[go: up one dir, main page]

WO2021011142A1 - Atomisation et pyrolyse d'une charge de craquage de résidus - Google Patents

Atomisation et pyrolyse d'une charge de craquage de résidus Download PDF

Info

Publication number
WO2021011142A1
WO2021011142A1 PCT/US2020/038078 US2020038078W WO2021011142A1 WO 2021011142 A1 WO2021011142 A1 WO 2021011142A1 US 2020038078 W US2020038078 W US 2020038078W WO 2021011142 A1 WO2021011142 A1 WO 2021011142A1
Authority
WO
WIPO (PCT)
Prior art keywords
fluid
stream
nozzle
resid
particles
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Ceased
Application number
PCT/US2020/038078
Other languages
English (en)
Inventor
Paul F. Keusenkothen
Zachary D. YOUNG
Mohsen N. Harandi
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
ExxonMobil Chemical Patents Inc
Original Assignee
ExxonMobil Chemical Patents Inc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by ExxonMobil Chemical Patents Inc filed Critical ExxonMobil Chemical Patents Inc
Priority to US17/627,060 priority Critical patent/US12151223B2/en
Publication of WO2021011142A1 publication Critical patent/WO2021011142A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

Links

Classifications

    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G9/00—Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
    • C10G9/28—Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid material
    • C10G9/30—Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid material according to the "moving bed" method
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J12/00—Chemical processes in general for reacting gaseous media with gaseous media; Apparatus specially adapted therefor
    • B01J12/005—Chemical processes in general for reacting gaseous media with gaseous media; Apparatus specially adapted therefor carried out at high temperatures, e.g. by pyrolysis
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J19/00—Chemical, physical or physico-chemical processes in general; Their relevant apparatus
    • B01J19/26—Nozzle-type reactors, i.e. the distribution of the initial reactants within the reactor is effected by their introduction or injection through nozzles
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J4/00—Feed or outlet devices; Feed or outlet control devices
    • B01J4/001—Feed or outlet devices as such, e.g. feeding tubes
    • B01J4/002—Nozzle-type elements
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J6/00—Heat treatments such as Calcining; Fusing ; Pyrolysis
    • B01J6/008—Pyrolysis reactions

