• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    fluid catalytic cracking process and device for maximizing light olefins or middle distillates and light olefins. The present invention describes a device and process for fluid catalytic cracking, providing efficient conversion of heavy hydrocarbon feedstocks into light olefins, aromatics and gasoline. a countercurrent flow reactor operating in turbulent or bubbling fluidization regime is integrated with a riser reactor for fluid catalytic cracking. a load of heavy hydrocarbon is catalytically broken down into naphtha and light olefins in the riser reactor, a cocurrent flow reactor. To improve the yield and selectivity of light olefins, cracked hydrocarbon products from the riser reactor, such as C4 and naphtha-banded hydrocarbons can be recycled and processed in the counterflow reactor. Countercurrent flow reactor integration with a conventional fcc riser reactor and with the catalyst regeneration system can overcome the thermal equilibrium aspects commonly associated with two-stage cracking processes, can substantially increase the total conversion and olefin yield light, and/or can increase the processing capacity of heavier raw materials.
    公开号:BR112015000528B1
    申请号:R112015000528-4
    申请日:2013-07-10
    公开日:2022-01-18
    发明作者:Rama Rao Marri；Dalip Singh Soni；Pramod Kumar
    申请人:Lummus Technology Inc；
    IPC主号:
    专利说明:

    field of invention
    [001] Embodiments described in the present invention are generally related to a fluid catalytic cracking device and a process for maximizing the conversion of a heavy hydrocarbon feedstock, such as vacuum diesel and/or heavy oil residues, into light olefins of high yields such as propylene and ethylene, aromatics and high octane gasoline. background
    [002] Currently, the production of light olefins through fluid catalytic cracking (FCC) processes has been considered one of the most attractive proposals. Fuel specifications are becoming highly restricted due to stringent environmental regulations. In addition, there is a growing demand for petrochemical building blocks such as propylene, ethylene and aromatics (benzene, toluene, xylenes, etc). Furthermore, the integration of oil refineries with a petrochemical complex has become a preferred option for economic and environmental requirements. Global trends also demonstrate that there is an increased need for middle distillates (diesel) compared to gasoline. Maximizing middle distillates from a typical FCC process requires operating the reactor at lower temperatures; this also requires the use of different catalyst formulations. Operating at lower temperatures decreases the yield of light olefins and feedstock for alkylation units.
    [003] Many fluidized bed catalytic processes have been developed during the last two decades, adapting to changing market requirements. For example, US 7479218 describes a fluidized catalytic reactor system where a riser reactor is divided into two parts with different radii to improve the selectivity of light olefin production. The first part of the riser reactor with a smaller radius is used for the cracking of larger load molecules for the naphtha strip. The larger radius portion, the second part of the riser reactor, is used for re-cracking naphtha strip products into light olefins, such as propylene, ethylene, etc. Because the reactor system concept is very simple, the level of selectivity for light olefins is limited for the following reasons: (1) the naphtha range charge streams come into contact with the deactivated or partially deactivated catalyst by coke; (2) the temperature in the second part of the reaction section is much lower than the first zone due to the endothermic nature of the reaction in both zones; and (3) lack of the high activation energy required for light load cracking compared to heavy hydrocarbons.
    [004] US6106697, US7128827 and US7323099 employ two-stage fluid catalytic cracking (FCC) units to allow a high level of selective cracking control of heavy hydrocarbons and load naphtha range streams. In the first stage of the FCC unit, which consists of a riser, stripper and regenerator reactor for converting the diesel/heavy hydrocarbon charge into naphtha boiling range products, in the presence of a Y-type wide-pore zeolite-based catalyst. A second stage FCC unit with a similar group of containers/configuration is used for catalytic cracking of recycled naphtha streams from the first stage. Obviously, the second stage of the FCC unit employs a catalyst of the ZSM-5 type (the small pore zeolite base) to improve the selectivity for light olefins. Although this scheme provides a high level of control over the charge, catalyst, operating window selection and optimization in a broad sense, processing the second stage of the naphtha charge produces very little coke, which is insufficient to maintain the thermal balance. This requires heat from external sources to present adequate temperature in the regenerator to obtain good combustion and to provide heat for vaporization of the load and endothermic reaction. Generally, the torch-oil is burned in the second stage of the FCC regenerator, causing excessive catalyst deactivation caused by very high temperatures of the catalyst particles and hot spots.
    [005] US7658837 describes a process and device for optimizing the yields of FCC products using a portion of the conventional stripper bed as a reactive stripper. Such a concept of restoration of the second reactor compromises its effectiveness to a certain extent, and therefore, can lead to an increased coke load for the regenerator. Product yield and selectivity are also likely to be affected by the contact of the filler with the coked or deactivated catalyst. Therefore, reaction stripper temperatures cannot be changed independently because the temperature at the top of the riser is directly controlled to maintain a desired set of conditions.
    [006] US2007/0205139 describes a process for injecting hydrocarbon cargo through a first distributor located at the bottom of the riser, to maximize gasoline yield. When the objective is to maximize light olefins, the load is injected into the upper section of the riser through a similar load distribution system to reduce the residence time of hydrocarbon vapors.
    [007] WO2010/067379 proposes to increase propylene and ethylene yields through the injection of C4 and olefinic naphtha streams in the riser ascending zone below the heavy hydrocarbon load injection zone. These streams not only improve the yield of light olefins, but also act as a catalyst transport medium in place of the stream. This concept helps in reducing the level of thermal deactivation of the catalyst. However, this can impair the flexibility of operating conditions, such as temperature and weight hourly space velocity (WHSV) in the ascending zone, which are critical in breaking such light load currents. This likely results in lower selectivity for the desired light olefins.
    [008] US6869521 describes that contacting a feedstock derived from an FCC product (particularly naphtha) with a catalyst in a second reactor operating in the fast fluidization regime is useful in promoting hydrogen transfer reactions, and also for controlling reactions. of catalytic cracking.
    [009] US7611622 describes an FCC process that employs two risers for converting raw materials containing C3/C4 into aromatics. The first and second hydrocarbon feeds are supplied to the first and second risers, respectively, in the presence of a gallium-enriched catalyst, and with the second riser operating at a higher reaction temperature than the first.
    [010] US5944982 describes a catalytic process with two risers to produce less sulfur and high octane gasoline. The second riser is used in the recycling process of heavy naphtha and light cycle oils after hydrotreating to maximize gasoline yield and octane rating.
