Process for reacting hydrocarbons using stripper

Abstract

According to one or more embodiments described herein, an olefin compound may be formed by a process comprising contacting a feed stream comprising one or more hydrocarbons with a particulate solid in a reactor. In the reactor, the one or more hydrocarbons may be reacted to form one or more olefin compounds, and coke may be formed on the particulate solid. The particulate solids may be passed from the reactor to a stripping zone. In the stripping zone, the particulate solids may be contacted with a stripping gas and oxygen. The stripping gas may include nitrogen, steam, or a combination thereof. In the stripping zone, a majority of the coke may react with oxygen to form carbon dioxide. A majority of the carbon dioxide generated in the stripping zone can be passed out of the stripping zone and combined with the one or more olefin compounds.

Description

[0001] CROSS-REFERENCE TO RELATED APPLICATIONS

[0002] This application claims the benefit of U.S. Provisional Application Serial No. 63 / 406,445, filed on September 14, 2022, the entire disclosure of which is hereby incorporated by reference into this document. Technical Field

[0003]

[0013] Various embodiments described herein relate generally to chemical processing, and more particularly, to methods and systems for forming olefin compounds. Background Art

[0004] Olefin compounds can be used as basic materials to produce many types of goods and materials. For example, ethylene can be used to make polyethylene, ethylene chloride or ethylene oxide. Such products can be used in product packaging, construction, textiles, etc. Therefore, olefin compounds such as ethylene, propylene, butylene and styrene are needed in industry. Summary of the invention

[0005] Olefin compounds can be formed from various hydrocarbon feeds. For example, olefin materials can be formed by dehydrogenating alkanes (catalytic or thermal). In some of these methods, particulate solids are utilized, which can typically circulate between a reactor and a regeneration unit. In such methods, coke can be formed on the particulate solids. In many conventional methods, the coke is burned in the regeneration unit to form CO which is ultimately discharged into the environment. 2 This is not ideal because CO 2 is a known greenhouse gas. As disclosed herein, the coke in such a process may react with oxygen in a stripping zone to form CO 2 , which is combined with the olefin product. In one or more embodiments, CO 2 It can subsequently be separated from the olefin product and not released into the environment.

[0006] According to one or more embodiments described herein, olefin compounds can be formed by a method including contacting a feed stream containing one or more hydrocarbons with a particulate solid in a reactor. In the reactor, the one or more hydrocarbons can be reacted to form one or more olefin compounds, and coke can be formed on the particulate solid. The method may also include transferring the particulate solid from the reactor to a stripping zone. In the stripping zone, the particulate solid can be contacted with a stripping gas and oxygen. The stripping gas may include nitrogen, steam, or a combination thereof. In the stripping zone, most of the coke can react with oxygen to form carbon dioxide. Most of the carbon dioxide produced in the stripping zone is transferred from the stripping zone and combined with the one or more olefin compounds. The method may also include transferring the particulate solid from the stripping zone to a regeneration unit, wherein the particulate solid can be heated by burning fuel in the regeneration unit. The method may also include transferring at least a portion of the particulate solid from the regeneration unit to the reactor.

[0007] It should be understood that both the foregoing general description and the following detailed description describe various embodiments and are intended to provide an overview or framework for understanding the nature and characteristics of the claimed subject matter. Additional features and advantages of the embodiments will be set forth in the specific embodiments, and in part, will be readily apparent to those of ordinary skill in the art from the description, including the drawings and claims, or may be recognized by practicing the described embodiments. The drawings are included to provide a further understanding of the embodiments, and together with the specific embodiments, to explain the principles and operation of the claimed subject matter. However, the embodiments depicted in the drawings are illustrative and exemplary in nature, and are not intended to limit the claimed subject matter. BRIEF DESCRIPTION OF THE DRAWINGS

[0008] Reference will now be made in more detail to various embodiments, some of which are illustrated in the accompanying drawings, in which:

[0009] Figure 1 schematically depicts a reactor system according to one or more embodiments of the present disclosure; and

[0010] Figure 2 Another reactor system according to additional embodiments of the present disclosure is schematically depicted.

[0011] When describing Figure 1 and Figure 2 While the simplified schematic illustration of FIG. 1 does not include the many valves, temperature sensors, electronic controllers, etc. that may be used and are well known to those of ordinary skill in the art, are not included. In addition, the accompanying components that are typically included in such reactor systems, such as air supply, heat exchangers, buffer tanks, etc., are also not included. However, it should be understood that these components are within the scope of the present disclosure. DETAILED DESCRIPTION

[0012] The specific embodiments of the application will now be described. However, the present disclosure can be implemented in different forms and should not be construed as being limited to the embodiments set forth in the present disclosure. On the contrary, these embodiments are provided so that the present disclosure will be thorough and complete, and will fully convey the scope of the subject matter to those skilled in the art.

[0013] In the present invention, a method for producing light olefins such as propylene is described in detail below. Figure 1 and Figure 2 The embodiments disclosed herein are described in detail in the context of a reactor system for a reactor system. However, it should be understood that the principles disclosed and taught herein can be applied to other systems utilizing different system components oriented in different ways, or to different reaction schemes utilizing various catalyst compositions. For example, the concepts described are equally applicable to other systems having alternative reactor units and regeneration units, such as those operating under non-fluidized conditions, or those systems including downcomers instead of risers. It should also be understood that not all systems are identical. Figure 1 and Figure 2 All parts of the reactor system should be construed as being essential to the claimed subject matter.

[0014] Reference now Figure 1 , schematically depicts an exemplary reactor system 102 that may be suitable for use with the methods and / or apparatus described herein. The reactor system 102 generally includes a plurality of system components, such as a reactor portion 200 and a regeneration unit 300. As used herein, a "system component" refers to a portion of the reactor system 102, such as a reactor, a separator, a transfer line, a combination thereof, and the like. As used herein, Figure 1 As used in the context of , reactor section 200 generally refers to the portion of reactor system 102 where the primary process reaction (e.g., dehydrogenation) occurs to form a product stream. A feed stream enters reactor section 200, is converted into a product stream (containing product and unreacted feed), and exits reactor section 200. Reactor section 200 includes reactor 202, which may include an upstream reactor section 250 and a downstream reactor section 230. According to one or more embodiments, as Figure 1As depicted, the reactor portion 200 may further include a granular solid separation section 210 for separating granular solids from chemical products formed in the reactor 202. The granular solids may be passed through a stripping zone 224 before being passed to the regeneration unit 300. In the stripping zone 224, an oxygen-containing gas may enter the stripping zone 224 through a first gas inlet 520. The stripping gas may enter the stripping zone 224 through a second gas inlet 510. The granular solids may be exposed to an oxygen-containing gas in the stripping zone 224 before being passed to the regeneration unit 300. In addition, as used herein, the regeneration unit 300 generally refers to a portion of the reactor system 102 in which the granular solids are treated in some way, such as by combustion, to, for example, improve catalytic activity and / or heat the catalyst. The regeneration unit 300 may include a burner 350 and a riser 330, and may further include a granular solid separation section 310. In one or more embodiments, the particulate solids separation section 210 can be in fluid communication with the combustor 350 (eg, via a standpipe 426), and the particulate solids separation section 310 can be in fluid communication with the upstream reactor section 250 (eg, via a standpipe 424 and a transport riser 430).

