide; and 5 wt% to 40 wt% medium pore zeolite, such as 10 wt% to 35 wt% or 10 wt% to 30 wt% zeolite. In another embodiment, the HDA catalyst may comprise: 12 wt% to 18 wt% molybdenum oxide or sulfide, such as 13 wt% to 17 wt% or 14 wt% to 16 wt% molybdenum oxide or sulfide; 2 wt% to 8 wt% nickel oxide or sulfide, such as 3 wt% to 7 wt% or 4 wt% to 6 wt% nickel oxide or sulfide; and 5 wt% to 40 wt% medium pore zeolite, such as 10 wt% to 35 wt% or 10 wt% to 30 wt% medium pore zeolite.

[0087] It should be understood that some embodiments of the presently described methods and systems may utilize HDA catalysts comprising mesoporous zeolites (i.e., having an average pore size of 2 nm to 50 nm). However, in other embodiments, the average pore size of the zeolite may be less than 2 nm (i.e., microporous).

[0088] An exemplary HDA catalyst may include KFR-70 from Albemarle Corporation.

[0089] The heavy stream 120 may contact one or more hydroprocessing catalysts at a temperature of at least 300° C., at least 325° C., at least 350° C., at least 375° C., or at least 400° C. The heavy stream 120 may contact one or more hydroprocessing catalysts at a temperature of less than 1000° C., less than 800° C., less than 600° C., less than 500° C., or less than 450° C.

[0090] The heavy stream 120 can contact one or more hydroprocessing catalysts in the presence of hydrogen. For example, the atmosphere in which the heavy stream 120 contacts the one or more hydroprocessing catalysts can be at least 10 mol% hydrogen, at least 25 mol% hydrogen, at least 50 mol% hydrogen, at least 75 mol% hydrogen, at least 90 mol% hydrogen, or even at least 99 mol% hydrogen.

[0091] The heavy stream 120 can contact the one or more hydroprocessing catalysts at a pressure of at least 75 bar, at least 100 bar, at least 125 bar, or at least 150 bar. For example, the heavy stream 120 can contact the one or more hydroprocessing catalysts at a hydrogen partial pressure of at least 10 bar, at least 20 bar, at least 30 bar, at least 50 bar, at least 75 bar, at least 100 bar, at least 125 bar, or at least 150 bar.

[0092] The heavy stream 120 may contact one or more hydroprocessing catalysts at a hydrogen / oil ratio of at least 600. For example, the heavy stream 120 may contact one or more hydroprocessing catalysts at a hydrogen / oil ratio of at least 800, at least 1000, at least 1200, 600 to 1500, 800 to 1400, 1100 to 1300, or any subset thereof.

[0093] The heavy stream 120 can be in the range of more than 0.1h -1 , more than 0.2h -1 , greater than 0.25h -1 , greater than 0.28h -1 , less than 0.5h -1 , less than 0.4h -1 , less than 0.35h -1 , less than 0.32h -1 , 0.1h -1 to 0.5h -1 , 0.2h -1 to 0.4h -1 , 0.25h -1 to 0.35h -1 , 0.28h -1 to 0.32h -1 or any subset thereof.

[0094] Hydroprocessed heavy streams

[0095] Hydroprocessing 125 the heavy stream 120 may form a hydroprocessed heavy stream 130 .

[0096] Based on the total weight of the hydrotreated heavy stream 130, at least 50 wt%, at least 60 wt%, at least 70 wt%, at least 80 wt%, at least 90 wt%, or even at least 99 wt% of the hydrotreated heavy stream 130 may have a boiling point temperature of at least 350°C, at least 360°C, at least 370°C, or at least 380°C.

[0097] The hydrotreated heavy stream 130 may comprise less than 10 wt% sulfur, based on the total weight of the hydrotreated heavy stream 130. For example, the hydrotreated heavy stream 130 may comprise less than 8 wt%, less than 6 wt%, less than 4 wt%, less than 2 wt%, less than 1 wt%, less than 0.5 wt%, less than 0.25 wt%, or even less than 0.1 wt% sulfur, based on the total weight of the hydrotreated heavy stream 130.

[0098] The sulfur content of the hydrotreated heavy stream 130 may be less than 20%, less than 15%, less than 10%, less than 5%, less than 4%, or less than 3%, less than 2%, or even less than 1% of the sulfur content of the heavy stream 120. The sulfur content may be measured according to standard test method ASTM D-4924.

[0099] The hydrotreated heavy stream 130 may contain less than 5000 ppm nitrogen. For example, the hydrotreated heavy stream 130 may contain less than 2500 ppm, less than 2000 ppm, less than 1500 ppm, less than 1000 ppm, less than 500 ppm, less than 250 ppm, less than 125 ppm, less than 75 ppm, less than 50 ppm, less than 25 ppm, less than 10 ppm, or even less than 1 ppm nitrogen.

[0100] The nitrogen content of hydrotreated heavy stream 130 may be less than 30%, less than 25%, less than 20%, less than 15%, less than 10%, less than 5%, or even less than 1% of the nitrogen content of heavy stream 120. Nitrogen content may be measured according to standard test method ASTM D-4629.

[0101] The hydrotreated heavy stream 130 may contain less than 100 ppm nickel. For example, the hydrotreated heavy stream 130 may contain less than 75 ppm, less than 50 ppm, less than 25 ppm, less than 10 ppm, less than 5 ppm, or even less than 1 ppm nickel.

[0102] The nickel content of the hydrotreated heavy stream 130 may be less than 30%, less than 25%, less than 20%, less than 15%, less than 10%, less than 5%, or even less than 1% of the nickel content of the heavy stream 120 .

[0103] The hydrotreated heavy stream 130 may contain less than 100 ppm vanadium. For example, the hydrotreated heavy stream 130 may contain less than 75 ppm, less than 50 ppm, less than 25 ppm, less than 15 ppm, less than 10 ppm, less than 5 ppm, or even less than 1 ppm vanadium.

