Hydrocarbon reaction method using a stripper

Abstract

According to one or more embodiments described herein, olefinic compounds may be formed by a process including 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 react to form one or more olefinic compounds, and coke may form on the particulate solid. The particulate solid may be passed from the reactor to a strip zone. In the strip zone, the particulate solid may be contacted with a strip gas and oxygen. The strip gas may include nitrogen, steam, or a combination thereof. In the strip zone, a majority of the coke may react with oxygen to form carbon dioxide. A majority of the carbon dioxide produced in the strip zone may be discharged from the strip zone and combined with the one or more olefinic compounds.

Description

[Technical Field]

[0001] (CROSS-REFERENCE TO RELATED APPLICATIONS) This application claims the benefit of U.S. Provisional Application No. 63 / 406,445, filed September 14, 2022, the entire disclosure of which is incorporated herein by reference.

[0002] FIELD OF THE INVENTION FIELD OF THE INVENTION Embodiments described herein relate generally to chemical processing, and more particularly to methods and systems utilized in the formation of olefinic compounds. [Background technology]

[0003] Olefin compounds can be used as base materials to produce many types of goods and materials. For example, ethylene can be used to produce polyethylene, ethylene chloride, or ethylene oxide. Such products can be used in packaging products, construction, fibers, etc. Therefore, there is an industrial demand for olefin compounds such as ethylene, propylene, butene, and styrene. Summary of the Invention

[0004] Olefinic compounds can be formed from a variety of hydrocarbon feeds. For example, olefinic materials can be formed by the dehydrogenation (catalytic or thermal) of alkanes. Some of these processes utilize particulate solids, which can generally be circulated between a reactor and a regeneration unit. In such processes, coke can form on the particulate solids. In many conventional processes, the coke is burned in the regeneration unit to form CO2, which is ultimately emitted into the environment. This is not ideal because CO2 is a known greenhouse gas. As disclosed herein, the coke in such processes can react with oxygen in a strip zone to form CO2, which is combined with the olefin product. In one or more embodiments, the CO2 can then be separated from the olefin product and not released into the environment.

[0005] According to one or more embodiments described herein, olefinic compounds may be formed by a process including contacting a feed stream containing one or more hydrocarbons with particulate solids in a reactor. In the reactor, the one or more hydrocarbons react to form one or more olefinic compounds, and coke may form on the particulate solids. The process may further include passing the particulate solids from the reactor to a strip zone. In the strip zone, the particulate solids may be contacted with a strip gas and oxygen. The strip gas may include nitrogen, steam, or a combination thereof. In the strip zone, a majority of the coke may react with oxygen to form carbon dioxide. A majority of the carbon dioxide produced in the strip zone may be discharged from the strip zone and combined with the one or more olefinic compounds. The method may further include passing the particulate solids from the strip zone to a regeneration unit, where the particulate solids may be heated by combustion of fuel in the regeneration unit. The method may further include passing at least a portion of the particulate solids from the regeneration unit to the reactor.

[0006] 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 features of the claimed subject matter. Additional features and advantages of the embodiments are set forth in the detailed description, and in part will become readily apparent to those skilled in the art from that description, including the accompanying drawings and claims, or can be learned by practicing the described embodiments. The drawings are included to provide a further understanding of the embodiments and, together with the detailed description, serve to explain the principles and operation of the claimed subject matter. However, the embodiments shown in the drawings are illustrative and exemplary in nature and are not intended to limit the claimed subject matter. [Brief explanation of the drawings]

[0007] Reference will now be made in more detail to various embodiments, some of which are illustrated in the accompanying drawings. [Figure 1] FIG. 1 is a schematic diagram illustrating a reactor system according to one or more embodiments of the present disclosure. [Figure 2] FIG. 10 is a schematic diagram of another reactor system according to an additional embodiment of the present disclosure.

[0008] 1 and 2, the numerous valves, temperature sensors, electronic controllers, etc. that may be used and that are well known to those skilled in the art are not included. Additionally, accompanying components that are often included within such reactor systems, such as air supplies, heat exchangers, surge tanks, etc., are also not included. However, it should be understood that these components are within the scope of the present disclosure. DETAILED DESCRIPTION OF THE INVENTION

[0009] Specific embodiments of the present application will now be described. However, this disclosure may be embodied in different forms and should not be construed as limited to the embodiments set forth in this disclosure. Rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the present subject matter to those skilled in the art.

[0010] The embodiments disclosed herein are described in detail herein in the context of the reactor system of Figures 1 and 2 operating as a fluidized dehydrogenation reactor system for producing light olefins, such as propylene. However, it should be understood that the principles disclosed and taught herein may be applicable to other systems utilizing different system components oriented in a different manner, or to different reaction schemes utilizing various catalyst compositions. For example, the concepts described may be equally applicable to other systems with alternative reactor and regeneration units, such as those operating under non-fluidized conditions or those including a downer rather than a riser. Furthermore, it should be understood that not all parts of the reactor systems of Figures 1 and 2 should be construed as essential to the claimed subject matter.