Definitions

  • the present disclosure relates to an apparatus and a process for conversion of petroleum resid fluids through atomization and pyrolysis.
  • Heavy oils including heavy crudes, reduced crudes, residual oils from distillation processes, and bitumens, are relatively low value products and unsuitable for many of the purposes for which lighter hydrocarbon products can be practically used.
  • lighter hydrocarbon products can be practically used.
  • a multiplicity of refining processes have been developed and used
  • Fluid Catalytic Cracking (FCC) and Resid Catalytic Cracking (RCC or RFCC) are important conversion processes that convert high-boiling, high-molecular weight hydrocarbon fractions of petroleum crude oils into more valuable gasoline, olefinic gases, and other products.
  • the feedstock to FCC/RCC is usually that portion of the crude oil that has an initial boiling point of 340 °C or higher at atmospheric pressure and an average molecular weight ranging from 200 g/mol to 600 g/mol or higher.
  • the feedstock is heated to a temperature range of from 495° C to 565° C and brought into contact with a catalyst.
  • a process using FCC/RCC catalysts may be carried out in riser reactors in which catalyst streams composed of catalyst particles and gas are brought into contact with oil and reacted.
  • the catalyst chemically breaks the long-chain molecules of the high-boiling hydrocarbon liquids into much shorter molecules, which are collected as a vapor.
  • the catalyst particles typically have an average particle size in the range from 60 pm to 150 pm.
  • the reactions proceed with resid-catalyst contact times (in the riser) from 0.5 to 5 seconds.
  • resid steam cracking Unlike catalytic cracking, resid steam cracking has not been successfully commercialized. Typically, resid steam cracking utilizes a nozzle having small inlet ports to generate a resid vapor. Often, the inlet ports quickly foul due to the mixed-phase resid cracking feed. The viscosity of the heavy resid feed may slow fluidized flow, and/or solids may agglomerate, thereby bogging fluidized flow.
  • a method comprises (consists of, consists essentially of) generating a stream of atomized resid fluid; and delivering the stream to a plurality of cracking particles, wherein the cracking particles have a temperature from 700 °C to 1200 °C when the stream is delivered.
  • an apparatus (consists of, consists essentially of) a first multi phase fluid application device configured to generate a first stream of atomized resid fluid; a port configured to guide a plurality of cracking particles to intersect the first stream; and a particle heating component configured to heat the cracking particles before the particles intersect the first stream.
  • FIG. 1A illustrates an exemplary multi-phase fluid application device
  • FIG. IB illustrates another exemplary multi-phase fluid application device.
  • FIG. 2 illustrates an exemplary cracking particle.
  • FIG. 3 A illustrates an exemplary apparatus for conversion of petroleum resid fluids to one or more cracked products.
  • FIG. 3B illustrates an exemplary apparatus for conversion of petroleum resid fluids to one or more cracked products.
  • the term“simultaneous” does not necessarily mean that two or more events occur at precisely the same time or over exactly the same time period. Rather, as used herein, “simultaneous” means that the two or more events occur near in time or during overlapping time periods. For example, the two or more events may be separated by a short time interval that is small compared to the duration of the overall operation. As another example, the two or more events may occur during time periods that overlap by 40% to 100% of either period.
  • hydrocarbon means a class of compounds containing hydrogen bound to carbon, and encompasses (i) saturated hydrocarbon compounds, (ii) unsaturated hydrocarbon compounds, and (iii) mixtures of hydrocarbon compounds (saturated and/or unsaturated), including mixtures of hydrocarbon. Additionally, the hydrocarbon compound may contain, for example, heteroatoms such as sulfur, oxygen, nitrogen, or any combination thereof.
  • reactor refers to equipment used for chemical conversion. As such, several items identified as reactors may be combined to become a single entity that is also identified as a reactor, in that individual and combined entities may be characterized as equipment used for chemical conversion.
  • a pyrolysis reactor refers to equipment for converting hydrocarbons by means of at least pyrolysis chemistry.
  • the pyrolysis reactor may include one or more reactors and/or associated equipment and lines. That is, in certain embodiments, the pyrolysis reactor may include at least two reactors coupled in series and in fluid communication with each other, or may include two reactor beds in series within a single reactor. Examples of such reactors include, but are not limited to, regenerative reverse-flow reactors as described in US 2007/0191664; and pyrolysis reactors as described in US 7,491,250, US 2007/0144940 and US 2008/0142409.
  • Such a pyrolysis reactor involves at least pyrolysis chemistry.
  • Pyrolysis or pyrolysis chemistry involves the conversion of hydrocarbons to unsaturates, such as ethylene and acetylene, which is an endothermic reaction requiring addition of heat.
  • the terms“crack” and“cracking” may be used interchangeably with the terms pyrolyse and pyrolysis.
  • >50%, >80%, or >90%, of this heat is provided by heat transfer via solid surfaces, such as tubulars or bed materials.