[0015] Generally, as described in this article, Figure 1 and Figure 2 In the embodiment shown, particulate solids are circulated between the reactor section 200 and the regeneration unit 300. It should be understood that when particulate solids are referred to herein, they may refer to solid materials that are catalytically active for the desired reaction, or may also refer to reference granules. Figure 1 and Figure 2The system mentioned in the present invention does not necessarily have catalytic activity but affects other particulate solids of the reaction, such as oxygen carrier materials. The terms "catalytic activity" and "catalyst activity" refer to the extent to which the particulate solid can catalyze the reaction carried out in the reactor system 102. The particulate solids leaving the reactor section 200 can be deactivated particulate solids. As used herein, "deactivated" can refer to particulate solids with reduced catalytic activity or cooler than the particulate solids entering the reactor section 200. However, deactivated particulate solids can retain some catalytic activity. Reduced catalytic activity can be caused by contamination of substances such as coke. Reactivation (sometimes referred to as "regeneration" in this article) can remove pollutants such as coke, increase the temperature of the particulate solids, or both. In an embodiment, before the particulate solids are transferred to the regeneration unit 300, most of the coke formed on the particulate solids can react with oxygen in the stripping zone 224. In an embodiment, the deactivated particulate solids can be reactivated by reactivating the particulate solids in the regeneration unit 300. The deactivated particulate solids may be reactivated by, but not limited to, removing coke by combustion, restoring catalyst acidity, oxidizing the particulate solids, other reactivation processes, or combinations thereof. In some embodiments, the particulate solids may be heated during reactivation by burning a fuel such as hydrogen, methane, ethane, propane, natural gas, or a combination thereof. The reactivated particulate solids from the regeneration unit 300 may then be transferred back to the reactor section 200.

[0016] The feed stream can enter the feed inlet 434, enter the reactor 202, and the product stream can exit the reactor system 102 via the pipe 420. According to one or more embodiments, the reactor system 102 can be operated by feeding a chemical feed (e.g., in a feed stream) and a fluidized particulate solid into the upstream reactor section 250. The chemical feed contacts the particulate solid in the upstream reactor section 250, and each chemical feed flows upward into and through the downstream reactor section 230 to produce a chemical product.

[0017] Now refer to the detailed Figure 1 , the reactor section 200 may include an upstream reactor section 250, a transition section 258, and a downstream reactor section 230, such as a riser. The transition section 258 may connect the upstream reactor section 250 with the downstream reactor section 230. Figure 1 As depicted, the upstream reactor section 250 can be positioned below the downstream reactor section 230. Such a configuration can be referred to as an upflow configuration in the reactor 202. The upstream reactor section 250 can include a container, a drum, a barrel, a barrel, or other container suitable for a given chemical reaction. Figure 1As depicted, the upstream reactor section 250 may be connected to the downstream reactor section 230 via a transition section 258. The upstream reactor section 250 may generally include a larger cross-sectional area than the downstream reactor section 230. The transition section 258 may taper from the size of the cross-section of the upstream reactor section 250 to the size of the cross-section of the downstream reactor section 230 such that the transition section 258 protrudes inwardly from the upstream reactor section 250 to the downstream reactor section 230. For example, the transition section 258 may be a frustum.

[0018] The upstream reactor section 250 may be connected to a transfer riser 430 which, in operation, may provide the reactivated particulate solids in the feed stream to the reactor portion 200. The reactivated catalyst and / or reactant chemicals may be mixed with a distributor 260 contained in the upstream reactor section 250. The particulate solids entering the upstream reactor section 250 via the transfer riser 430 may be passed to the transfer riser 430 via a standpipe 424, thereby arriving from the regeneration unit 300. In some embodiments, the particulate solids may enter the transfer riser 430 directly from the particulate solids separation section 210 via a standpipe 422, wherein the particulate solids enter the upstream reactor section 250, wherein in such embodiments, some of the particulate solids are not passed through the regeneration unit 300. The particulate solids may also be fed directly to the upstream reactor section 250 via the standpipe 422 (at Figure 1 250). This particulate solid may be somewhat deactivated, but may still be suitable for reaction in the upstream reactor section 250 in some embodiments, particularly when used in combination with a reactivated particulate solid.

[0019] Still refer to Figure 1 In one or more embodiments, based on the shapes, dimensions, and other process conditions (such as temperature and pressure) in the upstream reactor section 250 and the downstream reactor section 230, the upstream reactor section 250 can be operated as a fluidized bed, such as in a fast fluidized, turbulent, or bubbling bed flow reactor, while the downstream reactor section 230 can be operated in a more plug flow manner, such as in a riser reactor. For example, Figure 1The reactor 202 may include an upstream reactor section 250 operated as a fast fluidization, turbulent or bubbling bed reactor and a downstream reactor section 230 operated as a dilute phase riser reactor, resulting in an average granular solid and gas flow moving upward simultaneously. As used herein, the term "average flow" refers to the net flow, i.e., the total upward flow minus the reverse or reverse flow, which is generally the typical behavior of fluidized particles. As described herein, a "fast fluidization" reactor may refer to a reactor utilizing a fluidization scheme in which the superficial velocity of the gas phase is greater than the choke velocity and may be semi-dense in operation. As described herein, a "turbulent" reactor may refer to a fluidization scheme in which the superficial velocity is less than the choke velocity and is denser than a fast fluidization scheme. As described herein, a "bubbling bed" reactor may refer to a fluidization morphology in which well-defined bubbles in a high dense bed are present in two well-divided phases. "Choke velocity" refers to the minimum velocity required to maintain solids in a dilute phase mode in a vertical transport line. As used herein, "dilute phase riser" may refer to a riser reactor operating at a transport velocity, wherein the gas and particulate solids have approximately the same velocity in the dilute phase.