[0011] Referring now to FIG. 1 , an exemplary reactor system 102 that may be suitable for use with the methods and / or apparatus described herein is shown schematically. The reactor system 102 generally comprises multiple system components, such as a reactor section 200 and a regeneration unit 300. As described herein, a “system component” refers to a portion of the reactor system 102, such as a reactor, a separator, a transfer line, or a combination thereof. As used herein in the context of FIG. 1 , the reactor section 200 generally refers to the portion of the reactor system 102 where the primary process reaction (e.g., dehydrogenation) occurs to form a product stream. A feed stream enters the reactor section 200, is converted to a product stream (containing products and unreacted feed), and exits the reactor section 200. The reactor section 200 includes a reactor 202, which may comprise an upstream reactor section 250 and a downstream reactor section 230. According to one or more embodiments, as shown in FIG. 1 , reactor section 200 may further include a particulate solids separation section 210 that serves to separate particulate solids from chemical products formed in reactor 202. The particulate solids may pass through strip zone 224 before being sent to regeneration unit 300. In strip zone 224, an oxygen-containing gas may enter strip zone 224 through first gas inlet 520. Strip gas may enter strip zone 224 through second gas inlet 510. The particulate solids may be exposed to the oxygen-containing gas in strip zone 224 before being sent to regeneration unit 300. Also, as used herein, regeneration unit 300 generally refers to the portion of reactor system 102 that processes the particulate solids in some manner, such as by combustion, to improve catalytic activity and / or heat the particulate solids. Regeneration unit 300 may include a combustor 350 and a riser 330, and may further include particulate solids separation section 310. In one or more embodiments, the particulate solids separation section 210 can be in fluid communication with the combustor 350 (e.g., via a water tower 426), and the particulate solids separation section 310 can be in fluid communication with the upstream reactor section 250 (e.g., via a water tower 424 and a transfer riser 430).

[0012] Generally, as described herein, in the embodiment illustrated in FIGS. 1 and 2 , particulate solids are circulated between the reactor section 200 and the regeneration unit 300. It should be understood that references to particulate solids herein may refer to solid materials that are catalytically active for a desired reaction, or may equally refer to other particulate solids mentioned with respect to the systems of FIGS. 1 and 2 that do not necessarily have catalytic activity but affect the reaction, such as oxygen carrier materials. The terms “catalytic activity” and “catalyst activity” refer to the degree to which a particulate solid is capable of catalyzing a reaction taking place within the reactor system 102. The particulate solids exiting the reactor section 200 may be deactivated particulate solids. As used herein, “deactivated” may refer to particulate solids that are less catalytically active or cooler than the particulate solids entering the reactor section 200. However, deactivated particulate solids may retain some catalytic activity. The reduced catalytic activity may be due to contamination with substances such as coke. Reactivation (sometimes referred to herein as "regeneration") can remove contaminants such as coke, increase the temperature of the particulate solids, or both. In embodiments, a majority of the coke formed on the particulate solids can be reacted with oxygen in strip zone 224 before the particulate solids are sent to regeneration unit 300. In embodiments, deactivated particulate solids can be reactivated by particulate solid reactivation in regeneration unit 300. Deactivated particulate solids can be reactivated by, but are 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 can be heated during reactivation by combustion of a fuel such as hydrogen, methane, ethane, propane, natural gas, or combinations thereof. The reactivated particulate solids from regeneration unit 300 can then be returned to reactor section 200.

[0013] A feed stream may enter reactor 202 through feed inlet 434, and a product stream may exit reactor system 102 via pipe 420. According to one or more embodiments, reactor system 102 may be operated by feeding a chemical feed (e.g., in a feed stream) and fluidized particulate solids to upstream reactor section 250. The chemical feed contacts the particulate solids in upstream reactor section 250, and each flows upward into and through downstream reactor section 230 to produce chemical products.

[0014] Referring now in detail to FIG. 1 , the reactor section 200 may comprise an upstream reactor section 250, a transfer section 258, and a downstream reactor section 230, such as a riser. The transfer section 258 may connect the upstream reactor section 250 with the downstream reactor section 230. As shown in FIG. 1 , the upstream reactor section 250 may be disposed below the downstream reactor section 230. Such a configuration may be referred to as an upflow configuration for the reactor 202. The upstream reactor section 250 may comprise a vessel, drum, barrel, vat, or other vessel suitable for a given chemical reaction. As shown in FIG. 1 , the upstream reactor section 250 may be connected to the downstream reactor section 230 via the transfer section 258. The upstream reactor section 250 may generally comprise a larger cross-sectional area than the downstream reactor section 230. The transfer section 258 may taper from the cross-sectional size of the upstream reactor section 250 to the cross-sectional size of the downstream reactor section 230 such that the transfer section 258 projects inward from the upstream reactor section 250 toward the downstream reactor section 230. For example, the transfer section 258 may be a frustum.

[0015] The upstream reactor section 250 can be connected to a transfer riser 430 that can provide reactivated particulate solids in the feed stream to the reactor section 200 during operation. The reactivated catalyst and / or reaction chemicals can be mixed in a distributor 260 housed within the upstream reactor section 250. The particulate solids entering the upstream reactor section 250 via the transfer riser 430 can pass through the transfer riser 430 via a distributor 424 and thus arrive 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 distributor 422, in which case the particulate solids enter the upstream reactor section 250; in such embodiments, a portion of the particulate solids do not pass through the regeneration unit 300. The particulate solids can also be fed directly to the upstream reactor section 250 via the distributor 422 (not shown in FIG. 1 ). This particulate solid may be somewhat deactivated, but may still be suitable for reaction in upstream reactor section 250 in some embodiments, especially when used in conjunction with reactivated particulate solid.