  • Any combustion chemistry that occurs within the pyrolysis stream of a pyrolysis reactor provides a minority of the endothermic heat of pyrolysis, such as ⁇ 50%, ⁇ 20%, or ⁇ 10% of the endothermic heat of pyrolysis.
  • hydrocarbon feed refers to any variety of hydrocarbon compounds.
  • the“hydrocarbon feed” contains hydrocarbons (C bound to H) and may contain (i) minor components of heteroatoms ( ⁇ 10 wt%) covalently bound to hydrocarbons and (ii) minor components of heteroatoms ( ⁇ 10 wt%) not bound to hydrocarbons (e.g., H20), wherein these weight percents are based on the weight of the hydrocarbon feed.
  • Reference to“hydrocarbon compounds” or“hydrocarbons in the hydrocarbon feed” or “hydrocarbons of the hydrocarbon feed” means molecules within the hydrocarbon feed that contain at least hydrogen and carbon and, optionally containing heteroatoms such as oxygen, sulfur and nitrogen.
  • Weight percents of hydrogen and carbon, as used to characterize the hydrocarbon feed are typically provided as a percent of the hydrocarbons in the hydrocarbon feed.
  • the hydrocarbon compounds are comprised of at least 75 percent (%) of both carbon and hydrogen, based on total atom content of the hydrocarbon.
  • the hydrocarbon feed may include, by way of non-limiting examples, one or more of Fischer-Tropsch gases, methane, methane containing streams such as coal bed methane, biogas, associated gas, natural gas and mixtures or components thereof, steam cracked gas oil and residues, gas oils, heating oil, jet fuel, diesel, kerosene, gasoline, coker naphtha, steam cracked naphtha, catalytically cracked naphtha, hydrocrackate, reformate, raffinate reformate, Fischer-Tropsch liquids, natural gasoline, distillate, virgin naphtha, crude oil, atmospheric pipestill bottoms, vacuum pipestill streams including bottoms, wide boiling range naphtha to gas oil condensates, heavy non-virgin hydrocarbon streams from refineries, vacuum gas oils, heavy gas oil, naphtha contaminated with crude, synthetic crudes, shale oils, coal liquefaction products, coal tars, tars, atmospheric resid, heavy residuum, C4'
  • hydrocarbon co-feed generally refers to a co-feed that contains one or more hydrocarbon compounds.
  • fluid hydrocarbon co-feed refers to a hydrocarbon feed that is not in a solid state.
  • the fluid hydrocarbon co-feed can be a liquid hydrocarbon co feed, a gaseous hydrocarbon co-feed, or a mixture thereof.
  • the fluid hydrocarbon co-feed can be fed to a catalytic cracking reactor in a liquid state, and/or in a gaseous state, or in a partially liquid-partially gaseous state.
  • the fluid hydrocarbon co-feed When injected into the catalytic cracking reactor in a liquid state, and/or in a gaseous state, or in a partially liquid-partially gaseous state, the fluid hydrocarbon co-feed may be vaporized upon entry, such as the fluid hydrocarbon co-feed may be contacted in the gaseous state with the FCC catalyst.
  • a hydrocarbon co-feed can be a petroleum oil or petroleum oil component.
  • cracked product(s) refers to product(s) obtained after processing/cracking/breaking down heavy hydrocarbon molecules (usually nonvolatile) into lighter molecules (such as light oils (corresponding to gasoline), middle -range oils used in diesel fuel, residual heavy oils, a solid carbonaceous product known as coke, and such gases as methane, ethane, ethylene, propane, propylene, and butylene) by means of heat, pressure, and/or catalysts in a refinery reactor unit, such as an FCC reactor unit.
  • heavy hydrocarbon molecules usually nonvolatile
  • lighter molecules such as light oils (corresponding to gasoline), middle -range oils used in diesel fuel, residual heavy oils, a solid carbonaceous product known as coke, and such gases as methane, ethane, ethylene, propane, propylene, and butylene
  • residua feedstock may be delivered by an atomization apparatus that reduces bogging and/or feed inlet fouling.
  • the atomization apparatus may avoid fouling by having a high diluent ratio, and/or by heating the residua feedstock to a temperature that provides a low stickiness factor.
  • the term petroleum“residua” (also referred to as“resid,”“resid fluid,” or“resids”) generally refers to a hydrocarbon feed that contains non-volatiles (e.g., asphaltenes, metals, solids).
  • a resid feed may include such feedstock as plastic, crude oil, and/or bio oil.
  • resids include components of large molecular weight, generally containing: (a) asphaltenes and other high molecular weight aromatic structures that would inhibit the rate of hydrotreating/hydrocracking and cause catalyst deactivation; (b) metal contaminants occurring naturally in the crude or resulting from prior treatment of the crude that would tend to deactivate hydrocracking catalysts and interfere with catalyst regeneration; and (c) a relatively high content of sulfur and nitrogen compounds that give rise to objectionable quantities of SO2, SO3, and NO x upon combustion of the petroleum resid. Nitrogen compounds present in the resid also have a tendency to deactivate catalytic cracking catalysts.
  • FIG. 1A illustrates an exemplary multi-phase fluid application device 100.
  • Multi phase fluid application device 100 may be configured to simultaneously deliver (e.g., spray) two or more fluids (e.g., two or more distinct types of fluids and/or two or more distinct fluid phases).
  • multi-phase fluid application device 100 includes a housing 120 for two concentric fluid conduits 131, 132.
  • central fluid conduit 132 may have an internal diameter of from 25 pm to 75 pm.