[0020] According to embodiments, the chemical products and particulate solids may be transferred from the downstream reactor section 230 to a separation device 220 in the particulate solids separation section 210 where the particulate solids are separated from the chemical products that are conveyed from the particulate solids separation section 210. According to one or more embodiments, after the particulate solids are separated from the vapor in the separation device 220, the particulate solids may generally move through a stripping zone 224 to a particulate solids outlet port 222 where the particulate solids are transferred out of the reactor portion 200 via a standpipe 426 and into a regeneration unit 300.

[0021] According to one or more embodiments, the stripping zone 224 may include a first gas inlet 520 and a second gas inlet 510. The stripping zone 224 is an area where stripping can occur. Stripping is a process in which entrained and adsorbed products and reactants in the reactor are removed from particulate solids using a stripping gas. For example, ethane, ethylene and other hydrocarbon byproducts can be removed during the dehydrogenation process of ethane stripping. An oxygen-containing gas may enter the stripping zone 224 through the first gas inlet 520. The stripping gas may enter the stripping zone 224 through the second gas inlet 510. In some embodiments, the stripping gas may include nitrogen, steam, or a combination thereof.

[0022] The granular solids can move through the stripping zone 224 in a generally downward direction. As used in the present disclosure, the term "generally downward direction" means that the average velocity of the granular solids is in a downward direction, wherein the downward direction is subject to the force of gravity. Since it is an average value, the velocity of a single particle of the granular solid can have a distribution and may not be equal to the average value, but as a whole, the velocity of the granular solid will be averaged to be generally downward. According to an embodiment, the gas in the stripping zone 224 can move through the stripping zone 224 in a generally upward direction. As used in the present disclosure, the term "generally upward direction" means that the average velocity of the gas in the stripping zone 224 is in an upward direction, wherein the upward direction is opposite to the force of gravity. Since it is an average value, the velocity of the gas molecules in the stripping zone 224 can have a distribution and may not be equal to the average value, but as a whole, the velocity of the gas will be averaged to be generally upward. According to an embodiment, the granular solids and the gas can move through the stripping zone 224 in a countercurrent flow mode.

[0023] In one or more embodiments, the first gas inlet 520 can be located above the second gas inlet 510, such as Figure 1 In some embodiments, the first gas inlet 520 can be located below the second gas inlet 510. In some embodiments, the first gas inlet 520 and the second gas inlet 510 can be at the same height within the stripping zone 224.

[0024] As described herein, in one or more embodiments, the oxygen-containing gas can enter the stripping zone 224 through the first gas inlet 520. In some embodiments, the oxygen-containing gas can be air, enriched air, air mixed with steam, or flue gas. Enriched air is air to which oxygen has been added. In some embodiments, the oxygen-containing gas can contain at least 28 mol.% oxygen. In other embodiments, the oxygen-containing gas can contain about 2 mol.% to about 28 mol.% oxygen, about 2 mol.% to about 25 mol.% oxygen, about 2 mol.% to about 20 mol.% oxygen, about 2 mol.% to about 15 mol.% oxygen, about 2 mol.% to about 10 mol.% oxygen, about 2 mol.% to about 5 mol.% oxygen, about 5 mol.% to about 28 mol.% oxygen, about 5 mol.% to about 25 mol.% oxygen, about 5 mol.% to about 20 mol.% oxygen, about 5 mol.% to about 15 mol.% oxygen, about 5 mol.% to about 28 mol.% oxygen, about 5 mol.% to about 25 mol.% oxygen, about 5 mol.% to about 20 mol.% oxygen, about 5 mol.% to about 15 mol.% oxygen, about 5 mol.% % oxygen, about 10 mol.% to about 28 mol.% oxygen, about 10 mol.% to about 25 mol.% oxygen, about 10 mol.% to about 20 mol.% oxygen, about 10 mol.% to about 15 mol.% oxygen, about 15 mol.% to about 28 mol.% oxygen, about 15 mol.% to about 25 mol.% oxygen, about 15 mol.% to about 20 mol.% oxygen, about 20 mol.% to about 28 mol.% oxygen, about 20 mol.% to about 25 mol.% oxygen, or about 25 mol.% to about 28 mol.% oxygen. In some embodiments, at least a portion of the coke formed on the particulate solids can react with the oxygen in the stripping zone 224 to produce carbon dioxide. In some embodiments, at least 95 wt.% of the coke can react in the stripping zone 224. In other embodiments, about 75 wt.% to about 99 wt.% of the coke may be reacted in the stripping zone 224, such as about 75 wt.% to about 95 wt.%, about 75 wt.% to about 90 wt.%, about 75 wt.% to about 85 wt.%, about 75 wt.% to about 80 wt.%, about 80 wt.% to about 99 wt.%, about 80 wt.% to about 95 wt.%, about 80 wt.% to about 85 wt.%, about 85 wt.% to about 99 wt.%, about 85 wt.% to about 95 wt.%, about 85 wt.% to about 90 wt.%, about 90 wt.% to about 99 wt.%, about 90 wt.% to about 95 wt.%, or about 95 wt.% to about 99 wt.%. In some embodiments, the particulate solids may contain less than 1.0 wt.% of coke when passed to the regeneration unit 300.

[0025] As described herein, most of the carbon dioxide produced in the method described herein can be produced in the stripping zone, subsequently transferred out from the stripping zone and combined with one or more olefin compounds. Specifically, in one or more embodiments, at least 80wt.% of the total coke reacted in the stripping zone and the regeneration unit can be reacted in the stripping zone. For example, according to the various embodiments considered, at least 85wt.%, at least 90wt.%, at least 95wt.% or even at least 99wt.% of the total coke reacted in the stripping zone and the regeneration unit can be reacted in the stripping zone. In addition, most of the carbon dioxide (greater than 50mol.%) produced in the stripping zone can be transferred out from the stripping zone and combined with one or more olefin compounds, such as at least 60mol.%, at least 70mol.%, 80mol.%, 90mol.%, 95mol.% or even 99mol.%. The combination of these two schemes can make the overwhelming majority of the carbon dioxide produced be transferred out from the reactor system 102 by the stream comprising the reaction product, rather than being transferred out by the flue gas stream discharged from the regeneration unit 300.

[0026] Without being bound by theory, it is believed that by exposing the particulate solids to the oxygen-containing gas in the stripping zone 224, coke that may form on the particulate solids may be primarily combusted in the stripping zone 224, with less combustion (such as virtually no coke combustion) occurring in the regeneration unit 300. Combusting the coke may produce CO 2 , and when CO 2 When mixed with other gases (such as hydrocarbons), relatively complex downstream separation and processing steps may be required. The product stream may already require downstream processing and separation steps, so according to one or more embodiments, it may be advantageous to separate much of the CO produced. 2 Passed through the same stream as the product to take advantage of downstream processing and separation operations that already need to be performed. 2 Passed to the atmosphere via flue gases.