    [011] US20060231461 describes a process that maximizes the production of light cycle oil (LCO) or middle distillate product and light olefins. This process employs a two-reactor system where the first reactor (riser) is used to load cracked gas oil in LCO predominantly, and a second dense bed reactor is used to crack the recycled naphtha from the first reactor. This process is limited by the selectivity of the catalyst and the lack of the desired level of olefins in the naphtha, caused by operating with substantially lower reaction temperatures in the first reactor.Summary of the described modalities
    [012] It was discovered that it is possible to use a scheme with two reactors for the cracking of hydrocarbons, including C4, a lighter C5 fraction, a naphtha fraction, methanol, etc., for the production of light olefins, where the two reactors has no limitations on selectivity and operability, meets the requirements of thermal balance and also maintains a reduced number of units. Embodiments of the present invention utilize a conventional riser reactor combined with a fluidized bed/turbulent/countercurrent bubbling reactor designed to maximize light olefin production. Effluents from the riser reactor and counterflow reactor are processed in a common catalyst separation vessel, and the catalysts used in the riser reactor and counterflow reactor are recovered in a common catalyst regeneration vessel. This flow scheme is effective in maintaining high cracking activity, overcoming thermal equilibrium problems, as well as improving the yield and selectivity of light olefins from various hydrocarbon streams, and further simplifying rapid product cooling and utilizing a single hardware, as described in more detail below.
    [013] In one aspect, the embodiments described in the present invention relate to a process for catalytic cracking of hydrocarbons, including: regeneration of a spent catalyst having a first cracking catalyst with a first average particle size and density, and a second cracking catalyst with a second average particle size and density in a catalyst regeneration vessel to form a regenerated catalyst. The average particle size of the first cracking catalyst is smaller than the average particle size of the second. A first hydrocarbon feed contacts a cocurrent stream in the first portion of the regenerated catalyst in a riser reactor to produce a first effluent, including a first cracked hydrocarbon product, and a fraction of a spent catalyst mixture. A second portion of the regenerated catalyst is fed to a countercurrent flow reactor, where concomitantly: (i) the first cracking catalyst is separated from the second based on minimum density and particle size; (ii) a second hydrocarbon charge is contacted in the countercurrent stream with the second cracking catalyst to produce a second cracked hydrocarbon product; (iii) a second effluent is recovered from the countercurrent flow reactor including the second cracked hydrocarbon product, and the first cracking catalyst; and (iv) a third effluent is recovered including the second spent catalyst. The first and second effluent are fed to a separation vessel to remove the spent catalyst fraction and the first cracking catalyst separated from the first and second cracked hydrocarbon product. The separated catalysts are fed from the separation vessel to the catalyst regeneration vessel as the spent catalyst.
    [014] In another aspect, the modalities described in the present invention are related to a device for the catalytic cracking of hydrocarbons. The system may include a spent catalyst regeneration vessel including a first cracking catalyst having a first average particle size and density, and a second cracking catalyst having a second average particle size and density to form a regenerated catalyst comprising the first and the second cracking catalyst. The average particle size of the first cracking catalyst is smaller than the average particle size of the second. The system also includes a riser reactor for co-currently contacting an initial charge of hydrocarbon with a first portion of the regenerated catalyst to produce a first effluent including a first cracked hydrocarbon product, and a fraction of the spent catalyst. A flow conduit is provided for feeding the second portion of the regenerated catalyst to a countercurrent flow reactor. The countercurrent flow reactor is configured to concurrently: (i) separate the first cracking catalyst from the second based on a minimum of particle density and size; (ii) contacting in the countercurrent flow a second hydrocarbon charge with predominantly the second cracking catalyst to produce a second cracked hydrocarbon product; (iii) recovering a second effluent from the countercurrent flow reactor comprising the second cracked hydrocarbon product, and the first cracking catalyst; and (iv) recovering a third effluent comprising the second spent catalyst. A separation vessel is then used to separate the first effluent from the second, and to recover (a) a fraction of spent catalyst including the first separated cracking catalyst and (b) an effluent including the first and second cracked hydrocarbon products. A flow conduit is also provided to feed the spent catalyst fraction from the separation vessel to the catalyst regeneration vessel.
    [015] Other aspects and advantages will become clear from the description below and the attached claims. Brief description of figures
    [016] Figure 1 is a flow diagram of the simplified hydrocarbon cracking and light olefin production process according to one or more embodiments of the present invention. Detailed Description
    [017] In one aspect, the embodiments of the present invention relate to a fluid catalytic cracking device and a process for maximizing the conversion of a light hydrocarbon feedstock such as vacuum gas oil and/or heavy oil residues into olefins. high yield lighters such as propylene and ethylene, aromatics and high octane gasoline or middle distillates, while minimizing the yield of heavy products at the bottom. To achieve this objective, a countercurrent flow reactor, operating in a bubbling or turbulent fluidization regime, is integrated with a conventional fluid catalytic cracking reactor, such as a riser reactor. The heavy hydrocarbon feedstock is catalytically cracked into naphtha, middle distillates and light olefins in the riser reactor, which is a pneumatic reactor with co-current flow. To improve the yields and selectivity of light olefins (ethylene and propylene), cracked hydrocarbon products from the riser reactor, such as C4 and naphtha range hydrocarbons (olefins and paraffins) can be recycled and processed in the countercurrent flow reactor. . Alternately or additionally, external load streams such as C4 fractions from other processes such as steam cracking, metathesis reactor or delayed coking unit, and currents in the naphtha range from delayed coking, visbreaking or natural gas condensates can be processed in the countercurrent flow reactor to produce light olefins such as ethylene and propylene. The integration of the countercurrent flow reactor with a conventional FCC riser reactor, in accordance with the embodiments of the present invention, can overcome the obstacles of the above processes, can increase the total conversion and yield of light olefins, and/or can increase the ability to process heavier raw materials.
    [018] The integration of the countercurrent reactor with a conventional FCC riser reactor, according to the modalities described in the present invention, can be facilitated by (a) the use of a common catalyst regeneration vessel, (b) the use of two types catalyst, one being selective for cracking heavier hydrocarbons such as vacuum gas oil, heavy vacuum gas oil, heavy residue from the bottom of the atmospheric tower, and the other being selective for cracking C4 and hydrocarbons in the naphtha range for the production of light olefins, and (c) use of a countercurrent flow reactor that will separate the two types of catalyst, favoring the contact of the C4s or the naphtha load with the selective catalyst for cracking and production of light olefins.
    [019] The first cracking catalyst may be a Y-type zeolite, an FCC catalyst, or other similar catalysts useful for cracking heavier hydrocarbon feedstocks. The second cracking catalyst may be a ZSM-5 or ZSM-11 type, or a similar catalyst useful for cracking C4s or naphtha-banded hydrocarbons, and selective for producing light olefins. To facilitate the two-reactor schemes described in the present invention, the first cracking catalyst may have a first average particle size and a lower, lighter density than the second catalyst so that the catalysts can be separated based on density and size (e.g. based on terminal velocity or other characteristics of catalyst particles).