[0104] The vanadium content of the hydrotreated heavy stream 130 may be less than 30%, less than 25%, less than 20%, less than 15%, less than 10%, less than 5%, or even less than 1% of the vanadium content of the heavy stream 120 .

[0105] The aromatics content of hydrotreated heavy stream 130 may be less than 30%, less than 25%, less than 20%, less than 15%, less than 10%, less than 5%, or even less than 1% of the aromatics content of heavy stream 120 .

[0106] The hydrotreated heavy stream 130 may have a naphthenic and aromatics concentration of 20 wt% to 55 wt%, based on the total weight of the hydrotreated heavy stream 130. For example, the hydrotreated heavy stream 130 may have a naphthenic and aromatics concentration of 25 wt% to 50 wt%, 30 wt% to 45 wt%, 35 wt% to 40 wt%, or any subset thereof, based on the total weight of the hydrotreated heavy stream 130.

[0107] The hydrotreated heavy stream 130 can have a polar aromatic concentration of 1 wt.% to 6 wt.%, based on the total weight of the hydrotreated heavy stream 130. For example, the hydrotreated heavy stream 130 can have a polar aromatic concentration of 2 wt.% to 5 wt.%, 3 wt.% to 4 wt.%, or any subset thereof, based on the total weight of the hydrotreated heavy stream 130.

[0108] The hydrotreated heavy stream 130 may comprise from 40 wt% to 75 wt% saturated hydrocarbons, based on the total weight of the hydrotreated heavy stream 130. For example, the hydrotreated heavy stream 130 may comprise from 45 wt% to 70 wt%, from 50 wt% to 65 wt%, from 55 wt% to 60 wt%, or any subset thereof, based on the total weight of the hydrotreated heavy stream 130.

[0109] Dual FCC

[0110] The method 100 for processing a hydrocarbon feed 105 can include introducing a light stream 115 and a hydrotreated heavy stream 130 into separate FCC reaction zones to produce product streams comprising light olefins. Specifically, the light stream 115 can be introduced into a first FCC reaction zone 135 to produce a light product stream 140, and the hydrotreated heavy stream 130 can be introduced into a second FCC reaction zone 145 to produce a heavy product stream 150. The light stream 115 can be introduced directly from a fractionator into the first FCC reaction zone 135. The hydrotreated heavy stream 130 can be introduced directly from a hydrotreater into the second FCC reaction zone 145.

[0111] The light stream 115 may be exposed to more severe FCC cracking conditions than the hydrotreated heavy stream 130. As used herein, "more severe FCC cracking conditions" may include increased residence time, elevated reaction temperature, or both.

[0112] The residence time of the light stream 115 in the first FCC reaction zone 135 may be longer than the residence time of the hydrotreated heavy stream 130 in the second FCC reaction zone 145. For example, the residence time of the light stream 115 in the first FCC reaction zone 135 may be at least 5%, at least 10%, at least 20%, at least 30%, at least 40%, at least 50%, at least 60%, at least 75%, at least 100%, at least 125%, at least 150%, at least 175%, or at least 200% longer than the residence time of the hydrotreated heavy stream 130 in the second FCC reaction zone 145.

[0113] The residence time of the light stream 115 in the first FCC reaction zone 135 may be at least 0.5 seconds, at least 0.75 seconds, at least 1 second, at least 1.25 seconds, at least 1.5 seconds, at least 1.75 seconds, from 0.5 seconds to 2 seconds, from 1 second to 2 seconds, from 1.25 seconds to 2 seconds, from 1.5 seconds to 2 seconds, or any subset thereof. The residence time of the hydrotreated heavy stream 130 in the second FCC reaction zone 145 may be at least 0.5 seconds, at least 0.75 seconds, at least 1 second, at least 1.25 seconds, at least 1.5 seconds, at least 1.75 seconds, from 0.5 seconds to 2 seconds, from 1 second to 2 seconds, from 1.25 seconds to 2 seconds, from 1.5 seconds to 2 seconds, or any subset thereof.

[0114] The peak temperature to which the light stream 115 is exposed in the first FCC reaction zone 135 may be higher than the peak temperature to which the hydrotreated heavy stream 130 is exposed in the second FCC reaction zone 145. For example, the peak temperature of the light stream 115 in the first FCC reaction zone 135 may be higher than the peak temperature of the hydrotreated heavy stream 130 in the second FCC reaction zone 145 by at least 5%, at least 10%, at least 20%, at least 30%, at least 40%, at least 50%, at least 5°C, at least 10°C, at least 15°C, at least 20°C, at least 25°C, at least 30°C, from 5°C to 50°C, from 10°C to 45°C, from 15°C to 40°C, from 25°C to 35°C, or any subset thereof.

[0115] The light stream 115 may experience a peak temperature of 650° C. to 700° C., 655° C. to 695° C., 660° C. to 690° C., 665° C. to 685° C., 670° C. to 680° C., 660° C. to 700° C., 670° C. to 700° C., or any subset thereof in the first FCC reaction zone 135. The hydrotreated heavy stream 130 may experience a peak temperature of 600° C. to 665° C., 600° C. to 660° C., 600° C. to 655° C., 600° C. to 650° C., 625° C. to 665° C., 635° C. to 665° C., 635° C. to 660° C., 640° C. to 650° C., or any subset thereof in the second FCC reaction zone 145.

[0116] FCC operating conditions

[0117] In some embodiments, one or both of the first FCC reaction zone 135 and the second FCC reaction zone 145 can be operated in a downflow manner. A downflow FCC reactor or "downflow reactor" refers to a reactor in which reactants flow downward from a catalyst / feed mixing zone through a cracking reaction zone to a separation zone. Hydrocarbons react in the cracking reaction zone by contacting the FCC catalyst composition, which causes at least a portion of the hydrocarbons to undergo one or more cracking reactions to form one or more cracking reaction products, such as light olefins. The temperature of the catalyst can be equal to or greater than the reaction temperature of the cracking reaction zone, which can transfer heat to the hydrocarbons, thereby promoting endothermic cracking reactions.