[0027] In one or more embodiments, the addition of an oxygen-containing gas to the stripping zone 224 and the flow of the particulate solids and the oxygen-containing gas through the stripping zone 224 in a countercurrent flow pattern can combine to burn most or substantially all of the coke formed on the particulate solids within the stripping zone 224. This stripping zone 224 configuration can allow the particulate solids to enter the regeneration unit 300 with little or no coke formed on the particulate solids, which can reduce or eliminate CO buildup within the regeneration unit 300. 2 In the example of using hydrogen as the fuel in the regeneration unit 300, the main component of the exhaust from the regeneration unit 300 may be water, which can be safely discharged to the atmosphere, thereby limiting the necessary treatment of the exhaust from the regeneration unit and reducing the cost of operating the reactor system.

[0028] In one or more embodiments, the stripping zone 224 may include a third gas inlet 530, into which the fuel may be injected. In one or more embodiments, the fuel may enter the stripping zone 224 through the third gas inlet 530. In some embodiments, the third gas inlet 530 may be located above the first gas inlet 520 and the second gas inlet 510. In some embodiments, the third gas inlet 530 may be located between the first gas inlet 520 and the second gas inlet 510. In some embodiments, the third gas inlet 530 may be located below the first gas inlet 520 and the second gas inlet 510. In some embodiments, the third gas inlet 530 may be at the same height as the first gas inlet 520 and the second gas inlet 510. In some embodiments, the fuel may include hydrogen, methane, ethane, propane, natural gas, or a combination thereof. In some embodiments, the concentration of the fuel in the stripping zone 224 may be greater than 20 mol.%. In some embodiments, the concentration of the fuel in the stripping zone 224 can be about 5 mol.% to about 20 mol.%, about 5 mol.% to about 15 mol.%, about 5 mol.% to about 10 mol.%, about 10 mol.% to about 20 mol.%, about 10 mol.% to about 15 mol.%, or about 15 mol.% to about 20 mol.%. In some embodiments, the stripping zone 224 may not include the third gas inlet 530 ( Figure 1 not shown).

[0029] Reference now Figure 2 Reactor system 102, reactor system 104 and Figure 1 540, except that the stripping zone includes a single gas inlet 540. Thus, in one or more embodiments, oxygen in the oxygen-containing gas and the stripping gas can enter the stripping zone 224 through the gas inlet 540. For example, these streams can be combined upstream of the inlet to the stripping zone 224. In some embodiments, a mixture of steam and air can enter the stripping zone 224 through the gas inlet 540. In some embodiments, air can enter the stripping zone 224 through the gas inlet 540. In embodiments where the stripping zone includes a single gas inlet 540, the particulate solids and gas within the stripping zone 224 can move in a countercurrent flow pattern because the particulate solids move in a generally downward direction and the gas moves through the stripping zone 224 in a generally upward direction.

[0030] In other embodiments, oxygen and nitrogen can be delivered to the stripping zone 224 as an air stream through a single gas inlet, such as inlet 540. In such embodiments, since air contains both nitrogen and oxygen, the air stream contains at least nitrogen as the stripping gas as well as oxygen. Such an embodiment can eliminate the need for separate oxygen-containing gas streams and stripping gas streams.

[0031] Now return to reference Figure 1 According to one or more embodiments, the separation device 220 may be a cyclonic separation system, which may include two or more cyclonic separation stages. In the embodiment in which the separation device 220 includes more than one cyclonic separation stage, the first separation device in which the fluidized stream enters is referred to as a primary cyclonic separation device. The fluidized effluent from the primary cyclonic separation device may enter a secondary cyclonic separation device for further separation. The primary cyclonic separation device may include, for example, a primary cyclonic separator and a system commercially available under the name VSS (commercially available from UOP), LD2 (commercially available from Stone and Webster), and RS2 (commercially available from Stone and Webster). Primary cyclonic separators are described in, for example, U.S. Patents 4,579,716, 5,190,650, and 5,275,641, each of which is incorporated herein by reference in its entirety. In some separation systems utilizing a primary cyclone separator as a primary cyclone separation device, one or more additional cyclone separators, e.g., a secondary cyclone separator and a tertiary cyclone separator, are used to further separate particulate solids from the product gas. It should be understood that any primary cyclone separation device may be used in embodiments of the present invention.

[0032] Still refer to Figure 1, the separated particulate solids are transferred from the particulate solid separation section 210 to the burner 350. In the burner 350, the particulate solids can be processed by, for example, combustion with oxygen. For example, but not limited to, the particulate solids can be decoked and / or a fuel can be combusted to heat the particulate solids. The particulate solids are then transferred out of the burner 350 and through the riser 330 to the riser terminal separator 378, where the gas and solid components from the riser 330 are at least partially separated. The steam and the remaining solids are transported to the secondary separation device 320 in the particulate solid separation section 310, where the remaining particulate solids are separated from the gas from the particulate solid treatment (for example, the gas emitted by burning the spent particulate solids or fuel, referred to herein as flue gas). The flue gas can be transferred out of the regeneration unit 300 via the outlet pipe 432. In one or more embodiments, the flue gas passing out of the regeneration unit 300 via the outlet pipe 432 may contain less than 5 mol.% carbon dioxide (e.g., less than or equal to 4 mol.%, 3 mol.%, 2 mol.%, 1 mol.%, or even 0.5 mol.% or 0.25 mol.%). In some embodiments, the flue gas passing out of the regeneration unit 300 via the outlet pipe 432 may not contain carbon dioxide. The separated particulate solids are then passed to the upstream reactor section 250 via the standpipe 424 and the transport riser 430 through the oxygen treatment zone 370 within the particulate solid separation section 310, where the particulate solids are further used for catalytic reactions. Thus, in operation, the particulate solids can be circulated between the reactor section 200 and the regeneration unit 300. Generally speaking, the processed chemical streams including the feed stream and the product stream can be gaseous, and the particulate solids can be fluidized particulate solids.