    [020] In the catalyst regeneration vessel, the spent catalyst, recovered from both the riser reactor and the countercurrent flow reactor, is regenerated. After regeneration, a first portion of the catalyst mixture can be supplied from the regeneration vessel to a riser reactor (stream flow reactor). A second portion of the catalyst mixture may be fed from the regeneration vessel to the countercurrent flow reactor.
    [021] In the cocurrent flow reactor, a first hydrocarbon charge is brought into contact with a first portion of the regenerated catalyst to break down at least a portion of the hydrocarbons to form lighter hydrocarbons. An effluent can then be recovered from the riser reactor, comprising a first cracked hydrocarbon product and a used fraction of the catalyst mixture.
    [022] In the countercurrent flow reactor, the second portion of the regenerated catalyst flows into an upper portion of the reaction vessel, the catalyst separation zone, coming into contact with upstream flowing hydrocarbons and steam or other separation medium. The upstream flow of the fluid components is maintained at a rate sufficient to separate the first cracking catalyst from the second based at least on differences in density and particle size of the two catalysts. The larger, denser, selective catalyst for cracking the light hydrocarbon feedstocks flows downstream and forms a dense bed of catalyst particles. The second downstream cracking catalyst is contacted in the countercurrent flow with a second upstream hydrocarbon charge, C4 or naphtha fraction, breaking down the hydrocarbons and forming light olefins such as ethylene and propylene. The catalyst continues to flow downstream through the reaction zone to a lower separation zone, where the catalyst is contacted with steam or other stripping medium to separate the cracked hydrocarbons and unreacted feedstock components from the second cracking catalyst. The second used cracking catalyst is recovered from the bottom of the countercurrent flow reactor and returned to the catalyst regeneration vessel. The withdrawal medium, the cracked hydrocarbon product, and the first separate cracking catalyst are recovered as an effluent from the top of the reactor.
    [023] The second effluent (cracked hydrocarbon products and the first separated cracking catalyst) from the countercurrent flow reactor outlet is transported to a separation vessel via the riser reactor pipeline in a pneumatic fluidization regime. This piping can also be used to introduce an additional amount of heavy load or redirect part of the load from the first stage reactor (riser reactor). This satisfies two goals. First, the catalyst in the steam outlet line of the countercurrent flow reactor is predominantly Y-type zeolite/conventional FCC catalyst which are preferred for breaking down heavy charge molecules in middle distillates (diesel) at a relatively low reaction temperature. . A lower reaction temperature (475-520°C) is preferred to maximize middle distillates. Second, it aids in the simultaneous (rapid) cooling of lighter hydrocarbon streams from the countercurrent flow reactor. The cracking reaction is endothermic, facilitating the reduction of the temperature of the vapors leaving the product and also the residence time.
    [024] The first effluent (cracked hydrocarbons and spent catalyst from the riser reactor) and the second effluent (cracked hydrocarbons and the first cracking catalyst separated from the countercurrent flow reactor) are fed to a separation vessel to remove the fraction of spent catalyst and the first cracking catalyst separated from the first and second hydrocarbon products. Cracked hydrocarbon products, including light olefins, C4 hydrocarbons, hydrocarbons in the naphtha range, and heavier hydrocarbons can then be separated to recover the desired products or fractions thereof.
    [025] Therefore, the processes described in the present invention integrate a countercurrent flow reactor and a riser reactor, with common product separations and catalyst regeneration, where the catalysts used in the countercurrent flow reactor are highly selective for hydrocarbon cracking C4, and in the naphtha range to produce light olefins. Common catalyst regeneration provides thermal balance, and common product separation (separation vessel, etc.) offers simplicity of operations and reduced number of units, among other advantages.
    [026] Referring to Figure 1, a flow diagram of the simplified process for cracking hydrocarbons and producing light olefins, according to the modalities described in the present invention, is illustrated. The process includes a two-reactor setup to maximize the yield of propylene and ethylene from petroleum waste feedstocks. The second reactor is composed of a dense fluidized bed equipped with baffles or internal systems. C4 olefins and/or light naphtha from products from the first reactor or similar load streams from external sources are processed in the second reactor to increase the yield of light olefins, including propylene and ethylene, and high-octane aromatics/gasoline.
    [027] A charge of waste oil is injected through one or more charge injectors 2 located near the bottom of the first riser reactor 3. The heavy oil charge comes into contact with the hot regenerated catalyst introduced through a J-tube -bend 1. The catalyst, for example, can be one based on Y-type zeolite, which can be used alone or in combination with other catalysts, such as ZSM-5 or ZSM-11.
    [028] The heat required for the vaporization of the load and/or increasing its temperature to the desired one in the reactor, such as in the range of 500°C to about 700°C, and for the endothermic heat (heat of reaction) can be supplied by the hot regenerated catalyst from the regenerator 17. The pressure in the first riser reactor 3 is generally in the range of about 1 barg to about 5 barg.
    [029] Upon completion of most of the cracking reaction, the product mixture, unconverted charge vapors, and catalyst flow flow into a two-stage cyclone system located in the containment vessel of Cyclone 8. two-stage cyclone includes a primary cyclone 4 for separating catalyst from vapors. Spent catalyst is discharged into stripper 9 through dip leg 5 of the primary cyclone. The fine catalyst particles entrained with the separated vapors from primary cyclone 4 and the product vapors from the second reactor 32, introduced via flow line 36a and by a single stage cyclone 36c, are separated in a second stage cyclone 6. The collected catalyst is discharged into stripper 9 through dip leg 7. Vapors from second stage cyclone 6 are vented through a secondary cyclone outlet, connected to plenum chamber 11, and are then routed to a main/ gas turbine through the steam line of reactor 12b to recover the products, including the desired olefins. If necessary, product vapors are also cooled by introducing light cycle oil (LCO) or steam via distribution line 12a as a cooling medium.
    [030] The spent catalyst recovered through the legs 5,7 is subjected to separation in the stripper bed 9 to remove interstitial vapors (hydrocarbon vapors contained between the catalyst particles) through the countercurrent contact of the steam, introduced at the bottom of the stripper 9 through a gas distributor 10. The spent catalyst is then transferred to the regenerator 17 through the spent catalyst tube 13a and the riser 15. The spent catalyst slide valve 13b located in the catalyst tube 13a is used to control the flow from stripper 9 to regenerator 17. A small portion of combustion air is introduced through distributor 14 to aid in the transfer of spent catalyst.