[0016] 1 , in one or more embodiments, based on the shape, size, and other process conditions (such as temperature and pressure) of the upstream reactor section 250 and the downstream reactor section 230, the upstream reactor section 250 can operate as a fluidized bed, such as a fast fluidized bed, turbulent bed, or bubbling bed upflow reactor, while the downstream reactor section 230 can operate more in a plug flow regime, such as a riser reactor. For example, the reactor 202 of FIG. 1 may have the upstream reactor section 250 operating as a fast fluidized bed, turbulent bed, or bubbling bed reactor and the downstream reactor section 230 operating as a dilute-phase riser reactor, such that the average particulate solids and gas flow move upward simultaneously. "Average flow," as that term is used herein, refers to net flow, i.e., total upward flow minus countercurrent or reflux, as is generally typical of fluidized particle behavior. As described herein, a "fast fluidization" reactor may refer to a reactor utilizing a fluidization regime in which the superficial velocity of the gas phase is greater than the choking velocity and may be semi-dense during operation. As described herein, a "turbulent" reactor may refer to a fluidization regime in which the superficial velocity is less than the choking velocity and the fluid is denser than the fast fluidization regime. As described herein, a "bubble bed" reactor may refer to a fluidization regime in which well-defined bubbles in a dense bed exist in two distinct phases. "Choking velocity" refers to the minimum velocity required to maintain solids in a dilute phase mode in a vertical conveying line. As described herein, a "dilute phase riser" may refer to a riser reactor operating at a conveying velocity, in which the gas and particulate solids have approximately the same velocity in the dilute phase.

[0017] According to an embodiment, the chemical products and particulate solids may be discharged from downstream reactor section 230 and sent to separator 220 in particulate solids separation section 210, where the particulate solids are separated from the chemical products and the chemical products are transported out of particulate solids separation section 210. According to one or more embodiments, following separation from the vapor in separator 220, the particulate solids may generally travel through strip zone 224 to particulate solids outlet port 222, where the particulate solids are transported out of reactor section 200 via water column 426 to regeneration unit 300.

[0018] According to one or more embodiments, the strip zone 224 may include a first gas inlet 520 and a second gas inlet 510. The strip zone 224 is an area where stripping may occur. Stripping is a process in which entrained and adsorbed products and reactants from a reactor may be removed from particulate solids by use of a strip gas. For example, during ethane dehydrogenation, stripping may remove ethane, ethylene, and other hydrocarbon by-products. An oxygen-containing gas may enter the strip zone 224 through the first gas inlet 520. A strip gas may enter the strip zone 224 through the second gas inlet 510. In some embodiments, the strip gas may include nitrogen, steam, or a combination thereof.

[0019] The particulate solids may move in a generally downward direction through the strip zone 224. As used herein, the term "generally downward direction" means that the average velocity of the particulate solids is a downward direction, and the downward direction is due to the downward force of gravity. As an average, the velocity of individual particles of the particulate solids may vary and not equal the average, but overall, the velocity of the particulate solids is generally downward on average. According to embodiments, the gas within the strip zone 224 may move in a generally upward direction through the strip zone 224. As used herein, the term "generally upward direction" means that the average velocity of the gas within the strip zone 224 is an upward direction, and the upward direction counters the downward force of gravity. As an average, the velocity of the gas molecules within the strip zone 224 may vary and not equal the average, but overall, the velocity of the gas is generally upward on average. According to embodiments, the particulate solids and gas may move in a countercurrent pattern through the strip zone 224.

[0020] 1, the first gas inlet 520 may be above the second gas inlet 510. In some embodiments, the first gas inlet 520 may be below the second gas inlet 510. In some embodiments, the first gas inlet 520 and the second gas inlet 510 may be at the same height within the strip zone 224.

[0021] As described herein, in one or more embodiments, an oxygen-containing gas may enter the strip zone 224 through the first gas inlet 520. In some embodiments, the oxygen-containing gas may be air, enriched air, air mixed with steam, or flue gas. Enriched air refers to air with added oxygen. In some embodiments, the oxygen-containing gas may contain at least 28 mol% oxygen. In other embodiments, the oxygen-containing gas may contain between about 2 mol% and about 28 mol%, between about 2 mol% and about 25 mol%, between about 2 mol% and about 20 mol%, between about 2 mol% and about 15 mol%, between about 2 mol% and about 10 mol%, between about 2 mol% and about 5 mol%, between about 5 mol% and about 28 mol%, between about 5 mol% and about 25 mol%, between about 5 mol% and about 20 mol%, between about 5 mol% and about 15 mol%, or between about 5 mol% and about 1 The oxygen content may be 0 mol%, about 10 mol% to about 28 mol%, about 10 mol% to about 25 mol%, about 10 mol% to about 20 mol%, about 10 mol% to about 15 mol%, about 15 mol% to about 28 mol%, about 15 mol% to about 25 mol%, about 15 mol% to about 20 mol%, about 20 mol% to about 28 mol%, about 20 mol% to about 25 mol%, or about 25 mol% to about 28 mol% oxygen. In some embodiments, at least a portion of the coke formed on the particulate solids may react with oxygen in strip zone 224 to produce carbon dioxide. In some embodiments, at least 95 wt% of the coke may be reacted in strip zone 224. In other embodiments, about 75% to about 99% by weight of the coke may be reacted in strip zone 224, e.g., about 75% to about 95% by weight, about 75% to about 90% by weight, about 75% to about 85% by weight, about 75% to about 80% by weight, about 80% to about 99% by weight, about 80% to about 95% by weight, about 80% to about 85% by weight, about 85% to about 99% by weight, about 85% to about 95% by weight, about 85% to about 90% by weight, about 90% to about 99% by weight, about 90% to about 95% by weight, or about 95% to about 99% by weight of the coke. In some embodiments, the particulate solids may contain less than 1.0% by weight of coke when sent to regeneration unit 300.

[0022] As described herein, a majority of the carbon dioxide produced in the processes described herein may be produced in the strip zone and subsequently discharged from the strip zone and combined with one or more olefin compounds. In particular, in one or more embodiments, at least 80 wt. % of the total coke reacted in the strip zone and regeneration unit may be reacted in the strip zone. For example, according to various contemplated embodiments, at least 85 wt. %, at least 90 wt. %, at least 95 wt. %, or even at least 99 wt. % of the total coke reacted in the strip zone and regeneration unit may be reacted in the strip zone. Furthermore, a majority (greater than 50 mol. %) of the carbon dioxide produced in the strip zone may be discharged from the strip zone and combined with one or more olefin compounds, such as at least 60 mol. %, at least 70 mol. %, 80 mol. %, 90 mol. %, 95 mol. %, or even 99 mol. %. The combination of these two schemes allows a majority of the produced carbon dioxide to be discharged from the reactor system 102 in a stream containing the reaction products rather than in the flue gas stream exiting the regeneration unit 300.