[0118] Steam can be introduced into the top of the cracking reaction zone to provide additional heating to the hydrocarbon and catalyst mixture. Steam can also serve as a diluent, reducing the hydrocarbon partial pressure in the FCC reactor. Steam can also prevent secondary reactions and help improve the selectivity of the cracking reaction.

[0119] After leaving the FCC reactor, the catalyst can be separated from the hydrocarbons to separate the spent catalyst. The spent catalyst can then be sent to a regenerator. The regenerated catalyst can have a greater activity than the spent catalyst. Catalyst from the first FCC reaction zone 135 and the second FCC reaction zone 145 can be regenerated in a single regenerator.

[0120] One or both of the first FCC reaction zone 135 and the second FCC reaction zone 145 may operate under high severity conditions, also known as HS-FCC. The FCC reaction zones may operate at a peak temperature greater than or equal to 580° C., a weight ratio of the FCC catalyst composition to crude oil of 2:1 to 10:1, and a residence time of 0.1 to 60 seconds.

[0121] The first FCC reaction zone 135 and the second FCC reaction zone 145 can each independently operate at a peak temperature greater than or equal to 580° C. For example, the first FCC reaction zone 135 and the second FCC reaction zone 145 can each independently operate at a peak temperature greater than 600° C., greater than 620° C., greater than 640° C., greater than 645° C., greater than 660° C., greater than 670° C., 600° C. to 700° C., 600° C. to 690° C., 600° C. to 680° C., 650° C. to 700° C., 650° C. to 690° C., 650° C. to 680° C., 670° C. to 700° C., 670° C. to 680° C., or any subset thereof. When the reaction temperature is above, for example, 720° C. or 700° C., the hydrocarbons can undergo increased thermal cracking and reduced catalytic cracking compared to embodiments where the reaction temperature is below 720° C. or 700° C.

[0122] In each of first FCC reaction zone 135 and second FCC reaction zone 145, the weight ratio of the FCC catalyst composition to hydrocarbons may independently be from 2:1 to 10:1, such as from 2:1 to 8:1, 2:1 to 6:1, 2:1 to 4:1, 4:1 to 10:1, 6:1 to 10:1, or 8:1 to 10:1.

[0123] The first FCC reaction zone 135 and the second FCC reaction zone 145 can independently be operated with a catalyst to oil (CTO) ratio of 2:1 to 10:1, where the catalyst to oil ratio is the weight ratio of the FCC catalyst composition to the weight of hydrocarbons in a unit volume of the reaction mixture comprising the hydrocarbons and the FCC catalyst composition. For example, the first FCC reaction zone 135 and the second FCC reaction zone 145 can independently be operated with a catalyst to oil ratio of 2:1 to 3:1, 2:1 to 5:1, 2:1 to 10:1, 3:1 to 5:1, or 5:1 to 10:1. Without being bound by theory, it is believed that a catalyst to oil ratio of less than 2:1 may not provide a sufficient amount of catalyst to catalytically crack hydrocarbons economically and productively. It is believed that a catalyst to oil ratio greater than 10:1 may not be economically practical in large-scale commercial applications.

[0124] The hydrocarbons may contact the FCC catalyst composition in the first FCC reaction zone 135 with a residence time of from 0.1 seconds to 60 seconds. For example, the hydrocarbons may contact the FCC catalyst composition in the first FCC reaction zone 135 with a residence time of from 5 seconds to 60 seconds, from 10 seconds to 60 seconds, from 20 seconds to 60 seconds, from 30 seconds to 60 seconds, from 40 seconds to 60 seconds, from 50 seconds to 60 seconds, from 0.1 seconds to 50 seconds, from 0.1 seconds to 40 seconds, from 0.1 seconds to 30 seconds, from 0.1 seconds to 20 seconds, from 0.1 seconds to 10 seconds, from 10 seconds to 50 seconds, from 20 seconds to 40 seconds, or any subset thereof.

[0125] The hydrocarbons may contact the FCC catalyst composition in the second FCC reaction zone 145 with a residence time of from 0.1 seconds to 60 seconds. For example, the hydrocarbons may contact the FCC catalyst composition in the second FCC reaction zone 145 with a residence time of from 5 seconds to 60 seconds, from 10 seconds to 60 seconds, from 20 seconds to 60 seconds, from 30 seconds to 60 seconds, from 40 seconds to 60 seconds, from 50 seconds to 60 seconds, from 0.1 seconds to 50 seconds, from 0.1 seconds to 40 seconds, from 0.1 seconds to 30 seconds, from 0.1 seconds to 20 seconds, from 0.1 seconds to 10 seconds, from 10 seconds to 50 seconds, from 20 seconds to 40 seconds, or any subset thereof.

[0126] Without being bound by any particular theory, it is believed that residence times less than 0.1 seconds may not provide sufficient time for the hydrocarbons to be adequately cracked by the FCC catalyst composition.

[0127] The hydrocarbons can contact the FCC catalyst composition in the presence of steam. For example, the steam to hydrocarbon ratio in the first FCC reaction zone 135 can be from 0:1 to 1:1, such as from 0:1 to 0.75:1, 0:1 to 0.5:1, 0:1 to 0.25:1, 0:1 to 0.1:1, 0:1 to 0.01:1, or any subset thereof. The steam to hydrocarbon ratio in the second FCC reaction zone 145 can be from 0:1 to 1:1, such as from 0:1 to 0.75:1, 0:1 to 0.5:1, 0:1 to 0.25:1, 0:1 to 0.1:1, 0:1 to 0.01:1, or any subset thereof.