    [031] The spent or coked catalyst is discarded through the spent catalyst distributor 16 in the center of the fluidized bed regenerator, in the dense region 24. The combustion air is introduced by the air distributor 18, located at the bottom of the bed regenerator fluidized 24. The coke deposited on the catalyst is then combusted in the regenerator 17 through reaction with combustion air. The regenerator 17, for example, can operate at a temperature in the range of about 640°C to about 750°C and with a pressure in the range of about 1 barg to 5 barg (100 kPag to 500 kPag). The fine catalyst particles entrained along with the flue gas are collected in the first stage cyclone 19 and in the second stage cyclone 21, and are discarded in the fluidized bed regenerator through their respective legs 20, 22. The flue gas recovered in the second stage cyclone 21 output is directed to the flue gas line 24, through the plenum chamber of the regenerator 23 for recovery of heat released downstream and/or recovery of energy.
    [032] A first part of the regenerated catalyst is withdrawn into a regenerated catalyst feed tank (RCSP) 26 through the withdrawal line 25, which is in fluid communication with the regenerator 17 and the regenerated catalyst tube 27. The catalyst bed in the RCSP tank 26 it fluctuates according to the level of the fluidized bed regenerator 17. The regenerated catalyst is then transferred from the RCSP tank 26 to the riser reactor 3 through the catalyst tube 27, which are in communication with the J-bend tube 1 The flow of catalyst from the regenerator 17 to the riser reactor 3 may be regulated by a slide valve 28 located in the regenerated catalyst tube 27. The opening of the slide valve 28 is adjusted to control the flow of catalyst to maintain a temperature desired at the top of the riser reactor 3.
    [033] In addition to ascending steam, a supply is also made to inject charge vapors such as C4 olefins and naphtha or similar external vapors as an ascending medium for the J-bend tube 1, through a gas distributor 1a located in the section Y, to allow a transfer of the regenerated catalyst from the J-bend tube to the riser reactor 3. The J-bend tube can also act as a dense bed reactor for cracking the C4 olefin and naphtha streams into light olefins, under favorable for such reactions, such as a weight hourly space velocity (WHSV) of 0.5 to 50 h-1, a temperature of 640°C to 750°C, and residence times of 3 to 10 seconds. The diameter or size of the J-bend tube (D3) can be varied to obtain these conditions. For example, the diameter of the J-bend tube can vary from 1 to 3 times the diameter of the regenerated catalyst tube.
    [034] A second part of the regenerated catalyst is withdrawn in a second reactor 32 through a tube 30. A slide valve 31 can be used to control the flow of catalyst from the regenerator 17 to a second reactor 32, based on the temperature point. of the steam outlet. Streams of C4 olefins and naphtha are injected into the lower portion of the catalyst bed through one or more charge distributors 34 (34a, 34b) in both the liquid and gas phases. The second reactor 32 operates in a countercurrent fashion, where the regenerated catalyst flows downstream (from the top to the bottom of the reactor bed), and the hydrocarbon stream flows upstream (from the bottom to the top of the reactor bed). . This is an important aspect that helps to maintain an optimal temperature profile along the length/height of the second reactor 32.
    [035] The second reactor 32 can be equipped with a baffle or internal structures that facilitate the contact and mixing of the catalyst and charge molecules. These structures can also help to minimize channeling, blistering and/or coalescence. The second reactor 32 can also be enlarged in different sections along the length to keep the surface velocity of the gas constant.
    [036] After the end of the reaction, the catalyst is withdrawn in the lowermost portion of the second reactor 32 to separate the hydrocarbon/products charge, using the steam introduced through the distributor 35. The spent catalyst is then transferred to the regenerator 17 through pipe 37 and ascending line 40, through a distributor 41. Combustion air may be introduced through distributor 39 to allow smooth transfer of catalyst to regenerator 17. Slide valve 38 may be used to control the flow of fuel. catalyst from the second reactor 32 to the regenerator 17. Spent catalyst from both reactors 3, 32 is then regenerated in the common regenerator 17, operating in a total combustion mode.
    [037] The second reactor 32 utilizes two different catalyst particles, including a smaller, lighter Y-type zeolite or an FCC catalyst, and a small-pore zeolite of selected form ZSM-5/ZSM-11. For example, Y-type zeolite or FCC catalyst may have a particle size in the range of about 20120 microns, while the ZSM-5/ZSM11 catalyst may have a particle size in the range of about 80 to about 200 microns. microns. The surface gas velocity in the second reactor 32 is such that the FCC/Y-type zeolite catalyst is ejected from the reactor so that the second reactor 21 preferentially retains the ZSM-5-type catalyst within the bed, due to differences in terminal velocity. particle size or differences between minimum bubbling/minimum fluidization rates. The smaller, lighter Y-type FCC/zeolite catalyst is then transported from the second reactor 32 to the common separator or containment vessel 8, which contains the cyclones of the riser reactor and/or reaction termination system, through the outlet line 36a .
    [038] A hydrocarbon charge, such as heavy vacuum gas oil, atmospheric tower residue, heavy hydrocarbon residue charge, light cycle oil (LCO), and/or steam may be injected as a cooling medium in the outlet 36a through a distributor 36b. The flow rate of such a cooling medium can be controlled by adjusting the temperature of the vapor entering the containment vessel 8. All vapors from the second reactor 32, including those fed through the distributor 36b, are discharged into the dilute phase of the containment vessel 32. containment 8 via a single stage cyclone 36c. The employment of hydrocarbon feedstock as a cooling medium is preferably as it serves the dual purpose of cooling the products of the second reactor 32 and also improving the production of middle distillates, such as breaking down the heavy hydrocarbon cooling medium in the transport to distributor 36b. In some embodiments, the cooling medium may be introduced near the outlet of the countercurrent flow reactor. The temperature within the transport line 36a can be controlled by varying the amount of hydrocarbon charge through the flow line 36b.
    [039] The first stage reactor, riser 3, operates in the fast fluidization regime (for example, with a surface gas velocity in the range of about 3 to about 10 m/s at the bottom), and pneumatic conveying (e.g. at a surface gas velocity in the range of about 10 to about 25 m/s) at the top.
    [040] The second reactor 32 operates in a turbulence/bubbling regime (e.g. with a surface gas velocity in the range of about 0.01 to about 1.0 m/s) with a catalyst bed density in the range of about 480 kg/m3 to about 800 kg/m3. The weight hourly space velocity (WHSV) in the second reactor 32 is generally in the range of about 0.5 hr -1 to about 50 hr -1 ; steam and catalyst residence times can range from about 2 to about 20 seconds. The height H1 of the stripper bed is generally 1 to 5 times the diameter (D2) of the second counterflow reactor 32. The height H2 of the active catalyst bed available for C4/naphtha loading reaction is 2 to 10 times D2, which is located above the stripper bed 32a. The height H3 of the catalyst separation zone is generally 1 to 5 times the diameter (D2) of the second counterflow reactor 32. The difference in the location of the C4 charge and the naphtha charge is 1 to 7 times D2 or 2 at 7 times D1 of the tangent line from the bottom of the second reactor vessel 32. Preferably, the C4 charge is carried out below the injection of the naphtha charge. However, switching of charge injection locations is possible, and the charge location may depend on the desired target products. Depending on the objectives and residence time requirements, the diameter (D2) of the second reactor vessel can be 1 to 3 times the diameter (D1) of the stripper bed 32a.