[0023] Without being bound by theory, it is believed that by exposing the particulate solids to an oxygen-containing gas in strip zone 224, any coke that may form on the particulate solids is burned primarily in strip zone 224 and to a lesser extent (e.g., little coke combustion) in regeneration unit 300. The combustion of coke may produce CO2, which may require relatively difficult downstream separation and processing steps when mixed with other gases, such as hydrocarbons. The product stream may already require downstream processing and separation steps, and therefore, according to one or more embodiments, it may be advantageous to pass much of the CO2 produced through the same stream as the product to take advantage of the downstream processing and separation operations already required. Therefore, less CO2 is sent to the atmosphere via the flue gas.

[0024] In one or more embodiments, the addition of oxygen-containing gas to strip zone 224, in combination with flowing the particulate solids and oxygen-containing gas in a countercurrent pattern through strip zone 224, can combust most or essentially all of the coke that forms on the particulate solids in strip zone 224. Such a configuration of strip zone 224 allows the particulate solids to enter regeneration unit 300 with little or no coke forming on the particulate solids, potentially reducing or eliminating CO2 production within regeneration unit 300. In examples where the fuel used in regeneration unit 300 is hydrogen, the primary component of the exhaust from regeneration unit 300 can be water, which can be safely released to the atmosphere, limiting the required amount of treatment of the regeneration unit exhaust and reducing the cost of operating the reactor system.

[0025] In one or more embodiments, the strip zone 224 may include a third gas inlet 530 through which fuel may be injected. In one or more embodiments, the fuel may enter the strip zone 224 through the third gas inlet 530. In some embodiments, the third gas inlet 530 may be above the first gas inlet 520 and the second gas inlet 510. In some embodiments, the third gas inlet 530 may be between the first gas inlet 520 and the second gas inlet 510. In some embodiments, the third gas inlet 530 may be 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 elevation 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 fuel in the strip zone 224 may be greater than 20 mole %. In some embodiments, the concentration of fuel in strip zone 224 can be between about 5 mol% and about 20 mol%, between about 5 mol% and about 15 mol%, between about 5 mol% and about 10 mol%, between about 10 mol% and about 20 mol%, between about 10 mol% and about 15 mol%, or between about 15 mol% and about 20 mol%. In some embodiments, strip zone 224 may not include third gas inlet 530 (not shown in FIG. 1).

[0026] Referring now to reactor system 102 of FIG. 2, reactor system 104 is identical to reactor system 102 of FIG. 1, except that the strip zone includes a single gas inlet 540. Accordingly, in one or more embodiments, the oxygen-containing gas and the oxygen in the strip gas may enter strip zone 224 through gas inlet 540. For example, these streams may be combined upstream of the inlet to strip zone 224. In some embodiments, a mixture of steam and air may enter strip zone 224 through gas inlet 540. In some embodiments, air may enter strip zone 224 through gas inlet 540. In embodiments in which the strip zone includes a single gas inlet 540, the particulate solids and gas within strip zone 224 may move in a countercurrent pattern as the particulate solids move in a generally downward direction through strip zone 224 and the gas moves in a generally upward direction.

[0027] In additional embodiments, oxygen and nitrogen may be passed as an air stream through a single gas inlet (such as inlet 540) to strip zone 224. In such embodiments, since air contains both nitrogen and oxygen, the air stream contains at least nitrogen as a strip gas and also contains oxygen. Such embodiments may eliminate the need for separate oxygen-containing and stripping gas streams.

[0028] Returning to FIG. 1 , according to one or more embodiments, separator 220 may be a cyclonic separation system that may include two or more stages of cyclonic separation. In embodiments in which separator 220 includes more than one cyclonic separation stage, the first separator into which the fluidized stream enters is referred to as the primary cyclonic separator. The fluidized effluent from the primary cyclonic separator may enter a secondary cyclonic separator for further separation. Primary cyclonic separators may include, for example, primary cyclones and systems commercially available under the names VSS (commercially available from UOP), LD2 (commercially available from Stone and Webster), and RS2 (commercially available from Stone and Webster). Primary cyclones are described, for example, in U.S. Pat. Nos. 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 as the primary cyclone separator, one or more sets of additional cyclones, e.g., secondary and tertiary cyclones, are used to further separate the particulate solids from the product gas. It should be understood that any primary cyclone separator may be used in embodiments of the present invention.

[0029] Continuing with reference to FIG. 1 , the separated particulate solids travel from the particulate solids separation section 210 to a combustor 350. In the combustor 350, the particulate solids may be processed, for example, by combustion with oxygen. For example, but not limited to, the particulate solids may be decoked and / or a fuel may be combusted to heat the particulate solids. The particulate solids then exit the combustor 350 through a riser 330 to an end-of-riser separator 378, where the gas and solid components from the riser 330 are at least partially separated. The vapor and remaining solids are transferred to a secondary separator 320 within the particulate solids separation section 310, where the remaining particulate solids are separated from gases from the particulate solids processing (e.g., gases emitted by the combustion of spent particulate solids or fuel, referred to herein as flue gas). The flue gas may exit the regeneration unit 300 via an outlet pipe 432. In one or more embodiments, the flue gas exiting the regeneration unit 300 via the outlet pipe 432 may contain less than 5 mol% carbon dioxide (e.g., in additional embodiments, 4 mol%, 3 mol%, 2 mol%, 1 mol%, or even 0.5 mol% or 0.25 mol% or less). In some embodiments, the flue gas exiting the regeneration unit 300 via the outlet pipe 432 may not contain any carbon dioxide. The separated particulate solids then travel via the water column 424 and the transfer riser 430 through the oxygen treatment zone 370 in the particulate solids separation section 310 to the upstream reactor section 250, where they are further utilized in catalytic reactions. Thus, during operation, the particulate solids may circulate between the reactor section 200 and the regeneration unit 300. Generally, the treated chemical streams, including the feed stream and the product stream, may be gaseous, and the particulate solids may be fluidized particulate solids.