  • central fluid conduit 132 may have a length of from 15 cm to 45 cm.
  • annular fluid conduit 131 may have an outer diameter of from 0.25 inch to 0.75 inch.
  • annular fluid conduit 131 may have an internal diameter of from 1300 mm to 1500 mm. As a further example, annular fluid conduit 131 may have a length of from 15 cm to 45 cm. In some embodiments (not shown), multi-phase fluid application device 100 includes two or more fluid conduits, any of which may or may not be concentric.
  • Multi-phase fluid application device 100 also includes a nozzle 110.
  • nozzle 110 may be a two-phase nozzle, a three-phase nozzle, a capillary nozzle, or an FCC spray nozzle.
  • Nozzle 110 may include an atomization tip (e.g., a gas-atomizing tip capable of shearing a liquid feedstock into very small particles, reducing surface tension, and/or increasing the number of drops in a given area).
  • nozzle 110 may be configured to deliver a stream (e.g., narrow, focused, convergent, divergent, pulsing, intermittent, jet, etc.) of two or more fluids (e.g., a resid and a diluent).
  • the two or more fluids may be delivered to nozzle 110 by fluid conduits (e.g., concentric fluid conduits 131, 132) in housing 120.
  • one or more fluids e.g., fluid hydrocarbon co-feed
  • nozzle 110 may be configured to deliver a stream having a mean atomized drop diameter of from 3 pm to 50 pm, or from 10 pm to 25 pm.
  • the nozzle may be configured to generate a stream of atomized resid droplets of selected sizes.
  • the initial size of the droplets may depend upon configuration factors such as the viscosity of the liquid, the temperature of the atomization fluid, the shear angle between the atomization fluid and the liquid, and/or the shear rate between the atomization fluid and the liquid.
  • FIG. IB illustrates another exemplary multi-phase fluid application device 101.
  • Multi-phase fluid application device 101 may be configured similarly to multi-phase fluid application device 100, with the exception that the two fluid conduits are adjacent, rather than concentric.
  • FIG. IB shows fluid conduit 231 adjacent to fluid conduit 232 in body 120.
  • Multi-phase fluid application device 101 includes a nozzle 210, which may be configured similarly to nozzle 110, with the exception that the two or more fluids (e.g., feedstocks) may be delivered to nozzle 210 by fluid conduits (e.g., adjacent fluid conduits 231, 232) that are adjacent, rather than concentric.
  • fluid conduits e.g., adjacent fluid conduits 231, 232
  • suitable multi-phase fluid application devices may include housings, fluid conduits, and nozzles having a variety of configurations, each configured to generate a stream of atomized resid droplets of selected sizes.
  • multi-phase fluid application device 100 is configured to transport two fluids separately (e.g., through fluid conduits 131, 132) through housing 120 to nozzle 110, where the two fluids are combined (e.g., mixed, emulsified, etc.).
  • the fluids may combine in housing 120 prior to reaching nozzle 110.
  • nozzle 110 may be configured to retain separation between the two (or more) fluids during some or all of the delivery of the fluid.
  • multi-phase fluid application device 100 may include valves, timing devices, actuators, filters, paddles, perforated conduits, etc., to more precisely control when, where, and how the two or more fluids are combined.
  • Multi-phase fluid application device 100 may also include one or more heating components (e.g., a heat exchanger; not shown).
  • a heating component may be associated with central fluid conduit 132 to heat the fluid transported therethrough.
  • central conduit 132 may be configured to promote and/or control heating of the fluid transported therethrough, such as being made of metal or ceramic materials.
  • a heating component may be associated with annular fluid conduit 131 to heat the fluid transported therethrough.
  • a heating component may be associated with nozzle 110 to heat the fluid during combining and/or delivery of the fluids.
  • nozzle 110 may be configured to operate at high temperatures, such as from 700° C to 1000° C.
  • a heating component may be associated with housing
  • heating components may include sensors, actuators, thermostats, device controllers, etc., to allow precision in heating timing, location, and/or temperature of the various components of multi-phase fluid application device 100 and/or fluids delivered thereby.
  • multi-phase fluid application device 100 is configured to atomize a fluid containing petroleum residua.
  • a resid cracking feed may contain hydrocarbons, such as whole crude to vacuum resid.
  • a resid cracking feed may contain an asphaltene or ash content from 500 ppm to 30 wt%.
  • a resid cracking feed may contain hydrocarbons having a Conradson carbon residue (CCR) from 1% to 20%.
  • multi-phase fluid application device 100 may combine the resid cracking feed with a diluent, either as an atomization fluid or as a second feedstock.
  • a diluent may contain an inert gas (such as N2 ) , steam, etc.
  • the resid cracking feed may be heated from 50°C to 300°C prior to reaching nozzle 110.
  • the resid cracking feed may have a kinematic viscosity from 1 centistokes to 500 centistokes, such as from 3 centistokes to 10 centistokes.
  • nozzle 110 may deliver from 0.5 g/min to 10 g/min resid cracking feed and a total diluent rate (combined nozzle gas and gas cofeed) of 300 ml/min to 2L/min (e.g., in a test unit). In some embodiments, nozzle 110 may deliver a diluent-to- hydrocarbon weight ratio of 0.3 to 1.0 (e.g., at production scales). Note that“atomization” refers to creation of a mist or aerosol, and does not necessarily reduce the fluids into atomic components.