    [041] The regenerator 17 operates in a conventional turbulence flow regime, presenting a surface gas velocity in the range of 0.5 to 1.2 m/s with a bed density in the range of 400 to 600 kg/m3.
    [042] As needed, the catalyst composition can be introduced through one or more flow lines 42,43. For example, the FCC or Y-type zeolite catalyst composition or a mixture of these two can be introduced into the regenerator 17 through the flow line 42, and the ZSM-5/ZSM-11 catalyst composition can be introduced into the second reactor. 32 through the flow line 43.
    [043] The countercurrent flow reactor can be equipped with baffles or internal structures, such as modular grids, as described in US Patent 7,179,427. Other types of internal parts that improve contact effectiveness and product selectivity/yield can also be used. Internal parts can improve catalyst distribution through the reactor and its contact with charge vapors, leading to an increase in the average reaction rate, improving overall catalyst activity, and optimizing operating conditions to increase production of light olefins.
    [044] The embodiments described in the present invention use conventional Y-type or FCC zeolite catalysts, maximizing the conversion of heavy hydrocarbon loads. Y-type or FCC zeolite catalyst features a smaller and lighter particle size than ZSM-5 or similar used to improve light olefin production in the countercurrent flow reactor. The ZSM-5 or similar catalyst has a larger and denser particle size than the Y-type or FCC zeolite used to preferably maintain a bed of the ZSM-5 catalyst in the countercurrent flow reactor. The surface gas velocity of vapors in the second reactor is maintained to allow retention of the Y-type or FCC zeolite catalyst outside the countercurrent flow reactor, utilizing differences in single particle terminal velocities or differences between minimum bubbling/ fluidization. This concept allows the elimination of two-stage FCC systems and consequently a simplified and efficient process. The catalysts employed in the process can be a combination of the zeolite catalyst type Y/FCC and ZSM-5 or other similar catalysts, such as those mentioned in US5043522 and US5846402.
    [045] Another benefit of the embodiments described in the present invention is that the two-integrated reactor scheme overcomes the heat balance limitations in C4/naphtha catalytic cracking processes. The countercurrent flow reactor acts as a heat sink due to integration with the catalyst regenerator, minimizing the chiller requirement during the processing of waste raw materials.
    [046] Product vapors from the countercurrent flow reactor are transported into the first stage reactor/separation flask or reaction termination device where these vapors are mixed and cooled with the first stage products and/or external cooling means , such as LCO or vapors to minimize unwanted thermal cracking reactions. Alternately, the product output line from the countercurrent flow reactor can also be used to introduce an additional amount of heavy load or part of load redirection from the first stage reactor (riser reactor). This serves two purposes: (1) the catalyst in the steam outlet line of the countercurrent flow reactor is predominantly conventional Y-type zeolite/FCC which is preferentially for breaking down these heavy charge molecules into middle distillates, and (2) such Cracking reaction is endothermic and helps to reduce the temperature of the vapors of the products in progress and also the residence time.
    [047] In the embodiments described in the present invention, an existing FCC unit can be retrofitted with a countercurrent flow reactor. For example, a suitably sized reactor can be connected to a catalyst regeneration vessel to provide for catalyst loading and return from the countercurrent flow vessel and be connected to an existing separation vessel to separate the hydrocarbon and catalyst products. . In other words, a countercurrent flow reactor can be added to an FCC base unit that is used in gasoline mode, light olefin mode or diesel mode.
    [048] As described above, a countercurrent bubbling bed or turbulent bed reactor with baffles or appropriate internals is integrated with an FCC riser reactor and separation system. This countercurrent flow reactor is in fluid communication with other vessels, allowing selective catalytic cracking and cooling of the integrated hydrocarbon product, separation and catalyst regeneration.
    [049] Such an integrated reactor system offers one or more of the following advantages. First, countercurrent flow of catalyst and light hydrocarbon feed (load streams from C4 olefins to naphtha) can provide an optimal and uniform temperature profile across the reaction zone and availability of active catalyst sites (contact of regenerated catalyst as reactants move upstream through the reaction zone), increasing the average reaction rate. Due to the endothermic nature of the cracking reactions, the temperature decreases along the height of the reactor, but the hot regenerated catalyst counterbalances the heat input. In fact, the countercurrent flow reaction indirectly helps in maintaining uniform temperature along the length of the reactor. The reactor configuration produces a high yield of light olefins by increasing the average reaction rate and catalyst activity. This reactor can be operated at significantly higher reaction temperatures to satisfy the high activation energy requirements to break down such lighter loads.
    [050] Second, the second reactor can be supplied with baffles or modular grid internal structures. These internal structures/baffles can provide intimate contact of the catalyst with the hydrocarbon filler molecules, resulting in bubble elimination and prevention of bubble formation due to coalescence, as well as channeling or diversion of the catalyst or filler. Reactor internal structures/baffles aid in mixing, distributing and contacting the hydrocarbon and catalyst charge, improving selectivity for desired light olefin products while minimizing dry gas and coke formation.
    [051] Third, the reactor layout is such that the reaction and separation can be carried out in a single vessel. Separation is carried out at the bottom of the countercurrent flow reactor. The separation stream flows to the bottom of the reaction section and acts as a diluent to control the partial pressure of the hydrocarbons.
    [052] Split injection of hydrocarbon load streams into sections into the countercurrent flow reactor can also help maintain a desired WHSV, which is optimal for each feedstock. For example, a C4 hydrocarbon load stream requires a lower WHSV while a naphtha load requires a relatively higher WHSV.
    [053] The product vapors from the countercurrent flow reactor are also advantageously redirected to the upper first reactor (riser), being able to reduce the temperature of the reactor products due to the cooling at lower temperatures of the riser reactor. These cracked hydrocarbon products can also be cooled using light cycle oil (LCO) and/or cooling stream within the first stage reactor vessel. The termination device of the first stage riser reactor is also used to quickly separate product vapors and redirect them to a product recovery section, thereby advantageously reducing unwanted thermal cracking reactions and improving product selectivity.
    [054] The processes described in the present invention also use two types of catalyst particles, such as zeolite Y/FCC catalyst of smaller, lower density particles and larger, higher density ZSM-5 particles. This allows for the retention of lighter and smaller particles in the catalyst separation zone of the countercurrent flow reactor, thereby retaining the ZSM-5 type particles in the reaction zone of the countercurrent reactor. The lighter hydrocarbon feedstock is subjected to selective catalytic cracking in the presence of the ZSM-5 type catalyst to maximize light olefin yield. The adverse effects of prior art catalyst deactivation due to torch-oil burning in the regenerator to maintain thermal equilibrium are also avoided.