[0030] Referring now to regeneration unit 300, as shown in FIG. 1 , combustor 350 of regeneration unit 300 may include one or more lower reactor section inlet ports 352 and may be in fluid communication with riser 330. An oxygen-containing gas, such as air, may travel to combustor 350 through pipe 428. Combustor 350 may be in fluid communication with particulate solids separation section 210 via water column 426, which may deliver spent particulate solids from reactor section 200 to regeneration unit 300 for regeneration. Combustor 350 and riser 330, collectively referred to as particulate solids combustion reactor 302, may operate with a fluidization regime similar to or identical to that disclosed for upstream reactor section 250 and downstream reactor section 230 of reactor section 200. That is, the combustor 350 may operate as a fluidized bed, such as in a fast fluidized bed, turbulent bed, or bubbling bed upflow reactor, while the riser 330 may operate more in a plug flow regime, such as a riser reactor. The geometries described with respect to the upstream reactor section 250 and the downstream reactor section 230 are equally applicable to the combustor 350 and the riser 330. Additionally, the combustor 350 may also include a fuel inlet 354 through which a fuel, such as a hydrocarbon stream or hydrogen, may be supplied to the combustor 350.

[0031] As described in one or more embodiments, following separation of the flue gas from the particulate solids in the end-of-riser separator 378 and secondary separation unit 320, treatment of the treated particulate solids with an oxygen-containing gas occurs in oxygen treatment zone 370. In some embodiments, oxygen treatment zone 370 comprises a fluid-solid contactor. The fluid-solid contactor may include a baffle or grid structure to facilitate contact of the treated particulate solids with the oxygen-containing gas. Examples of fluid-solid contactors are described in more detail in U.S. Pat. Nos. 9,827,543 and 9,815,040. The fluidization regime within oxygen treatment zone 370 may be bubbling bed fluidization. Oxygen treatment zone 370 may include an oxygen-containing gas inlet 372 through which an oxygen-containing gas may be delivered to oxygen treatment zone 370 for oxygen treatment of the particulate solids.

[0032] In a non-limiting example, the reactor system 102 described herein can be utilized to produce olefinic compounds from a hydrocarbon feed stream. As used herein, the term "olefinic compound" refers to a hydrocarbon having one or more carbon-carbon double bonds, separate from the formal double bonds present in aromatic compounds. For example, ethylene and styrene are olefinic compounds, but ethylbenzene is not an olefinic compound because the only double bonds present in ethylbenzene are formal double bonds present as part of the aromatic structure. Olefinic compounds can be produced from a wide variety of hydrocarbon feed streams by utilizing different reaction mechanisms. For example, olefinic 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 olefinic compounds. It should be understood that when "catalysts" are referred to herein, they can equally refer to the particulate solids referred to with respect to the systems of FIGS. 1 and 2.

[0033] According to one or more embodiments, the reaction may be a dehydrogenation reaction. According to such embodiments, the one or more hydrocarbons may be a hydrocarbon feed stream, and the hydrocarbon feed stream may include one or more of ethylbenzene, ethane, propane, n-butane, and i-butane. In one or more embodiments, the hydrocarbon feed stream may include 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% ethylbenzene. In one or more embodiments, the hydrocarbon feed stream may include 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% ethane. In additional embodiments, the hydrocarbon feed stream may include 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% propane. In additional 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% n-butane. In additional 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% i-butane. In additional 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 total of ethylbenzene, ethane, propane, n-butane, and i-butane.

[0034] In one or more embodiments, the dehydrogenation reaction may utilize a gallium and / or platinum particulate solid as a catalyst. In such embodiments, the particulate solid may include a gallium and / or platinum catalyst. As described herein, the gallium and / or platinum catalyst includes gallium, platinum, or both. The gallium and / or platinum catalyst may be supported on an alumina or alumina-silica support and may optionally include potassium. Such gallium and / or platinum catalysts are disclosed in U.S. Pat. No. 8,669,406, the entire contents of which are incorporated herein by reference. However, it should be understood that other suitable catalysts may be utilized to carry out the dehydrogenation reaction.

[0035] In one or more embodiments, the reaction mechanism may be dehydrogenation followed by combustion (in the same chamber). In such embodiments, the dehydrogenation reaction may produce hydrogen as a by-product, and the oxygen carrier material may contact the hydrogen to promote combustion of the hydrogen to form water. Examples of such reaction mechanisms contemplated as possible reaction mechanisms for the systems and methods described herein are disclosed in International Publication No. WO 2020 / 046978 and U.S. Patent Application Publication No. 2021 / 0292259, the teachings of which are incorporated herein by reference in their entireties.

[0036] In one or more embodiments, the particulate solid may include an oxygen carrier material and a dehydrogenation catalyst material. In some embodiments, the particulate solid may consist essentially of an oxygen carrier material. As used herein, "consisting essentially of" refers to a material that contains less than 1 wt. % of an unlisted material (i.e., consisting essentially of A means that A is at least 99 wt. % of the composition). In some embodiments, the particulate 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 particulate solid. In some embodiments, the oxygen carrier material and the dehydrogenation catalyst may be contained in the same particle of the particulate solid.