[0128] The FCC catalyst composition may include one or more of various fluid catalytic cracking catalysts, which may be suitable for use in FCC reaction zones operating under high severity conditions. Examples of fluid catalytic cracking catalysts suitable for use as FCC catalyst compositions may include, but are not limited to, zeolites, silica-alumina catalysts, carbon monoxide combustion promoter additives, bottom oil cracking additives, light olefin production additives, other catalyst additives, or combinations of these components. Zeolites that may be used as at least a portion of the FCC catalyst composition for cracking may include, but are not limited to, Y zeolite, REY zeolite, USY zeolite, RE-USY zeolite, or a combination of these zeolites. The FCC catalyst composition may also include shaped selective catalyst additives, such as ZSM-5 zeolite crystals or other pentasil-type catalyst structures, which are commonly used in other FCC processes to produce light olefins and / or improve the octane number of FCC gasoline. In one or more embodiments, the FCC catalyst composition may include a mixture of ZSM-5 zeolite crystals and cracking catalyst zeolites and a matrix structure of a conventional FCC cracking catalyst. In one or more embodiments, the FCC catalyst composition may be a mixture of Y zeolite and ZSM-5 zeolite catalyst embedded with clay, alumina, and a binder.

[0129] In one or more embodiments, at least a portion of the FCC catalyst composition may be modified to include one or more rare earth elements (the 15 elements of the lanthanide series of the IUPAC periodic table plus scandium and yttrium), alkaline earth metals (Group 2 of the IUPAC periodic table), transition metals, phosphorus, fluorine, or any combination of these elements, which may increase olefin yields. One or more transition metals or metal oxides may also be impregnated on the catalyst. The metal or metal oxide may include one or more metals from Groups 6-10 of the IUPAC periodic table. The metal or metal oxide may include one or more of molybdenum, rhenium, tungsten, or any combination of these. At least a portion of the FCC catalyst composition may be impregnated with tungsten oxide.

[0130] The FCC catalyst composition can be formed by various methods. According to one embodiment, the matrix material can be mixed with a fluid (such as water) to form a slurry, and the zeolite can be mixed with a fluid (such as water) alone to form a slurry. The matrix material slurry and the zeolite slurry can be combined under stirring. Separately, another slurry can be formed by combining a binder material with a fluid (such as water). The binder slurry can then be combined with a slurry containing the zeolite and matrix material to form a final slurry. The final slurry can then be dried, for example, by spray drying, and then calcined to produce microparticles of the cracking catalyst.

[0131] The FCC catalyst composition can be in the form of shaped particles, such as microspheres. As used in this disclosure, "particles" refer to particles with an average particle size of 0.1 microns to 100 microns. The size of a particle refers to the maximum length of the particle from one side to the other measured along the longest distance of the particle. For example, a spherical particle has a size equal to its diameter, or a rectangular prism-shaped particle has a maximum length equal to the hypotenuse extending from the opposite corner. In an embodiment, each zeolite component of the FCC catalyst composition can be included in each catalyst particle. However, in other embodiments, particles can be mixed, wherein the particles only comprise a portion of the FCC catalyst composition. For example, a mixture of two types of particles can be included in the FCC catalyst composition, wherein one type of particle only comprises ZSM-5 and the other type of particle only comprises USY zeolite.

[0132] The FCC catalyst composition may be contacted with steam prior to use in an FCC system. The purpose of the steam treatment may be to accelerate the hydrothermal aging of the FCC catalyst composition that occurs during operation of the FCC system to obtain an equilibrium catalyst. Without being bound by any particular theory, it is believed that the steam treatment may result in the removal of aluminum from the framework, thereby reducing the number of sites where framework hydrolysis may occur under hydrothermal and thermal conditions. This removal of aluminum results in an increase in the thermal and hydrothermal stability of the dealuminated zeolite. As smaller SiO4 tetrahedra replace larger AlO4 - tetrahedral, so dealumination can result in a reduction in unit cell size. Dealumination can also affect the acidity of the zeolite by removing framework aluminum and forming additional framework aluminum species. Dealumination can affect the acidity of the zeolite by reducing the total acidity and increasing the acid strength of the zeolite. The total acidity can be reduced due to the removal of framework aluminum that acts as Bronsted acid sites. The acid strength of the zeolite can be increased because paired acid sites are removed or the second coordinated, next neighboring aluminum is removed. The increase in acid strength can be attributed to the fact that the charge density on the protons of the OH groups is highest when there is no framework aluminum in the second coordination sphere. In an embodiment, the FCC catalyst composition can be contacted with steam at a temperature greater than or equal to 800°C for a period of 6 hours or longer before contacting the hydrocarbons with the FCC catalyst composition.

[0133] In an embodiment, one or more supplemental feed streams may be combined with the hydrocarbons of the light stream 115 and / or the hydrotreated heavy stream 130 prior to introducing the hydrocarbons into one or both of the first FCC reaction zone 135 and the second FCC reaction zone 145. The one or more supplemental feed streams may be added so that they contact the FCC catalyst simultaneously with the hydrocarbons of the light stream and / or the hydrotreated heavy stream. The supplemental feed stream may include one or more of a vacuum residue, tar sands, asphalt, atmospheric residue, vacuum gas oil, demetallized oil, a naphtha stream, or a combination of these.

[0134] Light product stream

[0135] Fluid catalytic cracking of the light stream 115 in the first FCC reaction zone 135 can produce a light product stream 140 comprising light olefins, such as ethylene, propylene, and butenes. For example, the light product stream 140 can comprise at least 15 wt%, at least 20 wt%, at least 25 wt%, at least 30 wt%, or at least 35 wt% light olefins based on the total weight of the hydrocarbons in the light product stream.

[0136] Light product stream 140 may comprise at least 2 wt% C2 olefins, such as ethylene. For example, light product stream 140 may comprise at least 4 wt%, at least 6 wt%, or at least 8 wt%, at least 10 wt%, or at least 11 wt% C2 olefins.

[0137] Light product stream 140 may comprise at least 2 wt% C3 olefins, such as propylene. For example, light product stream 140 may comprise at least 5 wt%, at least 10 wt%, at least 15 wt%, at least 17 wt%, or at least 18 wt% C3 olefins.

[0138] The light product stream 140 may comprise at least 2 wt% C4 olefins, such as butenes. For example, the light product stream 140 may comprise at least 5 wt%, at least 6 wt%, at least 7 wt%, or at least 8 wt% C4 olefins.