    [055] Although less coke is produced from the countercurrent flow reactor, the integration of this reactor with an FCC unit regeneration-reactor system eliminates the thermal balance problems of previous techniques. As a result, the embodiments described in the present invention can advantageously increase the residue content in the heavy load for the first stage riser reactor, while the countercurrent flow reactor assists in removing excessive heat from the regenerator. The use of countercurrent flow reactor can also avoid the need to use a catalyst cooler during waste processing.
    [056] The embodiments described in the present invention also encompass the separation of aromatics from the products in the naphtha range prior to recycling to the countercurrent flow reactor. Likewise, C4 streams after separation of C3/C4 mixtures can be recycled to the countercurrent flow reactor. These steps can help to reduce the size of the countercurrent flow reactor, improving throughput conversion.
    [057] Countercurrent flow reactors as described in the present invention can be easily inserted into existing FCC units operating in gasoline mode, light olefins mode or diesel mode, offering additional capacity, flexibility of operation and improved light olefin production. . Combining the aspects of a countercurrent flow reactor with the reactor's internal products greatly improves the conversion and selectivity of the desired products.
    [058] Depending on product requirements, the countercurrent flow reactor can also be easily isolated, without requiring unit shutdown, allowing the riser reactor, catalyst regenerator and separation vessel to continue in operation.
    [059] Conventionally, the catalyst composition to maintain its activity is introduced into the regenerator bed using unit air. On the contrary, the embodiments described in the present invention can advantageously inject catalyst of the ZSM-5 type directly into the second reactor bed using current or nitrogen as the conversion medium, producing increased yields of light olefins.
    [060] The countercurrent flow reactor can also offer flexibility and operating window to adjust operating conditions, such as weight hourly space velocity (WHSV), hydrocarbon vapor and catalyst residence time, reaction temperature, catalyst/oil ratio, etc. For example, the upstream counterflow reactor and bed temperature can be controlled by adjusting the catalyst flow of the catalyst regenerator, which indirectly controls the catalyst/oil ratio. Reactor bed level can be controlled by manipulating spent catalyst flow from reactor to regenerator, controlling WHSV and catalyst residence time.
    [061] One or more of the above advantages and aspects of the embodiments of the processes described in the present invention may offer an improved process for catalytic cracking of hydrocarbons to produce light olefins.
    [062] Although the description includes a limited number of embodiments, those skilled in the art, reviewing the benefits of this description, will appreciate that other embodiments can be devised without departing from the scope of the present invention. In this way, the scope can be limited only by the attached claims.
    权利要求:
    Claims (16)
    [0001]
    1. Process for catalytic cracking of hydrocarbons CHARACTERIZED in that it comprises: regenerating a spent catalyst comprising a first cracking catalyst with a first average particle size and density, and a second cracking catalyst with a second average particle size and density in a catalyst regeneration vessel (17) to form a regenerated catalyst comprising the first cracking catalyst and the second cracking catalyst, wherein the average particle size of the first cracking catalyst is smaller than the average particle size of the second catalyst and wherein the first cracking catalyst comprises a Y-type zeolite catalyst and the second cracking catalyst comprises a ZSM-5 catalyst; contacting, in cocurrent flow, a first hydrocarbon charge with a first portion of the catalyst regenerated in a riser reactor (3) to produce going a first effluent comprising a first cracked hydrocarbon product, and a spent catalyst mixing fraction; feeding a second portion of the regenerated catalyst to a countercurrent flow reactor (32); concomitantly into the countercurrent flow reactor (32): separating the first cracking catalyst from the second cracking catalyst based on at least one of density and particle size; contacting, in countercurrent flow, a second hydrocarbon charge with the second cracking catalyst to produce a second cracked hydrocarbon product; recovering a second effluent from the countercurrent flow reactor (32) comprising the second cracked hydrocarbon product and the first cracking catalyst; recovering a third effluent comprising the second spent catalyst; feeding the first effluent and the second effluent to a separation vessel (8) to separate the mixed spent catalyst fraction and the first cracking catalyst separated from the first and second cracked hydrocarbon products; and feeding the separated catalysts from the separation vessel (8) to the catalyst regeneration vessel (17) as the spent catalyst.
    [0002]
    Process according to claim 1, CHARACTERIZED in that it further comprises feeding the separated catalysts from the separation vessel (8) to a stripper (9) of the spent catalyst to separate additional hydrocarbons from the separated catalysts before feeding the separated catalysts to the catalyst regeneration vessel (17).
    [0003]
    3. Process according to claim 1, CHARACTERIZED in that the first hydrocarbon fraction comprises at least one of a C4 hydrocarbon fraction, a naphtha fraction and a heavy hydrocarbon fraction.
    [0004]
    4. Process according to claim 1, CHARACTERIZED in that the second hydrocarbon fraction comprises at least one of a C4 hydrocarbon fraction and a naphtha fraction.
    [0005]
    5. Process, according to claim 4, CHARACTERIZED in that the C4 hydrocarbon fraction is fed to the countercurrent flow reactor (32) at a height below the naphtha fraction.
    [0006]
    6. Process, according to claim 1, CHARACTERIZED in that it further comprises contacting the second effluent with a third intermediate hydrocarbon fraction between the countercurrent flow reactor (32) and the separation vessel (8) to cool the second effluent, breaking down the third hydrocarbon fraction or a combination thereof.
    [0007]
    7. Process, according to claim 6, CHARACTERIZED in that it further comprises controlling a temperature of the cooled effluent by adjusting the flow rate of the third hydrocarbon fraction.
    [0008]
    8. Process, according to claim 6, CHARACTERIZED by the fact that the third hydrocarbon fraction comprises light cycle oil.
    [0009]
    9. Process, according to claim 1, CHARACTERIZED in that it further comprises contacting the second effluent with a cooling medium.
    [0010]
    10. Process, according to claim 1, CHARACTERIZED by the fact that the riser reactor (3) operates with a surface gas velocity in the range of 3 m/s to 10 m/s, close to the inlet, and in the range of 10 m/ sa 25 m/s near the exit.
    [0011]
    11. Process, according to claim 1, CHARACTERIZED by the fact that the countercurrent flow reactor (32) operates with a surface gas velocity in the range of 0.01 m/s to 1.0 m/s, and in which the surface gas velocity in the countercurrent flow reactor (32) is sufficient to separate the first cracking catalyst from the second cracking catalyst.
    [0012]
    12. Process according to claim 1, CHARACTERIZED in that the countercurrent flow reactor (32) comprises a lower separation zone, an intermediate reaction zone and an upper catalyst separation zone, and the process further comprises operating the countercurrent flow reactor (32) so that the intermediate reaction zone has a catalyst bed density in the range of 480 kg/m3 to 800 kg/m3.