[0033] Now referring to the regeneration unit 300, as Figure 1As depicted, the burner 350 of the regeneration unit 300 may include one or more lower reactor section inlet ports 352 and may be in fluid communication with the riser 330. An oxygen-containing gas (e.g., air) may be delivered to the burner 350 via a pipe 428. The burner 350 may be in fluid communication with the granular solids separation section 210 via a riser 426, which may supply spent granular solids from the reactor section 200 to the regeneration unit 300 for regeneration. The burner 350 and the riser 330 (collectively referred to as the granular solids combustion reactor 302) may be operated in a fluidization scheme similar or identical to that disclosed with respect to the upstream reactor section 250 and the downstream reactor section 230 of the reactor section 200. That is, the burner 350 may be operated as a fluidized bed, such as in a fast fluidized, turbulent, or bubbling bed flow reactor, while the riser 330 may be operated in a more plug flow manner, such as in a riser reactor. The geometries described with respect to the upstream reactor section 250 and the downstream reactor section 230 may be equally applicable to the burner 350 and the riser 330. In addition, the burner 350 may also include a fuel inlet 354 that may supply a fuel to the burner 350, such as a hydrocarbon stream or hydrogen.

[0034] As described in one or more embodiments, after the particulate solids are separated from the flue gas in the riser terminal separator 378 and the secondary separation device 320, the processed particulate solids are treated with an oxygen-containing gas in the oxygen treatment zone 370. In some embodiments, the oxygen treatment zone 370 includes a fluid solid contact device. The fluid solid contact device may include a baffle or a grid structure to promote contact between the processed particulate solids and the oxygen-containing gas. Examples of fluid solid contact devices are further described in detail in U.S. Patents Nos. 9,827,543 and 9,815,040. The fluidization scheme in the oxygen treatment zone 370 can be a bubbling bed type fluidization. The oxygen treatment zone 370 may include an oxygen-containing gas inlet 372, which can supply oxygen-containing gas to the oxygen treatment zone 370 for oxygen treatment of the particulate solids.

[0035] In a non-limiting example, the reactor system 102 described herein can be used to produce olefin compounds from a hydrocarbon feed stream. As used herein, the term "olefin compound" refers to a hydrocarbon having one or more carbon-carbon double bonds in addition to the formal double bonds in aromatic compounds. For example, ethylene and styrene are olefin compounds, but ethylbenzene is not an olefin compound because the only double bond present in ethylbenzene is a formal double bond that exists as part of the aromatic structure. Olefin compounds can be produced from various hydrocarbon feed streams using different reaction mechanisms. For example, olefin compounds can be produced by at least dehydrogenation reactions, cracking reactions, dehydration reactions, and methanol to olefin reactions. These reaction types can utilize different feed streams and different particulate solids to produce olefin compounds. It should be understood that when "catalysts" are mentioned herein, these catalysts can also refer to catalysts related to Figure 1 and Figure 2 The system refers to the particulate solids.

[0036] According to one or more embodiments, the reaction can be a dehydrogenation reaction. According to such embodiments, one or more hydrocarbons can be a hydrocarbon feed stream, which can include one or more of ethylbenzene, ethane, propane, n-butane and isobutane. In one or more embodiments, the hydrocarbon feed stream can include at least 50wt.%, at least 60wt.%, at least 70wt.%, at least 80wt.%, at least 90wt.%, at least 95wt.% or even at least 99wt.% of ethylbenzene. In one or more embodiments, the hydrocarbon feed stream can include at least 50wt.%, at least 60wt.%, at least 70wt.%, at least 80wt.%, at least 90wt.%, at least 95wt.% or even at least 99wt.% of ethane. In other embodiments, the hydrocarbon feed stream can include at least 50wt.%, at least 60wt.%, at least 70wt.%, at least 80wt.%, at least 90wt.%, at least 95wt.% or even at least 99wt.% of propane. In other embodiments, the hydrocarbon feed stream may contain at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.%, or even at least 99 wt.% of n-butane. In other embodiments, the hydrocarbon feed stream may contain at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.%, or even at least 99 wt.% of isobutane. In other embodiments, the hydrocarbon feed stream may contain at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.%, or even at least 99 wt.% of the sum of ethylbenzene, ethane, propane, n-butane, and isobutane.

[0037] In one or more embodiments, the dehydrogenation reaction can utilize gallium and / or platinum granular solids as catalysts. In such embodiments, the granular solids can include gallium and / or platinum catalysts. As described herein, the gallium and / or platinum catalysts include gallium, platinum, or both. The gallium and / or platinum catalysts can be supported by an alumina or alumina silica carrier and can optionally include potassium. Such gallium and / or platinum catalysts are disclosed in U.S. Patent No. 8,669,406, which is incorporated herein by reference in its entirety. However, it should be understood that other suitable catalysts can be utilized to carry out the dehydrogenation reaction.

[0038] In one or more embodiments, the reaction mechanism can be dehydrogenation followed by combustion (in the same chamber). In such embodiments, the dehydrogenation reaction can produce hydrogen as a byproduct, and the oxygen-carrying material can contact the hydrogen and promote the combustion of the hydrogen, thereby forming water. Examples of such reaction mechanisms are disclosed in WO 2020 / 046978 and U.S. Patent Publication 2021 / 0292259, which are considered possible reaction mechanisms for the systems and methods described herein, and the teachings of these documents are incorporated herein by reference in their entirety.

[0039] In one or more embodiments, the granulated solid may include an oxygen carrier material and a dehydrogenation catalyst material. In some embodiments, the granulated solid may be substantially composed of an oxygen carrier material. As described herein, "substantially composed of" refers to a material with less than 1wt.% of unlisted materials (i.e., substantially composed of A means that A accounts for at least 99wt.% of the composition). In some embodiments, the granulated solid may not include a dehydrogenation catalyst material. In some embodiments, the oxygen carrier material and the dehydrogenation catalyst material may be separate particles of the granulated solid. In some embodiments, the oxygen carrier material and the dehydrogenation catalyst may be contained in the same particles of the granulated solid.

[0040] In embodiments where the particulate solid comprises a dehydrogenation catalyst, the dehydrogenation of one or more hydrocarbons may be at least partially carried out by catalytic dehydrogenation. Catalytic dehydrogenation is the dehydrogenation of hydrocarbons promoted by the use of a dehydrogenation catalyst. In embodiments where the particulate solid does not comprise a dehydrogenation catalyst, the dehydrogenation reaction may be a non-catalytic thermal dehydrogenation reaction. Non-catalytic thermal dehydrogenation refers to the dehydrogenation of hydrocarbons that occurs due to high temperature, pressure, or a combination thereof without the use of a dehydrogenation catalyst.

[0041] In some embodiments, the particulate solid may comprise a "dual use material" that can serve as both a dehydrogenation catalyst and an oxygen carrier material. It should be understood that at least the oxygen carrier material and the dehydrogenation catalyst described herein are used in the same reaction vessel (such as Figure 1In embodiments in which the reaction vessel is provided, this dual-purpose material can be used in place of or in combination with a particulate solid oxygen carrier material and a particulate solid dehydrogenation catalyst.