  • FIG. 2 illustrates an exemplary cracking particle 200.
  • particle 200 may include a material having a high thermal or heat capacity (e.g., a ceramic).
  • particle 200 may be a spent and/or deactivated catalyst particle (e.g., dense alumina or spray dried alumina).
  • particle 200 is a sphere, for example, having a diameter 225 of from 40 pm to 400 pm, or from 100 pm to 150 pm. It should be appreciated that particle 200 may be of a variety of three-dimensional geometric shapes, including sphere, ellipsoid, solid with concavity, irregular solid, perforated solid, etc.
  • geometric shapes that provide particle 200 with a higher surface area- to-volume ratio will increase the conversion of petroleum resid fluids according to methods described herein, as compared to geometric shapes that provide a lower surface area-to-volume ratio.
  • the conversion may be close to 100% for gaseous products and/or coke precursors or tars.
  • severity may be an important metric (e.g., the severity ratio of propylene yield over methane yield).
  • the target severity range may be from 0.2 to 1.4.
  • FIG. 3A illustrates an exemplary apparatus 300 for conversion of petroleum resid fluids to one or more cracked products.
  • apparatus 300 includes a multi-phase fluid application device 100 and a plurality of particles 200.
  • the plurality of particles 200 are arranged to move (e.g., translationally) past multi-phase fluid application device 100 in direction 240 (e.g., falling with gravity) to receive application of multi-phased fluids delivered through multi-phase fluid application device 100 (e.g., delivered as stream 115).
  • plurality of particles 200 may be alternatively arranged to move translationally in a variety of fashions, for example, suspended in a tank of fluid, propelled by a column of gas, or resting on a conveyor belt.
  • plurality of particles 200 are also arranged to move rotationally (e.g., by the application of torque) while passing multi-phase fluid application device 100.
  • application of a stream 115 of multi-phase fluids by multi-phase fluid application device 100 to plurality of particles 200 creates a mixture 201 of multi-phase fluid and particles.
  • the impact of the stream 115 on the plurality of particles 200 may affect the arrangement and/or disrupt (e.g., shear) the motion of the plurality of particles 200.
  • the impact of the stream 115 on the plurality of particles 200 may result in mixing and/or spreading-out of the particles 200.
  • the heat energy present in the multi-phase fluid and/or the heat energy present in the plurality of particles 200 may contribute to a thermal reaction during application of the multi-phase fluids to one or more of the plurality of particles 200.
  • the thermal reaction may vaporize the multi-phase fluid to convert petroleum residua therein to one or more cracked products.
  • the multiphase fluid may be vaporized (e.g., reacting to gaseous products), reducing the size of atomized resid droplets.
  • more complete mixing of the atomized droplets in stream 115 with the plurality of particles 200 will produce more efficient vaporization and/or gasification resulting from cracking.
  • more efficient vaporization may produce less agglomeration on the particles 200 and/or fouling of components of apparatus 300.
  • multi -phase fluid application device 100 is positioned in apparatus
  • the length of illustrated normal line 136 provides the distance between the nozzle 110 of multi-phase fluid application device 100 and the plurality of particles 200 (including negative distances indicative of ingress of the nozzle tip into the space occupied by the plurality of particles).
  • the length of normal line 136 may be from -0.5 cm to 10 cm, or from -0.5 cm to 0.5 cm, or from 0 cm to 5 cm, or from 5 cm to 10 cm.
  • the configuration of the nozzle 110, the angle 135, and the distance between the nozzle 110 of multi-phase fluid application device 100 and the plurality of particles 200 may determine a width 137 (e.g., from 0.5 cm to 2 cm, or from 2 cm to 5 cm, or from 5 cm to 10 cm) of stream 115 at a location of the plurality of particles 200.
  • Width 137 may be geometrically related to the flow angle 138 of stream 115, which may range of from 10° to 70°.
  • Apparatus 300 may also include a variety of additional components, such as a speed controller associated with the translational motion of the particles 200, a torque controller associated with the rotational motion of the particles 200, a position controller associated with the length of normal line 136, an aspect controller associated with the angle 135, and a flow controller associated with the volume and time-dependent flux of fluid in stream 115.
  • apparatus 300 and the associated controllers may be configured (e.g., to control the width 137 of stream 115 and/or the speed at which particles 200 pass therethrough).
  • components of apparatus 300 may be configured to adjust the rate of motion of particles 200 to maximize the heat transfer from the particles 200 to the applied multi-phase fluid.
  • components of apparatus 300 may be configured to adjust the residence time (RT) of the resulting vapor or gaseous product.
  • the RT may be representative of the time from initial mixing of the stream 155 and the particles 200 to the time of quenching of the mixture 201 of multi-phase fluid and particles. It is currently believed that vaporization may be improved with higher flow rates of multi-phase fluid, thereby improving the rate of heat transfer and maximizing the slip.