    [0013]
    Process according to claim 12, CHARACTERIZED in that it further comprises feeding a separation medium comprising stream or an inert gas to the separation zone to separate cracked hydrocarbons from the second cracking catalyst.
    [0014]
    Process according to claim 1, CHARACTERIZED in that it further comprises feeding the fresh catalyst or first cracking catalyst composition to the catalyst regeneration vessel (17).
    [0015]
    Process according to claim 1, CHARACTERIZED in that it further comprises feeding the fresh catalyst or composition of the second cracking catalyst to at least one of the catalyst regeneration vessel (17) and the countercurrent flow reactor (32) .
    [0016]
    A process according to claim 1, CHARACTERIZED in that it further comprises feeding the fresh catalyst or composition of the second cracking catalyst to the countercurrent flow reactor (32).
    类似技术:
    公开号 | 公开日 | 专利标题
    BR112015000528B1|2022-01-18|PROCESS FOR THE CATALYTIC CRACKING OF HYDROCARBONS
    KR102305664B1|2021-09-28|Fluid Catalytic Cracking Process and Apparatus and Other Applications to Maximize Light Olefin Yields
    US9458394B2|2016-10-04|Fluidized catalytic cracking of paraffinic naphtha in a downflow reactor
    US11161086B2|2021-11-02|Fluid catalytic cracking process and apparatus for maximizing light olefin yield and other applications
    BR112020000586A2|2020-07-14|integrated thermal and catalytic cracking for olefin production
    US20210002564A1|2021-01-07|Fluid catalytic cracking processes and apparatus
    KR20220024578A|2022-03-03|Fluid Catalytic Cracking Method and Apparatus
    CA3146557A1|2021-01-21|Fluid catalytic cracking process and apparatus for maximizing light olefin yield and other applications
    同族专利:
    公开号 | 公开日
    EP2872602B1|2018-02-14|
    CL2015000086A1|2015-07-31|
    MX2015000320A|2015-06-17|
    TWI599400B|2017-09-21|
    CO7250452A2|2015-04-30|
    AU2013290283A1|2015-02-26|
    US20140014555A1|2014-01-16|
    BR112015000528A2|2017-06-27|
    NO2972050T3|2018-07-21|
    CA2878908C|2017-02-28|
    KR102115859B1|2020-05-28|
    PH12015500072A1|2015-03-30|
    CA2878908A1|2014-01-16|
    LT2872602T|2018-07-10|
    TW201404463A|2014-02-01|
    SG11201500163YA|2015-02-27|
    PH12015500072B1|2015-03-30|
    EP2872602A1|2015-05-20|
    UA118017C2|2018-11-12|
    CN104583373A|2015-04-29|
    IN2015MN00043A|2015-10-16|
    JP6172819B2|2017-08-02|
    NZ704346A|2017-03-31|
    CN104583373B|2016-08-24|
    MY169106A|2019-02-18|
    PH12016502528A1|2017-08-07|
    ZA201500347B|2016-01-27|
    PH12016502528B1|2017-08-07|
    EP2872602A4|2016-04-13|
    KR20150038043A|2015-04-08|
    WO2014011759A1|2014-01-16|
    US10184088B2|2019-01-22|
    US9452404B2|2016-09-27|
    JP2015528037A|2015-09-24|
    US20170009150A1|2017-01-12|
    EA028567B1|2017-12-29|
    AU2013290283B2|2017-09-28|
    EA201590192A1|2015-04-30|
    引用文献:
    公开号 | 申请日 | 公开日 | 申请人 | 专利标题
    US486358A|1892-11-15|Hand attachment for sewing-machines |
    US3573200A|1968-12-04|1971-03-30|Chevron Res|Catalyst makeup|
    US4116814A|1977-07-18|1978-09-26|Mobil Oil Corporation|Method and system for effecting catalytic cracking of high boiling hydrocarbons with fluid conversion catalysts|
    US4541923A|1984-02-29|1985-09-17|Uop Inc.|Catalyst treatment and flow conditioning in an FCC reactor riser|
    AU607435B2|1986-09-03|1991-03-07|Mobil Oil Corporation|Process for fluidized catalytic cracking with reactive fragments|
    US4871446A|1986-09-03|1989-10-03|Mobil Oil Corporation|Catalytic cracking process employing mixed catalyst system|
    US4863585A|1986-09-03|1989-09-05|Mobil Oil Corporation|Fluidized catalytic cracking process utilizing a C3-C4 paraffin-rich Co-feed and mixed catalyst system with selective reactivation of the medium pore silicate zeolite component thereofo|
    US4892643A|1986-09-03|1990-01-09|Mobil Oil Corporation|Upgrading naphtha in a single riser fluidized catalytic cracking operation employing a catalyst mixture|
    US4717466A|1986-09-03|1988-01-05|Mobil Oil Corporation|Multiple riser fluidized catalytic cracking process utilizing hydrogen and carbon-hydrogen contributing fragments|
    AU605503B2|1986-09-03|1991-01-17|Mobil Oil Corporation|FCC naphtha in a single riser fluid catalytic cracking operation employing a catalyst mixture.|
    US4874503A|1988-01-15|1989-10-17|Mobil Oil Corporation|Multiple riser fluidized catalytic cracking process employing a mixed catalyst|
    US5043522A|1989-04-25|1991-08-27|Arco Chemical Technology, Inc.|Production of olefins from a mixture of Cu+ olefins and paraffins|
    US5043058A|1990-03-26|1991-08-27|Amoco Corporation|Quenching downstream of an external vapor catalyst separator|
    US5846402A|1997-05-14|1998-12-08|Indian Oil Corporation, Ltd.|Process for catalytic cracking of petroleum based feed stocks|
    US6106697A|1998-05-05|2000-08-22|Exxon Research And Engineering Company|Two stage fluid catalytic cracking process for selectively producing b. C.su2 to C4 olefins|
    US5944982A|1998-10-05|1999-08-31|Uop Llc|Method for high severity cracking|
    US6835863B2|1999-07-12|2004-12-28|Exxonmobil Oil Corporation|Catalytic production of light olefins from naphtha feed|
    US6514403B1|2000-04-20|2003-02-04|Abb Lummus Global Inc.|Hydrocracking of vacuum gas and other oils using a cocurrent/countercurrent reaction system and a post-treatment reactive distillation system|
    CN1205305C|2001-11-29|2005-06-08|中国石油化工股份有限公司|New-type catalytic cracking reaction-regeneration system|
    US20030127358A1|2002-01-10|2003-07-10|Letzsch Warren S.|Deep catalytic cracking process|
    US6869521B2|2002-04-18|2005-03-22|Uop Llc|Process and apparatus for upgrading FCC product with additional reactor with thorough mixing|
    US7179427B2|2002-11-25|2007-02-20|Abb Lummus Global Inc.|Apparatus for countercurrent contacting of gas and solids|