[0042] According to one or more embodiments, the reaction can be a cracking reaction. According to such embodiments, the hydrocarbon feed stream can include one or more of naphtha, normal butane or isobutane. According to one or more embodiments, the hydrocarbon feed stream can include at least 50wt.%, at least 60wt.%, at least 70wt.%, at least 80wt.%, at least 90wt.%, at least 95wt.% or even at least 99wt.% of naphtha. In other embodiments, the hydrocarbon feed stream can include at least 50wt.%, at least 60wt.%, at least 70wt.%, at least 80wt.%, at least 90wt.%, at least 95wt.% or even at least 99wt.% of normal butane. In other embodiments, the hydrocarbon feed stream can include at least 50wt.%, at least 60wt.%, at least 70wt.%, at least 80wt.%, at least 90wt.%, at least 95wt.% or even at least 99wt.% of isobutane. In other embodiments, the hydrocarbon feed stream may comprise at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.%, or even at least 99 wt.% of the sum of naphtha, n-butane, and isobutane.

[0043] In one or more embodiments, the cracking reaction can utilize one or more zeolites as catalysts. In such embodiments, the granular solid can include one or more zeolites. In some embodiments, the one or more zeolites utilized in the cracking reaction can include ZSM-5 zeolite. However, it should be understood that other suitable catalysts can be utilized to carry out the cracking reaction. For example, commercially available suitable catalysts can include Intercat Super Z Excel or Intercat Super Z Exceed. In other embodiments, in addition to the catalytically active material, the cracking catalyst can also include platinum. For example, the cracking catalyst can include 0.001wt.% to 0.05wt.% of platinum. Platinum can be sprayed in the form of platinum nitrate and calcined at an elevated temperature (such as about 700°C). Without being bound by theory, it is believed that adding platinum to the catalyst can allow fuels such as methane to be burned more easily.

[0044] According to one or more embodiments, the reaction can be a dehydration reaction. According to such embodiments, the hydrocarbon feed stream can include one or more of ethanol, propanol or butanol. According to one or more embodiments, the hydrocarbon feed stream can include at least 50wt.%, at least 60wt.%, at least 70wt.%, at least 80wt.%, at least 90wt.%, at least 95wt.% or even at least 99wt.% of ethanol. In other embodiments, the hydrocarbon feed stream can include at least 50wt.%, at least 60wt.%, at least 70wt.%, at least 80wt.%, at least 90wt.%, at least 95wt.% or even at least 99wt.% of propanol. In other embodiments, the hydrocarbon feed stream can include at least 50wt.%, at least 60wt.%, at least 70wt.%, at least 80wt.%, at least 90wt.%, at least 95wt.% or even at least 99wt.% of butanol. In further embodiments, the hydrocarbon feed stream may comprise at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.%, or even at least 99 wt.% of the sum of ethanol, propanol, and butanol.

[0045] In one or more embodiments, the dehydration reaction can utilize one or more acid catalysts. In such embodiments, the granular solid can include one or more acid catalysts. In some embodiments, the one or more acid catalysts utilized in the dehydration reaction can include zeolite (such as ZSM-5 zeolite), aluminum oxide, amorphous aluminosilicate, acid clay or a combination thereof. For example, according to one or more embodiments, suitable commercially available alumina catalysts include SynDol (available from Scientific Design Company), V200 (available from UOP) or P200 (available from Sasol). Suitable commercially available zeolite catalysts include CBV 8014, CBV 28014 (available from Zeolyst). Suitable commercially available amorphous aluminosilicate catalysts include silica-alumina catalyst carriers, 135 grades (available from Sigma Aldrich). However, it should be understood that other suitable catalysts can be utilized to carry out the dehydration reaction.

[0046] According to one or more embodiments, the reaction can be a methanol to olefins reaction. According to such embodiments, the hydrocarbon feed stream can contain methanol. According to one or more embodiments, the hydrocarbon feed stream can contain at least 50 wt.%, at least 60 wt.%, at least 70 wt.%, at least 80 wt.%, at least 90 wt.%, at least 95 wt.%, or even at least 99 wt.% methanol.

[0047] In one or more embodiments, the methanol to olefins reaction can utilize one or more zeolites as catalyst. In such embodiments, the granular solid can include one or more zeolites. In some embodiments, the one or more zeolites utilized in the methanol to olefins reaction can include one or more of ZSM-5 zeolite or SAPO-34 zeolite. However, it should be understood that other suitable catalysts can be utilized to carry out the methanol to olefins reaction.

[0048] In one or more embodiments, the granular solid may be capable of fluidization. In some embodiments, the granular solid may exhibit characteristics known in the industry as "Geldart A" or "Geldart B" characteristics. According to D. Geldart, "Gas Fluidization Technology", John Wiley & Sons (New York, 1986), pp. 34-37; and D. Geldart, "Types of Gas Fluidization", Powder Technol. 7 (1973) 285-292, the entire contents of which are incorporated herein by reference, particles can be classified as "Group A" or "Group B".

[0049] Group A is understood by those skilled in the art to represent aerated powders with fluidization in the bubble-free range; high bed expansion; slow and linear degassing rate; bubble characteristics, which may include a predominance of splitting / re-coalescing bubbles, with maximum bubble size and large wake; high levels of solid mixing and gas backmixing, assuming that U-umf are equal (U is the velocity of the carrier gas, and Umf is the minimum fluidizing velocity, usually but not necessarily measured in meters per second (m / s), i.e., there is too high a gas velocity); axisymmetric bulk characteristics; and no spurting except in very shallow beds. The listed characteristics tend to improve with decreasing average particle size, assuming equal cfp; or with increasing proportions <45 microns (μm); or with increasing pressure, temperature, viscosity and density of the gas. In general, the particles may exhibit a small average particle size and / or a low particle density (<1.4 grams per cubic centimeter, g / cm 3) It is easily fluidized, with smooth fluidization at low gas velocities; and it can exhibit controlled bubbling with small bubbles at higher gas velocities. +

[0050] Group B is understood by those skilled in the art to represent "sand-like" powders, which start to bubble at Umf; exhibit moderate bed expansion; rapid degassing; have no limitation on bubble size; moderate levels of solid mixing and gas backmixing, assuming equal U - umf; both axisymmetric and asymmetric agglomerates; and spout only in shallow beds. These characteristics tend to improve with decreasing average particle size, but the particle size distribution and certain uncertainties in the gas, pressure, temperature, viscosity, or density seem to have little effect on improving these characteristics. Generally, when the density (pp) is 1.4 < pp < 4 g / cm 3 ³, the particle size (cfp) of most particles is 40 μm < cfp < 500 μm, and preferably, when the density (pp) is 4 g / cm 3 ³, the particle size of most particles is 60 μm < cfp < 500 μm, and when the density (pp) is 1 g / cm 3 ³, the particle size of most particles is 250 μm < cfp < 1000 μm.