[0037] In embodiments in which the particulate solid comprises a dehydrogenation catalyst, the dehydrogenation of one or more hydrocarbons may be at least partially due to catalytic dehydrogenation. Catalytic dehydrogenation is the dehydrogenation of hydrocarbons facilitated by the use of a dehydrogenation catalyst. In embodiments in which 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 does not utilize a dehydrogenation catalyst and may instead occur through high temperature, high pressure, or a combination thereof.

[0038] In some embodiments, the particulate solid may comprise a "dual-purpose material" that can act as both a dehydrogenation catalyst and an oxygen carrier material. It should be understood that in at least the embodiments described herein in which an oxygen carrier material and a dehydrogenation catalyst are utilized in the same reactor vessel (such as that of FIG. 1), such a dual-purpose material may be utilized in place of or in combination with the particulate solid oxygen carrier material or the particulate solid dehydrogenation catalyst.

[0039] According to one or more embodiments, the reaction may be a cracking reaction. According to such embodiments, the hydrocarbon feed stream may comprise one or more of naphtha, n-butane, or i-butane. According to one or more 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% naphtha. In additional 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% n-butane. In additional 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% i-butane. In additional 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 total of naphtha, n-butane, and i-butane.

[0040] In one or more embodiments, the cracking reaction may utilize one or more zeolites as a catalyst. In such embodiments, the particulate solid may include one or more zeolites. In some embodiments, the one or more zeolites utilized in the cracking reaction may include ZSM-5 zeolite. However, it should be understood that other suitable catalysts may be utilized to carry out the cracking reaction. For example, suitable commercially available catalysts may include Intercat Super Z Excel or Intercat Super Z Exceed. In additional embodiments, the cracking catalyst may include platinum in addition to the catalytically active material. For example, the cracking catalyst may include 0.001% to 0.05% by weight of platinum. The platinum may be sprayed as platinum nitrate and calcined at a high temperature, such as about 700°C. Without being bound by theory, it is believed that the addition of platinum to the catalyst may enable easier combustion of fuels such as methane.

[0041] According to one or more embodiments, the reaction may be a dehydration reaction. According to such embodiments, the hydrocarbon feed stream may comprise one or more of ethanol, propanol, or butanol. According to one or more 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% ethanol. In additional 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% propanol. In additional 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% butanol. In additional 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 total of ethanol, propanol, and butanol.

[0042] In one or more embodiments, the dehydration reaction may utilize one or more acid catalysts. In such embodiments, the particulate solid may include one or more acid catalysts. In some embodiments, the one or more acid catalysts utilized in the dehydration reaction may include a zeolite (such as ZSM-5 zeolite), alumina, an amorphous aluminosilicate, an acid clay, or a combination thereof. For example, commercially available alumina catalysts that may be suitable, according to one or more embodiments, include SynDol (available from Scientific Design Company), V200 (available from UOP), or P200 (available from Sasol). Commercially available zeolite catalysts that may be suitable include CBV 8014, CBV 28014 (each available from Zeolyst). Commercially available amorphous aluminosilicate catalysts that may be suitable include silica-alumina catalyst support, grade 135 (available from Sigma-Aldrich). However, it should be understood that other suitable catalysts may be utilized to carry out the dehydration reaction.

[0043] According to one or more embodiments, the reaction can be a methanol to olefins reaction. According to such embodiments, the hydrocarbon feed stream can include methanol. According to one or more embodiments, the hydrocarbon feed stream can include 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.

[0044] In one or more embodiments, the methanol-to-olefins reaction may utilize one or more zeolites as a catalyst. In such embodiments, the particulate solid may comprise one or more zeolites. In some embodiments, the one or more zeolites utilized in the methanol-to-olefins reaction may comprise one or more of ZSM-5 zeolite or SAPO-34 zeolite. However, it should be understood that other suitable catalysts may be utilized to carry out the methanol-to-olefins reaction.

[0045] In one or more embodiments, the particulate solid may be capable of fluidization. In some embodiments, the particulate solid may exhibit what is known in the industry as "Geldart A" or "Geldart B" properties. Particles may be classified as "Group A" or "Group B" according to D. Geldart, Gas Fluidization Technology, John Wiley & Sons (New York, 1986), 34-37, and D. Geldart, "Types of Gas Fluidization," Powder Technol. 7 (1973) 285-292, which are incorporated herein by reference in their entireties.

[0046] Group A is understood by those skilled in the art to represent aerable powders having the following: bubble-free range of fluidization; high bed expansion; slow, linear degassing rate; bubble characteristics where splitting / re-coalescing bubbles may predominate, with maximum bubble size and large wake; high levels of solids mixing and gas backmixing, assuming equal U-Umf (where U is the carrier gas velocity and Umf is the minimum fluidization velocity, typically but not necessarily measured in meters per second (m / s), i.e., excess gas velocity exists); axisymmetric slug characteristics; and no eruptions except in very shallow beds. Assuming equal cfp, the listed properties tend to improve as the average particle size decreases, or as the percentage above 45 micrometers (μm) increases, or as the gas pressure, temperature, viscosity, and density increase. Generally, particles with small average particle size and / or low particle density (1.4 grams per cubic centimeter (g / cm) 3 ) or less), and easily fluidizes with smooth fluidization at low gas velocities and may exhibit controlled small bubble bubbling even at higher gas velocities.