  • each particle 200 may have a RT in the stream 115 from 10 msec to 500 msec.
  • FIG. 3B illustrates in cut-away view another exemplary apparatus 301 for conversion of petroleum resid fluids to one or more cracked products. As illustrated, apparatus
  • each multi-phase fluid application device 102 includes adjacent fluid conduits 331 and 332. As illustrated, for each multi-phase fluid application device 102, adjacent fluid conduits 331, 332 are fluidly coupled to a nozzle 310.
  • each multi -phase fluid application device 102 may deliver a diluent co-feed and a resid co-feed (e.g., solids) through nozzle 310.
  • nozzle 310 may produce atomization of the resid co-feed, generating a stream 115.
  • the pair of multi-phase fluid application devices 102 are illustrated sharing a common housing 320.
  • Housing 320 includes a port 142 through which a plurality of particles 200 move in direction 240 (e.g., falling with gravity).
  • the plurality of particles 200 are arranged to move (e.g., translationally) past streams 115 from multi-phase fluid application devices 102 in direction 240, creating a mixture of multiphase fluid and particles.
  • the impact of the streams 115 on the plurality of particles 200 may affect the arrangement and/or disrupt (e.g., shear) the motion of the plurality of particles 200, resulting in mixing and/or spreading-out of the particles 200.
  • the heat energy present in the multi-phase fluid and/or the heat energy present in the plurality of particles 200 may contribute to a thermal reaction during application of the multi-phase fluids to one or more of the plurality of particles 200, vaporizing the multi-phase fluid to convert petroleum resid fluids therein to one or more cracked products.
  • each multi-phase fluid application device 102 is positioned in apparatus 301 to deliver fluid (e.g., stream 115) at an angle 135 (e.g., from 0° to 90°) relative to the normal line 136 of the translational motion (e.g., direction 240) of the particles 200.
  • fluid e.g., stream 115
  • angle 135 e.g., from 0° to 90°
  • housing 320 may include one or more multi-phase fluid application device 102 positioned port 142. In some embodiments, the one or more multi-phase fluid application devices 102 may be positioned symmetrically port 142. In some embodiments, housing 320 may include a plurality of sub-housings (e.g., one for each multi-phase fluid application device 102) coupled together.
  • Apparatus 300 may also include one or more heating components (not shown).
  • a heating component may be associated with the plurality of particles 200 and/or any associated motion mechanisms.
  • Such heating component may include sensors, actuators, thermostats, device controllers, etc., to allow precision in heating timing, location, and/or temperature of the various components of apparatus 300.
  • the particles 200 may be maintained at a temperature of from 700°C to 1200°C immediately prior to and/or while passing by multi-phase fluid application device 100.
  • apparatus 300 may include additional and/or alternative multi-phase fluid application devices positioned at a variety of distances from, oriented at a variety of aspects relative to, and/or located at a variety of latitudes or longitudes and /or locations along direction 240 of, the plurality of particles 200.
  • apparatus 300 may provide improved devices and methods for conversion of petroleum residua (e.g., commercial resid steam cracking).
  • a atomized stream of resid e.g., stream 115
  • heated cracking particles e.g., plurality of particle 200.
  • pyrolysis rather than catalysis, promotes the cracking. Therefore, more uniform distribution of atomized resid on the surface of the cracking particles may provide more consistent and/or rapid conversion.
  • the heat capacity of the material used for the cracking particles may play a major role in a cracking process as compared to the catalytic properties of the cracking particles during the cracking process.
  • the apparatus may be configured so that the size of the atomized resid droplets corresponds to the size of the cracking particles. It is believed that too large of droplet diameter (relative to particle diameter) may lead to agglomeration of resid on the cracking particles, reducing the effectiveness of thermal transfer
  • a cracking particle may have a diameter of from 50 microns to 150 microns. To avoid agglomeration, the droplets may be smaller by a factor of from 2 to 10, having diameters of from 5 microns to 75 microns.
  • Embodiments disclosed herein provide apparatuses and processes for conversion of petroleum resid fluids through atomization and pyrolysis.
  • Disclosed devices and methods facilitate improvements to conversion of petroleum resid fluids over conventional technology.
  • a disclosed atomization apparatus facilitates delivery of resid feedstock by reducing bogging and/or feed inlet fouling. Some embodiments may avoid fouling by having a high diluent ratio, and/or by heating the resid feedstock to a temperature that provides a low stickiness factor.
  • Some embodiments may deliver the atomized resid to heated particle surfaces for thermalized conversion.
  • Some embodiments may facilitate the thermalized conversion by controlling parameters related to interaction between the resid spray and the particles (such as particle size, shape, velocity, rotation, and/or temperature, and resid spray volume, flux, and geometry).