[0139] Light product stream 140 may comprise at least 5 wt% gasoline-series products. For example, light product stream 140 may comprise at least 10 wt%, at least 20 wt%, at least 25 wt%, at least 30 wt%, at least 35 wt%, or at least 38 wt% gasoline-series products.

[0140] Fluid catalytic cracking of the light stream 115 in the first FCC reaction zone 135 may convert hydrocarbons originally found in the light stream 115 into other products. For example, fluid catalytic cracking of the light stream 115 in the first FCC reaction zone 135 may convert at least 50 wt%, at least 60 wt%, at least 70 wt%, at least 80 wt%, or at least 90 wt% of the hydrocarbons originally in the light stream 115 into other products.

[0141] Fluid catalytic cracking of the light stream 115 in the first FCC reaction zone 135 may convert a portion of the hydrocarbons originally found in the light stream 115 into coke. For example, fluid catalytic cracking of the light stream 115 in the first FCC reaction zone 135 may convert less than 10 wt%, less than 8 wt%, less than 7 wt%, less than 6 wt%, or less than 5 wt% of the hydrocarbons originally in the light stream 115 into coke.

[0142] Heavy product stream

[0143] Fluid catalytic cracking of the hydrotreated heavy stream 130 in the second FCC reaction zone 145 can produce a heavy product stream 150. The heavy product stream 150 can include light olefins, such as ethylene, propylene, and butenes. For example, the heavy product stream 150 can include at least 15 wt%, at least 20 wt%, at least 25 wt%, at least 30 wt%, at least 35 wt%, at least 40 wt%, at least 45 wt%, or at least 50 wt% light olefins based on the total weight of the hydrocarbons in the heavy product stream.

[0144] The heavy product stream 150 may comprise at least 2 wt% C2 olefins, such as ethylene. For example, the heavy product stream 150 may comprise at least 4 wt%, at least 6 wt%, or at least 8 wt%, or at least 10 wt% C2 olefins.

[0145] The heavy product stream 150 may contain at least 2 wt% C3 olefins, such as propylene. For example, the heavy product stream 150 may contain at least 5 wt%, at least 10 wt%, at least 15 wt%, at least 17 wt%, or at least 20 wt%, or at least 25 wt% C3 olefins.

[0146] The heavy product stream 150 may contain at least 2 wt% C4 olefins, such as butenes. For example, the heavy product stream 150 may contain at least 5 wt%, at least 10 wt%, at least 12 wt% C4 olefins, at least 14 wt%, or at least 15 wt% C4 olefins.

[0147] The heavy product stream 150 may comprise at least 5 wt% gasoline-series products. For example, the heavy product stream 150 may comprise at least 10 wt%, or at least 20 wt%, at least 25 wt%, at least 30 wt%, at least 35 wt%, or at least 38 wt% gasoline-series products.

[0148] Fluid catalytic cracking of the hydrotreated heavy stream 130 in the second FCC reaction zone 145 can convert hydrocarbons originally found in the hydrotreated heavy stream 130 into other products. For example, fluid catalytic cracking can convert at least 50 weight percent, at least 60 weight percent, at least 70 weight percent, at least 80 weight percent, or at least 90 weight percent of the hydrocarbons originally in the hydrotreated heavy stream 130 into other products.

[0149] Fluid catalytic cracking of the hydrotreated heavy stream 130 in the second FCC reaction zone 145 may convert a portion of the hydrocarbons originally found in the hydrotreated heavy stream 130 into coke. For example, fluid catalytic cracking of the hydrotreated heavy stream 130 in the second FCC reaction zone 145 may convert less than 10 wt%, less than 8 wt%, or less than 7 wt% of the hydrocarbons originally in the hydrotreated heavy stream 130 into coke.

[0150] Combined product streams

[0151] In some embodiments, the light product stream 140 and the heavy product stream 150 may be combined to form a combined product stream 155. The light product stream 140 and the heavy product stream 150 may be combined in a mixer.

[0152] Combined product stream 155 may comprise light olefins, such as ethylene, propylene, and butenes. For example, combined product stream 155 may comprise at least 15 wt%, at least 20 wt%, at least 25 wt%, at least 30 wt%, at least 35 wt%, at least 40 wt%, or at least 43 wt% light olefins.

[0153] Combined product stream 155 may contain at least 2 wt% C2 olefins, such as ethylene. For example, combined product stream 155 may contain at least 4 wt%, at least 6 wt%, or at least 8 wt%, or at least 10 wt% C2 olefins.

[0154] Combined product stream 155 may contain at least 2 wt% C3 olefins, such as propylene. For example, combined product stream 155 may contain at least 5 wt%, at least 10 wt%, at least 15 wt%, at least 17 wt%, or at least 20 wt% C3 olefins.

[0155] Combined product stream 155 may contain at least 2 wt% C4 olefins, such as butenes. For example, combined product stream 155 may contain at least 5 wt%, at least 10 wt%, or at least 11 wt% C4 olefins.

[0156] Combined product stream 155 can comprise at least 5 wt% gasoline-series products. For example, combined product stream 155 can comprise at least 10 wt%, or at least 20 wt%, at least 25 wt%, or at least 28 wt% gasoline-series products.

[0157] Fluid catalytic cracking of the light stream 115 in the first FCC reaction zone 130 and fluid catalytic cracking of the hydrotreated heavy stream 130 in the second FCC reaction zone 145 may convert a portion of the hydrocarbons originally found in the hydrocarbon feed 105 into other products. For example, fluid catalytic cracking of the light stream 115 and the hydrotreated heavy stream 130 may convert at least 50 wt%, at least 60 wt%, at least 70 wt%, at least 80 wt%, at least 85 wt%, or even at least 88 wt% of the hydrocarbons originally in the hydrocarbon feed 105 into other products.