    CN1308419C|2003-12-12|2007-04-04|石油大学|Multiple effects coupled technical method of fluidization and catalytic reactions in dual reaction regeneration system|
    US7128827B2|2004-01-14|2006-10-31|Kellogg Brown & Root Llc|Integrated catalytic cracking and steam pyrolysis process for olefins|
    US20050161369A1|2004-01-23|2005-07-28|Abb Lummus Global, Inc.|System and method for selective component cracking to maximize production of light olefins|
    BRPI0403184B1|2004-07-30|2015-04-07|Petroleo Brasileiro Sa|Process for changing the distribution of hydrocarbon fluid catalytic cracking products|
    AU2005274030B2|2004-08-10|2008-11-20|Shell Internationale Research Maatschappij B.V.|Method and apparatus for making a middle distillate product and lower olefins from a hydrocarbon feedstock|
    US7323099B2|2004-11-19|2008-01-29|Exxonmobil Chemical Patents Inc.|Two stage fluid catalytic cracking process for selectively producing C2 to C4 olefins|
    US20070205139A1|2006-03-01|2007-09-06|Sathit Kulprathipanja|Fcc dual elevation riser feed distributors for gasoline and light olefin modes of operation|
    US20080011645A1|2006-07-13|2008-01-17|Dean Christopher F|Ancillary cracking of paraffinic naphtha in conjuction with FCC unit operations|
    US7611622B2|2006-12-29|2009-11-03|Kellogg Brown & Root Llc|FCC process for converting C3/C4 feeds to olefins and aromatics|
    ES2645694T3|2008-12-10|2017-12-07|Reliance Industries Limited|Catalytic fluidized bed cracking process for manufacturing propylene and ethylene with increased performance|
    US8354018B2|2009-11-09|2013-01-15|Uop Llc|Process for recovering products from two reactors|
    CN102086402B|2009-12-03|2014-01-15|中国石油化工股份有限公司|Catalytic cracking method and device capable of increasing propylene yield and improving properties of gasoline|
    WO2012004809A1|2010-07-08|2012-01-12|Indian Oil Corporation Ltd.|Two stage fluid catalytic cracking process and apparatus|WO2016199164A1|2015-06-09|2016-12-15|Hindustan Petroleum Corporation Ltd.|Catalyst composition for fluid catalytic cracking, and use thereof|
    EP3512923A4|2016-09-16|2020-05-13|Lummus Technology LLC|Fluid catalytic cracking process and apparatus for maximizing light olefin yield and other applications|
    JP6860675B2|2016-09-16|2021-04-21|ラマス・テクノロジー・リミテッド・ライアビリティ・カンパニーＬｕｍｍｕｓ Ｔｅｃｈｎｏｌｏｇｙ ＬＬＣ|Processes and equipment for improved removal of contaminants in fluid cracking processes|
    WO2021011252A1|2019-07-15|2021-01-21|Lummus Technology Llc|Fluid catalytic cracking process and apparatus for maximizing light olefin yield and other applications|
    US10758883B2|2016-09-16|2020-09-01|Lummus Technology Llc|Fluid catalytic cracking process and apparatus for maximizing light olefin yield and other applications|
    CN107961744B|2016-10-19|2022-02-18|中国科学院大连化学物理研究所|Method and device for preparing propylene and C4 hydrocarbons|
    EP3558908A1|2016-12-21|2019-10-30|SABIC Global Technologies B.V.|Process to produce olefins from a catalytically cracked hydrocarbons stream|
    US10767117B2|2017-04-25|2020-09-08|Saudi Arabian Oil Company|Enhanced light olefin yield via steam catalytic downer pyrolysis of hydrocarbon feedstock|
    WO2018220643A1|2017-05-28|2018-12-06|Hindustan Petroleum Corporation Limited|Fluid catalytic cracking process|
    CA3069332A1|2017-07-18|2019-01-24|Lummus Technology Llc|Integrated thermal and catalytic cracking for olefin production|
    CN107460005B|2017-07-26|2019-05-21|天津大学|The method and device of aromatic hydrocarbon and alkene is prepared using bio oil catalytic hydrogenation coupling and catalyzing cracking|
    CN107597201B|2017-09-13|2019-10-08|上海华畅环保设备发展有限公司|Oil-containing outlet catalyst treatment and sorting reuse method and device|
    US10781377B2|2017-11-30|2020-09-22|Uop Llc|Process and apparatus for cracking hydrocarbons to lighter hydrocarbons|
    WO2020109885A1|2018-11-27|2020-06-04|King Abdullah University Of Science And Technology|Zoned fluidization process for catalytic conversion of hydrocarbon feedstocks to petrochemicals|
    TW202104562A|2019-04-03|2021-02-01|美商魯瑪斯科技有限責任公司|Staged fluid catalytic cracking processes incorporating a solids separation device for upgrading naphtha range material|
    WO2021019465A1|2019-07-31|2021-02-04|Sabic Global Technologies B.V.|Dense phase fluidized bed reactor to maximize btx production yield|
    WO2021024119A1|2019-08-05|2021-02-11|Sabic Global Technologies B.V.|Turbulent/fast fluidized bed reactor with baffles to maximize light olefin yields|
    WO2021091886A1|2019-11-04|2021-05-14|Lummus Technology Llc|Fluid catalytic cracking feed injector|
    US20210284921A1|2020-03-13|2021-09-16|Lummus Technology Llc|Production of light olefins from crude oil via fluid catalytic cracking process and apparatus|
    US20220033714A1|2020-07-28|2022-02-03|Saudi Arabian Oil Company|Methods and apparatuses for processing hydrocarbons to produce light olefins|
    法律状态:
    2018-12-04| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|
    2020-01-14| B06U| Preliminary requirement: requests with searches performed by other patent offices: procedure suspended [chapter 6.21 patent gazette]|
    2021-03-16| B07A| Application suspended after technical examination (opinion) [chapter 7.1 patent gazette]|
    2021-11-23| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|
    2022-01-18| B16A| Patent or certificate of addition of invention granted [chapter 16.1 patent gazette]|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 10/07/2013, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US13/547,807|US9452404B2|2012-07-12|2012-07-12|Fluid cracking process and apparatus for maximizing light olefins or middle distillates and light olefins|
    US13/547,807|2012-07-12|
    PCT/US2013/049906|WO2014011759A1|2012-07-12|2013-07-10|Fluid catalytic cracking process and apparatus for maximizing light olefins or middle distillates and light olefins|
    [返回顶部]