Landscapes

  • Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Physics & Mathematics (AREA)
  • Thermal Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Engineering & Computer Science (AREA)
  • General Chemical & Material Sciences (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

L'invention concerne un procédé et un appareil de conversion de fluide de résidu de pétrole par atomisation et pyrolyse, comprenant les étapes consistant à : générer un flux de fluide de résidu atomisé ; et fournir le flux à une pluralité de particules de craquage, les particules de craquage ayant une température de 700 °C à 1200 °C lorsque le flux est fourni. La génération du flux de fluide de résidu atomisé peut comprendre les étapes consistant à : fournir un fluide de résidu chauffé à une buse ; et fournir un fluide diluant à la buse. L'invention concerne également un procédé et un appareil qui comprennent : un premier dispositif d'application de fluide multiphase configuré pour générer un premier flux de fluide de résidu atomisé ; un orifice configuré pour guider une pluralité de particules de craquage pour couper le premier flux ; et un composant de chauffage de particules configuré pour chauffer les particules de craquage avant que les particules croisent le premier flux.
PCT/US2020/038078 2019-07-18 2020-06-17 Atomisation et pyrolyse d'une charge de craquage de résidus Ceased WO2021011142A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
US17/627,060 US12151223B2 (en) 2019-07-18 2020-06-17 Atomization and pyrolysis of resid cracking feed

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US201962875674P 2019-07-18 2019-07-18
US62/875,674 2019-07-18
EP19196859.3 2019-09-12
EP19196859 2019-09-12

Publications (1)

Publication Number Publication Date
WO2021011142A1 true WO2021011142A1 (fr) 2021-01-21

Family

ID=71143771

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2020/038078 Ceased WO2021011142A1 (fr) 2019-07-18 2020-06-17 Atomisation et pyrolyse d'une charge de craquage de résidus

Country Status (1)

Country Link
WO (1) WO2021011142A1 (fr)

Citations (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2526696A (en) 1946-03-02 1950-10-24 Lummus Co Process for the simultaneous production of coke and gaseous unsaturated hydrocarbonsand apparatus therefor
US2541693A (en) 1947-07-28 1951-02-13 Dow Chemical Co Production of lower olefins
US2692225A (en) * 1950-09-11 1954-10-19 Phillips Petroleum Co Residuum cracking in a pebble heater
US2692226A (en) 1950-10-07 1954-10-19 Standard Oil Dev Co Shale oil refining process
US3408007A (en) 1964-12-29 1968-10-29 Basf Ag Apparatus for atomizing highly viscous materials
US4919898A (en) 1987-08-11 1990-04-24 Stone & Webster Engineering Corp. Particulate solids cracking apparatus
US6352639B2 (en) * 1999-08-26 2002-03-05 Exxon Research And Engineering Company Superheating atomizing steam with hot FCC feed oil
US20060016726A1 (en) 2004-07-23 2006-01-26 Steffens Todd R Feed injector
US20070144940A1 (en) 2005-12-23 2007-06-28 Frank Hershkowitz Controlled combustion for regenerative reactors
US20080142409A1 (en) 2006-12-15 2008-06-19 Exxonmobil Research And Engineering Company Controlled combustion for regenerative reactors with mixer/flow distributor
US7491250B2 (en) 2002-06-25 2009-02-17 Exxonmobil Research And Engineering Company Pressure swing reforming
WO2018211531A1 (fr) * 2017-05-18 2018-11-22 Hindustan Petroleum Corporation Limited Atomiseur de fluide, unité de craquage catalytique fluidisé et procédé de craquage de combustible hydrocarboné lourd