[0047] Group B is understood by those skilled in the art to represent a "sand-like" powder having the following: starting to foam at Umf; showing moderate bed expansion; rapid degassing; no limitation on bubble size; assuming U-Umf is equal, the levels of solid mixing and gas backmixing are moderate; both axisymmetric and asymmetric slags; and jetting only in a shallow bed. These characteristics tend to improve as the average particle size decreases, but the particle size distribution and, with some uncertainty, the gas pressure, temperature, viscosity, or density do not seem to contribute much to the improvement of the above characteristics. Generally, when the density (pp) is 1.4 < pp < 4 g / cm 3 , 40 μm < cfp < 500 μm, preferably when the density (pp) is 4 g / cm 3 , 60 μm < cfp < 500 μm, and when the density (pp) is 1 g / cm 3 , most of the particles have a particle size (cfp) of 250 μm < cfp < 100 μm.

[0048] In one or more embodiments, olefinic compounds may be present in a "product stream," sometimes referred to as an "olefin-containing effluent." Such a stream may exit the reactor system of FIG. 1 and be subsequently processed. In one or more embodiments, the olefinic compounds may include one or more of ethylene, propylene, butylene, or styrene. The term butylene includes any isomer of butylene, such as α-butylene, cis-β-butylene, trans-β-butylene, and isobutylene. In some embodiments, the olefin-containing effluent 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% ethylene. In additional embodiments, the olefin-containing effluent 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% propylene. In additional embodiments, the olefin-containing effluent 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% butylene. In additional embodiments, the olefin-containing effluent 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% styrene. In additional embodiments, the olefin-containing effluent 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 total of one or more of ethylene, propylene, butylene, and styrene. The olefin-containing effluent may further comprise unreacted components of the feed stream as well as other reaction products not considered light olefins. The olefin compounds can be separated from the unreacted components in a subsequent separation step.

[0049] Several embodiments are currently disclosed herein. A first embodiment 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 the one or more hydrocarbons react to form one or more olefin compounds and coke is formed on the particulate solid; passing the particulate solid from the reactor to a strip zone, wherein the particulate solid is contacted with a strip gas and oxygen in the strip zone, the strip gas comprising nitrogen, steam, or a combination thereof, wherein a majority of the coke reacts with the oxygen to form carbon dioxide in the strip zone, and a majority of the carbon dioxide produced in the strip zone is discharged from the strip zone and combined with the one or more olefin compounds; passing the particulate solid from the strip zone to a regeneration unit, wherein the particulate solid is heated by combustion of a fuel in the regeneration unit; and passing at least a portion of the particulate solid from the regeneration unit to the reactor.

[0050] Another embodiment includes any of the preceding embodiments or combinations of embodiments, wherein at least 80 wt. % of the total coke reacted in the strip zone and regeneration unit is reacted in the strip zone.

[0051] Another embodiment includes any preceding embodiment or combination of embodiments, wherein the particulate solids contain less than 1.0 wt. % coke when sent to the regeneration unit.

[0052] Another embodiment includes any of the foregoing embodiments or combinations of embodiments in which the particulate solids move in a generally downward direction through the strip zone and the gas moves in a generally upward direction through the strip zone, such that the particulate solids and gas move in a countercurrent pattern through the strip zone.

[0053] Other embodiments include any of the foregoing embodiments or combinations of embodiments in which oxygen is passed through the strip zone in an oxygen-containing gas, and in which the oxygen-containing gas and the strip gas enter the strip zone through separate gas inlets.

[0054] Another aspect includes any preceding aspect or combination of aspects, wherein the strip zone comprises a first gas inlet, a second gas inlet, and a third gas inlet, wherein the oxygen-containing gas enters the strip zone through the first gas inlet, the strip gas enters the strip zone through the second gas inlet, and the fuel enters the strip zone through the third gas inlet, wherein the first gas inlet is above the second gas inlet and the third gas inlet is above the first gas inlet.

[0055] Another embodiment includes any of the foregoing embodiments or combinations of embodiments, wherein the strip gas comprises nitrogen, and oxygen and nitrogen are passed as an air stream through a single gas inlet into the strip zone.

[0056] Another embodiment includes any of the preceding embodiments or combinations of embodiments, wherein the fuel comprises hydrogen.

[0057] Another embodiment includes any preceding embodiment or combination of embodiments, wherein the amount of carbon dioxide in the flue gas from the regeneration unit is 0.5 mole percent or less of the flue gas.

[0058] Another embodiment includes any of the foregoing embodiments or combinations of embodiments, wherein a portion of the particulate solids is removed from the strip zone and passed to the reactor without first passing through a regeneration unit.

[0059] Another embodiment includes any preceding embodiment or combination of embodiments, wherein the reaction in the reactor is a dehydrogenation reaction, the one or more hydrocarbons include ethylbenzene, ethane, propane, n-butane, i-butane, or a combination thereof, and the particulate solid includes a dehydrogenation catalyst, an oxygen carrier material, or both.

[0060] Another embodiment includes any preceding embodiment or combination of embodiments, wherein the reaction in the reactor is a non-catalytic thermal dehydrogenation reaction, the one or more hydrocarbons include ethylbenzene, ethane, propane, n-butane, i-butane, or a combination thereof, and the particulate solid consists essentially of an oxygen carrier material.

[0061] Another embodiment includes any preceding embodiment or combination of embodiments, wherein the reaction in the reactor is a cracking reaction, the one or more hydrocarbons include naphtha, n-butane, i-butane, or a combination thereof, and the particulate solids include one or more zeolites.

[0062] Another embodiment includes any preceding embodiment or combination of embodiments, wherein the reaction in the reactor is a dehydration reaction, the one or more hydrocarbons comprise ethanol, propanol, butanol, or a combination thereof, and the particulate solid comprises one or more acid catalysts.

[0063] Another embodiment includes any preceding embodiment or combination of embodiments, wherein the reaction in the reactor is a methanol-to-olefins reaction, the one or more hydrocarbons may include methanol, and the particulate solid includes one or more zeolites.