[0158] The process 100 can convert at least a portion of the hydrocarbons initially in the hydrocarbon feed 105 into light olefins. For example, at least 25 weight percent, at least 30 weight percent, at least 35 weight percent, at least 40 weight percent, at least 45 weight percent, or at least 50 weight percent of the hydrocarbons initially in the hydrocarbon feed 105 can be converted to light olefins by the process 100.

[0159] Fluid catalytic cracking of the light stream 115 and the hydrotreated heavy stream 130 may convert a portion of the hydrocarbons originally found in the light stream 115 and the hydrotreated heavy stream 130 into coke. For example, fluid catalytic cracking may convert less than 10 weight percent, less than 8 weight percent, less than 7 weight percent, or less than 6 weight percent of the hydrocarbons originally in the light stream 115 and the hydrotreated heavy stream 130 into coke.

[0160] Example

[0161] Various aspects of the present disclosure will be further illustrated by the following examples. These examples are illustrative in nature and should not be construed as limiting the subject matter of the present disclosure.

[0162] Example 1

[0163] Arabian light crude oil having an API gravity of 33.0 and a sulfur content of 1.6 wt% was fractionated in a distillation column to form a light stream and a heavy stream. The properties of the feed crude stream and the resulting fractions (based on their percentage composition in the crude oil fractions) are given in Table 1 below.

[0164] Table 1

[0165] Stream Name boiling range Ni(ppm) V(ppm) S (weight %) N (ppm) hydrocarbon feed 3.4 14.52 1.6 444 Light Flow Below 370℃ <1 <1 0.2 13 Heavy Flow Above 370℃ 4.4 14.2 1.4 431

[0166] The details of the non-hydrotreated heavy stream are shown in Table 2 below, where the heavy stream is designated EX-1(A).

[0167] Example 2

[0168] The heavy stream from Example 1 was hydrotreated in a three-stage hydrotreater. The reaction conditions were: weighted average bed temperature of 400°C, pressure of 150 bar, liquid hourly space velocity (LHSV) of 0.5 h -1 , the H2 / oil ratio is 1200:1 (v / v), the oil flow rate is 300 ml / h, and the H2 flow rate is 360 L / h.

[0169] The first section of the hydrotreater uses a KFR-22 catalyst from Albemarle to perform hydrodemetallization (HDM). The second section of the hydrotreater uses a KFR-33 catalyst from Albemarle to perform hydrodesulfurization (HDS). The third section of the hydrotreater uses a KFR-70 catalyst from Albemarle to perform hydrodearomatization (HDA). The first, second, and third sections are discrete beds stacked one on top of the other in a single reaction zone. The heavy stream flows downward to the first section, then to the second section, and then to the third section. The properties of this hydrotreated heavy stream are shown in Table 2 below and are designated EX-2.

[0170] Table 2

[0171] EX-1(A) EX-2 <![CDATA[Kinematic viscosity at 100 °C (mm 2 / s)]]> 6 Density (g / ml) 0.965 0.8402 Nitrogen (ppm) 1208 68.5 Sulfur (weight %) 3.1 0.007 Ni(ppm) 10 <1 V(ppm) 32 <1 Aromatics 68.6 25.6

[0172] Example 3

[0173] Various fractions of Arabian Light Crude Oil were cracked under the following conditions: Catalysts having the compositions shown in Table 3 below were used in all reactions.

[0174] Table 3

[0175] Components weight% Notes ZSM-5 20 <![CDATA[Phosphorus is impregnated on zeolite with 7.5 wt% P2O5]]> USY 21 <![CDATA[Lanthanum is impregnated on zeolite with 2.5 wt% La2O3]]> Alumina 8 Pural SB from Sasol clay 49 Kaolin Silicon dioxide 2 Ludox TM-40 added as colloidal silica

[0176] The Advanced Cracking Evaluation (ACE) unit was used to simulate a commercial FCC process. The reaction was run twice with the new catalyst to simulate two separate FCC reaction zones in parallel.

[0177] Before each experiment, the catalyst was loaded into the reactor and heated to the desired reaction temperature. N2 gas was fed from the bottom through a feed injector to keep the catalyst particles fluidized. Once the catalyst bed temperature reached within ±2°C of the reaction temperature, the reaction could begin. The feed was then injected at a predetermined time (on-time (TOS)). The desired catalyst to feed ratio was obtained by controlling the feed pump. The gaseous product was transported to a liquid receiver where C 5+The hydrocarbons were condensed, and the remaining gases were conveyed to a gas receiver. After catalyst stripping was complete, the reactor was heated to 700°C, and the nitrogen atmosphere was replaced with air to regenerate the catalyst. During regeneration, the gases released were conveyed to a CO2 analyzer. The coke yield was calculated from the flue gas flow rate and CO2 concentration. The above process was repeated for each of Examples 3(A) and 3(B). The catalyst to hydrocarbon weight ratio was 8.

[0178] It will be appreciated that the time on stream (TOS) is directly proportional to the residence time.

[0179] Example 3(A) - First Reaction Zone

[0180] The light stream from Example 1 was fed to an advanced cracking evaluation unit. A time on stream (TOS) of 75 seconds, a residence time of 1 to 2 seconds, and a temperature of 675°C were used.

[0181] Example 3(B) - Second Reaction Zone

[0182] The hydrotreated heavy stream from Example 2 was fed to an advanced cracking evaluation unit. A TOS of 75 seconds, a residence time of 1 to 2 seconds, and a temperature of 645° C. were used. Characterizations are shown in Tables 4 and 5.

[0183] Example 3 (merged)

[0184] The streams of Example 3(A) and Example 3(B) were combined to form a single stream. The single stream simulated the output of processing the entire crude oil according to the method of the present disclosure.

[0185] Example 3 (combined) is a weighted average of Examples 3(A) and 3(B). Example 3(A) accounts for 53% by weight of Example 3 (combined). Example 3(B) accounts for 44% by weight of Example 3 (combined).

[0186] Comparative Example 1 (CE-1)

[0187] The same Arabian light crude oil used in Example 1 was directly cracked in the same cracking reactor as used in Example 3(A) under the same conditions, and the result was designated CE-1. Specifically, the temperature was 675°C and the TOS was 75 seconds.