[0051] In one or more embodiments, an olefin compound may be present in a "product stream" sometimes referred to as an "olefin-containing effluent". This stream leaves Figure 1The reactor system of olefins can be subsequently processed. In one or more embodiments, the olefin compound can include one or more of ethylene, propylene, butene or styrene. The term butene includes any butene isomer, such as α-butene, cis-β-butene, trans-β-butene and isobutylene. In some embodiments, the olefin-containing effluent can include at least 50wt.%, at least 60wt.%, at least 70wt.%, at least 80wt.%, at least 90wt.%, at least 95wt.% or even at least 99wt.% ethylene. In other embodiments, the olefin-containing effluent can include at least 50wt.%, at least 60wt.%, at least 70wt.%, at least 80wt.%, at least 90wt.%, at least 95wt.% or even at least 99wt.% propylene. In other embodiments, olefin-containing effluent can comprise at least 50wt.%, at least 60wt.%, at least 70wt.%, at least 80wt.%, at least 90wt.%, at least 95wt.% or even at least 99wt.% of butene. In other embodiments, olefin-containing effluent can comprise at least 50wt.%, at least 60wt.%, at least 70wt.%, at least 80wt.%, at least 90wt.%, at least 95wt.% or even at least 99wt.% of styrene. In other embodiments, olefin-containing effluent can comprise at least 50wt.%, at least 60wt.%, at least 70wt.%, at least 80wt.%, at least 90wt.%, at least 95wt.% or even at least 99wt.% of the sum of ethylene, propylene, butene and styrene. Olefin-containing effluent can also comprise the unreacted components of feed stream and other reaction products that are not considered to be light olefins. Olefin compounds can be separated with unreacted components in subsequent separation steps.

[0052] Several aspects are currently disclosed herein. The first aspect is a method for forming olefin compounds, the method comprising: contacting a feed stream comprising one or more hydrocarbons with a particulate solid in a reactor, wherein in the reactor: the one or more hydrocarbons react to form one or more olefin compounds; and coke is formed on the particulate solid; the particulate solid is transferred from the reactor to a stripping zone, wherein: the particulate solid is contacted with a stripping gas and oxygen in the stripping zone; the stripping gas comprises nitrogen, steam, or a combination thereof; in the stripping zone, a majority of the coke reacts with oxygen to form carbon dioxide; a majority of the carbon dioxide produced in the stripping zone is transferred from the stripping zone and combined with the one or more olefin compounds; the particulate solid is transferred from the stripping zone to a regeneration unit, wherein the particulate solid is heated by burning a fuel in the regeneration unit; and at least a portion of the particulate solid is transferred from the regeneration unit to the reactor.

[0053] Another aspect includes any of the preceding aspects or combinations of aspects, wherein at least 80 wt. % of the total coke reacted in the stripping zone and the regeneration unit is reacted in the stripping zone.

[0054] Another aspect includes any preceding aspect or combination of aspects, wherein the particulate solid comprises less than 1.0 wt. % coke when passed to the regeneration unit.

[0055] Another aspect includes any preceding aspect or combination of aspects, wherein the particulate solid moves through the stripping zone in a generally downward direction and the gas moves through the stripping zone in a generally upward direction such that the particulate solid and the gas move through the stripping zone in a countercurrent flow pattern.

[0056] Another aspect includes any preceding aspect or combination of aspects, wherein the oxygen is delivered to the stripping zone in an oxygen-containing gas, and the oxygen-containing gas and the stripping gas enter the stripping zone through separate gas inlets.

[0057] Another aspect includes any of the foregoing aspects or combinations of aspects, wherein the stripping zone comprises a first gas inlet, a second gas inlet and a third gas inlet, and wherein: the oxygen-containing gas enters the stripping zone through the first gas inlet; the stripping gas enters the stripping zone through the second gas inlet; the fuel enters the stripping zone through the third gas inlet; the first gas inlet is located above the second gas inlet; and the third gas inlet is located above the first gas inlet.

[0058] Another aspect includes any of the preceding aspects or combinations of aspects, wherein the stripping gas comprises nitrogen, and the oxygen and the nitrogen are delivered as air streams into the stripping zone through a single gas inlet.

[0059] Another aspect includes any preceding aspect or combination of aspects, wherein the fuel comprises hydrogen.

[0060] Another aspect includes any of the preceding aspects or combinations of aspects, wherein the amount of carbon dioxide in the flue gas from the regeneration unit is less than or equal to 0.5 mol. % of the flue gas.

[0061] Another aspect includes any preceding aspect or combination of aspects, wherein a portion of the particulate solids is withdrawn from the stripping zone and transferred to the reactor without first passing through the regeneration unit.

[0062] Another aspect includes any of the preceding aspects or combinations of aspects, wherein the reaction in the reactor is a dehydrogenation reaction; the one or more hydrocarbons include ethylbenzene, ethane, propane, n-butane, isobutane, or a combination thereof; and the particulate solid comprises a dehydrogenation catalyst, an oxygen support material, or both.

[0063] Another aspect includes any of the preceding aspects or combinations of aspects, wherein the reaction in the reactor is a non-catalytic thermal dehydrogenation reaction; the one or more hydrocarbons include ethylbenzene, ethane, propane, n-butane, isobutane, or a combination thereof; and the particulate solid consists essentially of an oxygen carrier material.

[0064] Another aspect includes any preceding aspect or combination of aspects, wherein the reaction in the reactor is a cracking reaction; the one or more hydrocarbons include naphtha, n-butane, isobutane, or a combination thereof; and the particulate solid includes one or more zeolites.

[0065] Another aspect includes any preceding aspect or combination of aspects, wherein: the reaction in the reactor is a dehydration reaction; the one or more hydrocarbons include ethanol, propanol, butanol, or a combination thereof; and the particulate solid includes one or more acid catalysts.

[0066] Another aspect includes any preceding aspect or combination of aspects, wherein: the reaction in the reactor is a methanol to olefins reaction; the one or more hydrocarbons can include methanol; and the particulate solid includes one or more zeolites.