Patent Citations (13)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2526696A (en) 1946-03-02 1950-10-24 Lummus Co Process for the simultaneous production of coke and gaseous unsaturated hydrocarbonsand apparatus therefor
US2541693A (en) 1947-07-28 1951-02-13 Dow Chemical Co Production of lower olefins
US2692225A (en) * 1950-09-11 1954-10-19 Phillips Petroleum Co Residuum cracking in a pebble heater
US2692226A (en) 1950-10-07 1954-10-19 Standard Oil Dev Co Shale oil refining process
US3408007A (en) 1964-12-29 1968-10-29 Basf Ag Apparatus for atomizing highly viscous materials
US4919898A (en) 1987-08-11 1990-04-24 Stone & Webster Engineering Corp. Particulate solids cracking apparatus
US6352639B2 (en) * 1999-08-26 2002-03-05 Exxon Research And Engineering Company Superheating atomizing steam with hot FCC feed oil
US7491250B2 (en) 2002-06-25 2009-02-17 Exxonmobil Research And Engineering Company Pressure swing reforming
US20060016726A1 (en) 2004-07-23 2006-01-26 Steffens Todd R Feed injector
US20070144940A1 (en) 2005-12-23 2007-06-28 Frank Hershkowitz Controlled combustion for regenerative reactors
US20070191664A1 (en) 2005-12-23 2007-08-16 Frank Hershkowitz Methane conversion to higher hydrocarbons
US20080142409A1 (en) 2006-12-15 2008-06-19 Exxonmobil Research And Engineering Company Controlled combustion for regenerative reactors with mixer/flow distributor
WO2018211531A1 (fr) * 2017-05-18 2018-11-22 Hindustan Petroleum Corporation Limited Atomiseur de fluide, unité de craquage catalytique fluidisé et procédé de craquage de combustible hydrocarboné lourd

Similar Documents

Publication Publication Date Title
JP6158807B2 (ja) 下降流反応装置におけるパラフィン系ナフサの流動接触分解
JP2020152916A (ja) 高速反応器システム
US8663456B2 (en) Process for cracking heavy hydrocarbon feed
KR101787210B1 (ko) 온도 구배 공정에 의한 원유의 직접 촉매 크래킹
JP6797983B2 (ja) 軽質オレフィンの製造のための溶剤脱瀝および流動接触分解の統合された方法
US9896627B2 (en) Processes and systems for fluidized catalytic cracking
CN103270141B (zh) 用于裂解重质烃进料的方法
CN110719949A (zh) 具有部分催化剂再循环的高苛刻度流化催化裂化系统和方法
WO2013150467A2 (fr) Procédé de production de produits chimiques hydrocarbonés à partir d'huile brute
US20120125812A1 (en) Process for Cracking Heavy Hydrocarbon Feed
AU2040600A (en) Fcc feed injection using subcooled water sparging for enhanced feed atomization
US5538625A (en) Process and apparatus for the steam cracking of hydrocarbons in the fluidized phase
WO2014175978A1 (fr) Réactions catalytiques améliorées dans un processus de cokéfaction pour améliorer l'opération de traitement et le rendement économique
US11446625B2 (en) Zoned fluidization process for catalytic conversion of hydrocarbon feedstocks to petrochemicals
US12151223B2 (en) Atomization and pyrolysis of resid cracking feed
US20150076034A1 (en) Coking process and system for enhanced catalytic reactions to improve process operation and economics
WO2021011142A1 (fr) Atomisation et pyrolyse d'une charge de craquage de résidus
JPH05505407A (ja) 流動相で炭化水素を蒸気クラッキングする方法および装置

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 20734823

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 20734823

Country of ref document: EP

Kind code of ref document: A1