[0188] Table 4

[0189]

[0190] As can be seen in Table 4, the combined yield of total light olefins for the present process is significantly higher than that for the comparative process. In addition, each of Example 3(A), Example 3(B), and Example 3 (Combined) exhibits significantly reduced levels of coke formation compared to Comparative Example CE-1.

[0191] Comparative Example 2 (CE-2)

[0192] The heavy stream from Example 1 was fed to an advanced cracking evaluation unit. A TOS of 75 seconds, a residence time of 1 to 2 seconds and a temperature of 645° C. were used. The characteristics of the products are given in Table 5 below.

[0193] Table 5

[0194]

[0195]

[0196] As can be seen in Table 5, using a hydrotreated heavy stream as a feed to the catalytic reactor provides the following advantages: higher conversion; higher yields of C2, C3, and C4 olefins; higher gasoline yields; and significantly reduced coke formation, among others.

[0197] aspect

[0198] According to a first aspect of the present disclosure, a method for processing a hydrocarbon feed comprises: fractionating the hydrocarbon feed into a light stream and a heavy stream, wherein the light stream comprises hydrocarbons boiling below 370° C. and the heavy stream comprises hydrocarbons boiling above 370° C.; hydrotreating the heavy stream to form a hydrotreated heavy stream; feeding the light stream to a first fluid catalytic cracking (FCC) reaction zone to produce a light product stream comprising light olefins; and feeding the hydrotreated heavy stream to a second fluid catalytic cracking (FCC) reaction zone to produce a heavy product stream comprising light olefins. The first FCC reaction zone operates at more severe operating conditions than the second FCC reaction zone.

[0199] According to a second aspect of the present disclosure, in combination with the first aspect, the first FCC reaction zone and the second FCC reaction zone are operated in a downflow configuration.

[0200] According to a third aspect of the present disclosure, in combination with any one of the first or second aspects, the first FCC reaction zone and the second FCC reaction zone are operated under high severity conditions.

[0201] According to a fourth aspect of the present disclosure, in combination with any one of the first to third aspects, the first FCC reaction zone and the second FCC reaction zone are independently operated at a temperature greater than or equal to 580° C., a weight ratio of the FCC catalyst composition to hydrocarbons of 2:1 to 10:1, and a residence time of 0.1 to 60 seconds.

[0202] According to a fifth aspect of the present disclosure, in combination with any one of the first to fourth aspects, the first FCC reaction zone is at least 10 degrees Celsius warmer than the second FCC reaction zone.

[0203] According to a sixth aspect of the present disclosure, in combination with any one of the first to fifth aspects, the light stream and the hydrotreated heavy stream have the same residence time in their respective FCC reaction zones.

[0204] According to a seventh aspect of the present disclosure, in combination with any one of the first to sixth aspects, the heavy stream is hydrotreated in a three-stage hydrotreatment unit.

[0205] According to an eighth aspect of the present disclosure, in combination with any one of the first to seventh aspects, hydrotreating the heavy stream comprises contacting the heavy stream with a hydrodemetallization catalyst, a hydrodesulfurization catalyst, and a hydrodearomatization catalyst in the presence of hydrogen.

[0206] According to a ninth aspect of the present disclosure, in combination with any one of the first to eighth aspects, the hydrocarbon feed is whole crude oil.

[0207] According to a tenth aspect of the present disclosure, in combination with any one of the first to ninth aspects, the hydrocarbon feed has an API gravity of 25 to 35.

[0208] According to an eleventh aspect of the present disclosure, in combination with any one of the first to tenth aspects, the light stream comprises at least 80 wt% hydrocarbons boiling below 370°C, based on the total weight of hydrocarbons in the light stream.

[0209] According to a twelfth aspect of the present disclosure, in combination with any one of the first to eleventh aspects, the light stream comprises at least 80 weight percent of all hydrocarbons initially boiling at a temperature below 370° C. in the hydrocarbon feed.

[0210] According to a thirteenth aspect of the present disclosure, in combination with any one of the first to twelfth aspects, the heavy stream comprises at least 80 wt% of hydrocarbons boiling above 370°C, based on the total weight of hydrocarbons in the heavy stream.

[0211] According to a fourteenth aspect of the present disclosure, in combination with any one of the first to thirteenth aspects, the heavy stream comprises at least 80 weight percent of all hydrocarbons initially boiling at temperatures above 370° C. in the hydrocarbon feed.

[0212] According to a fifteenth aspect of the present disclosure, in combination with any one of the first to fourteenth aspects, at least 35 wt% of the hydrocarbon feed is converted to light olefins.

[0213] According to a sixteenth aspect of the present disclosure, in combination with any one of the first to fifteenth aspects, the light product stream comprising light olefins comprises at least 35 wt% light olefins based on the total weight of hydrocarbons in the light product stream.

[0214] According to a seventeenth aspect of the present disclosure, in combination with any one of the first to sixteenth aspects, the heavy product stream comprising light olefins comprises at least 45 wt% light olefins based on the total weight of hydrocarbons in the heavy product stream.

[0215] According to an eighteenth aspect of the present disclosure, in combination with any one of the first to seventeenth aspects, the light product stream and the heavy product stream together comprise a combined at least 40 wt% of light olefins.

[0216] According to a nineteenth aspect of the present disclosure, in combination with any one of the first to eighteenth aspects, the first FCC reaction zone and the second FCC reaction zone are operated under high severity conditions; the hydrocarbon feed is whole crude oil; the light stream comprises at least 99 weight percent hydrocarbons boiling below 370° C.; the heavy stream comprises at least 99 weight percent hydrocarbons boiling above 370° C.; and hydrotreating the heavy stream comprises contacting the heavy stream with a hydrodemetallization catalyst, a hydrodesulfurization catalyst, and a hydrodearomatization catalyst in the presence of hydrogen.