[0067] It will be apparent to those skilled in the art that various modifications and variations may be made to the technology disclosed in the present invention without departing from the spirit and scope of the technology. Because those skilled in the art may make modifications, combinations, sub-combinations and variations of the disclosed embodiments that incorporate the spirit and essence of the technology disclosed in the present invention, the technology should be interpreted as including everything within the scope of the attached claims and their equivalents. In addition, although some aspects of the present disclosure may be identified herein as preferred or particularly advantageous, it is contemplated that the present disclosure is not limited to these aspects.

[0068] It should be noted that the various details described in the present disclosure should not be considered to imply that these details relate to elements that are essential components of the various embodiments described in the present disclosure, even in the case where specific elements are shown in each of the drawings attached to this specification. Unless so explicitly stated, the features disclosed and described herein should not be interpreted as "essential". Contemplated embodiments of the present technology include those that include some or all of the features of the appended claims.

[0069] For purposes of describing and defining the present disclosure, it is noted that the term "about" is used herein to represent the inherent degree of uncertainty that may be attributed to any quantitative comparison, value, measurement, or other representation. The term "about" is also utilized herein to represent the degree by which a quantitative representation may vary from a stated reference without resulting in a change in the basic function of the subject matter at issue.

[0070] Where relevant, where a composition is described as “comprising” one or more elements, embodiments of the composition “consisting of” or “consisting essentially of” those one or more elements are contemplated herein.

[0071] In some embodiments, a chemical or chemical stream is described as being "transferred" from one system unit or a portion of a system unit to another system unit or a portion of a system unit. As described herein, such transfer may include direct transfer or indirect transfer. For example, when transferring from "unit A" to "unit B", direct transfer has no intermediate destinations between unit A and unit B (i.e., directly through a pipe or other transport channel), and indirect transfer may include one or more intermediate destinations between unit A and unit B. For example, a stream transferred from unit A to unit B may be transferred through, but not limited to, a heat exchanger, a processing unit, etc.

[0072] It should be understood that in some embodiments, the composition range of the chemical composition in a stream or reactor should be understood as a mixture of isomers containing the composition. For example, a composition range specifying butenes can include a mixture of various isomers of butenes. It should be understood that the embodiments provide composition ranges for various streams, and the total amount of isomers of a specific chemical composition can constitute a range.

[0073] It should be noted that one or more of the following claims and detailed description utilize the term "wherein" or "wherein" as a transition phrase. For purposes of defining the present technology, it should be noted that this term is introduced in the claims as an open transition phrase that is used to introduce a recitation of a series of features of a structure and should be interpreted in a manner similar to the more commonly used open-ended preamble term "comprising."

[0074] It should be understood that any two quantitative values ​​assigned to a characteristic may constitute a range for that characteristic, and all combinations of ranges formed by all of the quantitative values ​​for a given characteristic are considered in the present disclosure. Where multiple ranges of quantitative values ​​are provided, these ranges may be combined to form a wider range, which is contemplated in the embodiments described herein.

Claims

1. A method for forming an olefin compound, the method comprising: A feed stream comprising one or more hydrocarbons is contacted with a particulate solid in a reactor wherein: The one or more hydrocarbons react to form one or more olefin compounds; and forming coke on the particulate solid; The particulate solids are transferred from the reactor to a stripping zone wherein: contacting the particulate solid with a stripping gas and oxygen in the stripping zone; The stripping gas comprises nitrogen, steam or a combination thereof; In the stripping zone, a majority of the coke reacts with oxygen to form carbon dioxide; transferring a majority of the carbon dioxide produced in the stripping zone away from the stripping zone and combining with the one or more olefinic compounds; transferring the particulate solids from the stripping zone to a regeneration unit, wherein the particulate solids are heated by combusting a fuel in the regeneration unit; and At least a portion of the particulate solids is transferred from the regeneration unit to the reactor.

2. The process according to claim 1, wherein at least 80 wt. % of the total coke reacted in the stripping zone and the regeneration unit is reacted in the stripping zone.

3. The process of claim 1 wherein the particulate solids contain less than 1.0 wt. % coke when passed to the regeneration unit.

4. The method of claim 1, wherein the particulate solids move through the stripping zone in a generally downward direction and the gas moves through the stripping zone in a generally upward direction such that the particulate solids and the gas move through the stripping zone in a countercurrent flow pattern.

5. A process according to any one of the preceding claims, wherein the oxygen is delivered to the stripping zone in an oxygen-containing gas, and the oxygen-containing gas and the stripping gas enter the stripping zone through separate gas inlets.

6. The process of claim 5, wherein the stripping zone comprises a first gas inlet, a second gas inlet and a third gas inlet, and wherein: The oxygen-containing gas enters the stripping zone through the first gas inlet; The stripping gas enters the stripping zone through the second gas inlet; Fuel enters the stripping zone through the third gas inlet; The first gas inlet is located above the second gas inlet; and The third gas inlet is located above the first gas inlet.

7. The process according to any one of claims 1 to 4, wherein the stripping gas comprises nitrogen, and the oxygen and the nitrogen are delivered as air streams into the stripping zone through a single gas inlet.

8. A method according to any one of the preceding claims, wherein the fuel comprises hydrogen.

9. The method according to any one of the preceding claims, wherein the amount of carbon dioxide in the flue gases coming from the regeneration unit is less than or equal to 0.5 mol.% of the flue gases.

10. A process according to any one of the preceding claims, wherein a portion of the particulate solids is withdrawn from the stripping zone and passed to the reactor without first passing through the regeneration unit.

11. The method according to claim 1, wherein: The reaction in the reactor is a dehydrogenation reaction; The one or more hydrocarbons include ethylbenzene, ethane, propane, n-butane, isobutane, or a combination thereof; and The particulate solid comprises a dehydrogenation catalyst, an oxygen support material, or both.

12. The method of claim 1, wherein: The reaction in the reactor is a non-catalytic thermal dehydrogenation reaction; The one or more hydrocarbons include ethylbenzene, ethane, propane, n-butane, isobutane, or a combination thereof; and The particulate solid consists essentially of oxygen carrier material.

13. The method of claim 1, wherein: The reaction in the reactor is a cracking reaction; The one or more hydrocarbons include naphtha, n-butane, isobutane, or a combination thereof; and The particulate solid comprises one or more zeolites.

14. The method of claim 1, wherein: The reaction in the reactor is a dehydration reaction; The one or more hydrocarbons include ethanol, propanol, butanol, or a combination thereof; and The particulate solid includes one or more acid catalysts.

15. The method of claim 1, wherein: The reaction in the reactor is a methanol to olefins reaction; The one or more hydrocarbons may include methanol; and The particulate solid comprises one or more zeolites.

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