[0064] It will be apparent to those skilled in the art that various modifications and variations can be made to the technology of the present disclosure without departing from the spirit and scope of the technology. Since combinations, subcombinations, and variations of the disclosed embodiments incorporating the spirit and substance of the technology of the present disclosure may occur to those skilled in the art, the technology should be construed as including all within the scope of the appended claims and their equivalents. Furthermore, although some aspects of the present disclosure may be identified herein as preferred or particularly advantageous, it is intended that the present disclosure is not limited to these aspects.

[0065] It should be noted that the various details described in this disclosure should not be construed as implying that these details relate to elements that are essential components of the various embodiments described in this disclosure, even if a particular element is illustrated in each of the drawings accompanying this specification. Unless specifically identified as such, features disclosed and described herein should not be construed as "essential." Contemplated embodiments of the present technology include those that include some or all of the features of the appended claims.

[0066] It should be noted that for purposes of describing and defining this disclosure, the term "about" is utilized in this disclosure to express the inherent degree of uncertainty that may result from any quantitative comparison, value, measurement, or other representation. The term "about" is also utilized in this disclosure to express the degree to which a quantitative representation may vary from the basis of description without resulting in a change in the basic functionality of the subject matter at issue.

[0067] Where relevant, when a composition is described as "comprising" one or more elements, embodiments of the composition that "consist" or "consist essentially of" those one or more elements are contemplated herein.

[0068] In some embodiments, a chemical or chemical stream is described as "passing" from one system unit or portion of a system unit to another system unit or portion of a system unit. As described herein, such passing may include direct or indirect passing. For example, when passing from "unit A" to "unit B," direct passing has no intermediate destination between unit A and unit B (i.e., directly through a pipe or other transfer passageway), while indirect passing may include one or more intermediate destinations between unit A and unit B. For example, a stream passing from unit A to unit B may pass through, but is not limited to, a heat exchanger, a processing device, etc.

[0069] It is understood that the compositional ranges of chemical components in a stream or reactor should, in some embodiments, be understood to contain a mixture of isomers of that component. For example, a compositional range specifying butene may include a mixture of various isomers of butene. It is understood that the examples provide compositional ranges for various streams, and that the total amount of isomers of a particular chemical composition may constitute a range.

[0070] It should be noted that one or more of the following claims utilize the term "where" or "wherein" as a transitional phrase. It should be noted that for purposes of defining the present technology, this term is introduced in the claims as an open-ended transitional phrase used to introduce the recitation of a series of features of a structure, and should be interpreted in a similar manner to the more commonly used open-ended preamble term "comprising."

[0071] It should be understood that any two quantitative values ​​assigned to a property may constitute a range for that property, and all combinations of ranges formed from all stated quantitative values ​​for a given property are contemplated in this application. When multiple ranges are given for quantitative values, these ranges may be combined to form larger ranges, which are contemplated in the embodiments described herein.

Claims

1. 1. A method for forming an olefinic compound, the method comprising: contacting a feed stream comprising one or more hydrocarbons with a particulate solid in a reactor, the process comprising: the one or more hydrocarbons react to form one or more olefinic compounds; contacting, wherein coke is formed on said particulate solids; passing the particulate solids from the reactor to a strip zone; the particulate solids are contacted with strip gas and oxygen in the strip zone; the strip gas comprises nitrogen, steam, or a combination thereof; In the strip zone, a majority of the coke reacts with oxygen to form carbon dioxide; passing a majority of the carbon dioxide produced in the stripping zone out of the stripping zone and combined with the one or more olefinic compounds; passing the particulate solids from the strip zone to a regeneration unit, wherein the particulate solids are heated by combustion of fuel within the regeneration unit; and passing at least a portion of said particulate solids from said regeneration unit to said reactor.

2. 10. The method of claim 1, wherein at least 80 wt. % of the total coke reacted in the strip zone and the regeneration unit is reacted in the strip zone.

3. 10. The method of claim 1, wherein said particulate solids contain less than 1.0 wt. % coke when sent to said regeneration unit.

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

5. 5. The method of claim 1, wherein the oxygen is passed through the strip zone in an oxygen-containing gas, the oxygen-containing gas and the strip gas entering the strip zone through separate gas inlets.

6. the strip zone comprises a first gas inlet, a second gas inlet, and a third gas inlet; the oxygen-containing gas enters the strip zone through the first gas inlet; the strip gas enters the strip zone through the second gas inlet; fuel enters the strip zone through the third gas inlet; the first gas inlet is above the second gas inlet; The method of claim 5 , wherein the third gas inlet is above the first gas inlet.

7. A method according to any one of claims 1 to 4, wherein the strip gas comprises nitrogen, and the oxygen and nitrogen are passed as an air stream through a single gas inlet into the strip zone.

8. The method of any one of claims 1 to 7, wherein the fuel comprises hydrogen.

9. A method according to any one of claims 1 to 8, wherein the amount of carbon dioxide in the flue gas from the regeneration unit is not more than 0.5 mol % of the flue gas.

10. A process according to any one of claims 1 to 9, wherein a portion of the particulate solids is removed from the strip zone and passed to the reactor without first passing through the regeneration unit.

11. the reaction in the reactor is a dehydrogenation reaction, the one or more hydrocarbons comprise ethylbenzene, ethane, propane, n-butane, i-butane, or a combination thereof; The method of claim 1 , wherein the particulate solid comprises a dehydrogenation catalyst, an oxygen carrier material, or both.

12. the reaction in the reactor is a non-catalytic thermal dehydrogenation reaction, the one or more hydrocarbons comprise ethylbenzene, ethane, propane, n-butane, i-butane, or a combination thereof; 10. The method of claim 1, wherein the particulate solid consists essentially of an oxygen carrier material.

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

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

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

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