[0217] According to the twentieth aspect of the present disclosure, in combination with any one of the first to nineteenth aspects, the first FCC reaction zone and the second FCC reaction zone are operated under high severity conditions; the first FCC reaction zone is at least 20 degrees Celsius higher than the second FCC reaction zone; the hydrocarbon feed is whole crude oil; the light stream comprises at least 99 weight % of hydrocarbons boiling below 370°C; the light stream accounts for at least 99 weight % of all hydrocarbons initially boiling below 370°C in the hydrocarbon feed; the heavy stream comprises at least 99 weight % of hydrocarbons boiling above 370°C; the heavy stream comprises at least 99 weight % of hydrocarbons boiling above 370°C; and hydrotreating the heavy stream comprises contacting the heavy stream with a hydrodemetallization catalyst, a hydrodesulfurization catalyst, and a hydrodearomatization catalyst in the presence of hydrogen.

[0218] It should be noted that any two quantitative values ​​assigned to a property may constitute a range for that property, and that all combinations of ranges formed by all of the stated quantitative values ​​for a given property are contemplated in this disclosure.

[0219] It should be noted that one or more of the appended claims utilize the term "wherein" as a transitional phrase. For purposes of defining the present technology, it should be noted that this term is introduced in the claims as an open transitional phrase to introduce a list of features of the structure and should be interpreted in a manner similar to the more commonly used open-ended term "comprising."

[0220] Having described the subject matter of the present disclosure in detail with reference to specific aspects, it should be noted that the various details of these aspects should not be construed as implying that these details are essential components of these aspects. Rather, the claims appended hereto should be construed as the sole indicator of the breadth of the present disclosure and the respective scope of the various aspects described herein. Furthermore, it will be apparent that modifications and variations may be made without departing from the scope of the appended claims.

Claims

1. A method for treating a hydrocarbon feed, comprising: fractionating the hydrocarbon feed into a light stream and a heavy stream, wherein the light stream comprises hydrocarbons boiling below 370° C. and the heavy stream comprises hydrocarbons boiling above 370° C.; hydrotreating the heavy stream to form a hydrotreated heavy stream; feeding the light stream to a first fluid catalytic cracking (FCC) reaction zone to produce a light product stream comprising light olefins; and The hydrotreated heavy stream is fed to a second fluid catalytic cracking (FCC) reaction zone to produce a heavy product stream comprising light olefins; wherein, The first FCC reaction zone operates at more severe operating conditions than the second FCC reaction zone.

2. The method according to claim 1, wherein The first FCC reaction zone and the second FCC reaction zone are operated in a downflow configuration.

3. The method according to claim 1 or 2, wherein The first FCC reaction zone and the second FCC reaction zone are operated under high severity conditions.

4. The method according to any one of claims 1 to 3, wherein The first and second FCC reaction zones independently operate at a temperature greater than or equal to 580°C, a weight ratio of FCC catalyst composition to hydrocarbons of 2:1 to 10:1, and a residence time of 0.1 to 60 seconds.

5. The method according to any one of claims 1 to 4, wherein The first FCC reaction zone is at least 10 degrees Celsius warmer than the second FCC reaction zone.

6. The method according to any one of claims 1 to 5, wherein The light stream and the hydrotreated heavy stream have the same residence time within their respective FCC reaction zones.

7. The method according to any one of claims 1 to 6, wherein The heavy stream is hydrotreated in a three-stage hydrotreating unit.

8. The method according to any one of claims 1 to 7, wherein Hydrotreating the heavy stream includes contacting the heavy stream with a hydrodemetallization catalyst, a hydrodesulfurization catalyst, and a hydrodearomatization catalyst in the presence of hydrogen.

9. The method according to any one of claims 1 to 8, wherein The hydrocarbon feed is whole crude oil.

10. The method according to any one of claims 1 to 9, wherein The hydrocarbon feed has an API gravity of 25 to 35.

11. The method according to any one of claims 1 to 10, wherein: The light stream comprises at least 80 wt% hydrocarbons boiling below 370° C., based on the total weight of hydrocarbons in the light stream; as well as The heavy stream comprises at least 80 wt% hydrocarbons boiling above 370°C, based on the total weight of hydrocarbons in the heavy stream.

12. The method according to any one of claims 1 to 11, wherein: said light stream comprising at least 80% by weight of all hydrocarbons initially boiling at a temperature below 370° C. in said hydrocarbon feed; as well as The heavy stream comprises at least 80 wt. % of all hydrocarbons initially boiling at temperatures above 370°C in the hydrocarbon feed.

13. The method according to any one of claims 1 to 12, wherein: the light product stream comprising light olefins comprising at least 35 wt% light olefins based on the total weight of hydrocarbons in the light product stream; The heavy product stream comprising light olefins comprises at least 45% by weight light olefins based on the total weight of hydrocarbons in the heavy product stream; as well as The light product stream and the heavy product stream together comprise a combined at least 40 weight percent light olefins.

14. The method according to any one of claims 1 to 13, wherein At least 35 weight percent of the hydrocarbon feed is converted to light olefins.

15. The method according to any one of claims 1 to 14, wherein: The hydrocarbon feed is whole crude oil; The light stream comprises at least 99 wt% hydrocarbons boiling below 370° C., based on the total weight of hydrocarbons in the light stream; The light stream comprises at least 99 weight percent of all hydrocarbons initially boiling below 370° C. in the hydrocarbon feed; The heavy stream comprises at least 99 wt% hydrocarbons boiling above 370° C., based on the total weight of hydrocarbons in the heavy stream; The heavy stream comprises at least 99 weight percent of all hydrocarbons initially boiling above 370° C. in the hydrocarbon feed; Hydrotreating the heavy stream comprises: contacting the heavy stream with a hydrodemetallization catalyst, a hydrodesulfurization catalyst, and a hydrodearomatization catalyst in the presence of hydrogen; The first FCC reaction zone and the second FCC reaction zone are operated under high severity conditions; and The first FCC reaction zone operates at a temperature at least 20 degrees Celsius higher than the second FCC reaction zone.

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