WO2013074434A1 - A process for producing hydrocarbons - Google Patents

A process for producing hydrocarbons Download PDF

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Publication number
WO2013074434A1
WO2013074434A1 PCT/US2012/064619 US2012064619W WO2013074434A1 WO 2013074434 A1 WO2013074434 A1 WO 2013074434A1 US 2012064619 W US2012064619 W US 2012064619W WO 2013074434 A1 WO2013074434 A1 WO 2013074434A1
Authority
WO
WIPO (PCT)
Prior art keywords
velocity
catalyst
char
bed
hydropyrolysis
Prior art date
Application number
PCT/US2012/064619
Other languages
English (en)
French (fr)
Inventor
Alan Anthony Del Paggio
Michael John Roberts
Terry Louise Marker
Larry Gordon Felix
Martin Brendan Linck
Original Assignee
Shell Oil Company
Shell Internationale Research Maatschappij B.V.
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 Shell Oil Company, Shell Internationale Research Maatschappij B.V. filed Critical Shell Oil Company
Priority to US14/356,781 priority Critical patent/US9657232B2/en
Priority to CN201280055636.5A priority patent/CN103930524B/zh
Priority to EP12850139.2A priority patent/EP2751224A4/en
Priority to BR112014011536-2A priority patent/BR112014011536B1/pt
Priority to NZ624595A priority patent/NZ624595B2/en
Priority to CA2855791A priority patent/CA2855791C/en
Priority to IN2732CHN2014 priority patent/IN2014CN02732A/en
Publication of WO2013074434A1 publication Critical patent/WO2013074434A1/en
Priority to ZA2014/02620A priority patent/ZA201402620B/en
Priority to US15/452,912 priority patent/US20170198222A1/en

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    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10B—DESTRUCTIVE DISTILLATION OF CARBONACEOUS MATERIALS FOR PRODUCTION OF GAS, COKE, TAR, OR SIMILAR MATERIALS
    • C10B57/00—Other carbonising or coking processes; Features of destructive distillation processes in general
    • C10B57/04—Other carbonising or coking processes; Features of destructive distillation processes in general using charges of special composition
    • C10B57/06—Other carbonising or coking processes; Features of destructive distillation processes in general using charges of special composition containing additives
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D45/00—Separating dispersed particles from gases or vapours by gravity, inertia, or centrifugal forces
    • B01D45/12—Separating dispersed particles from gases or vapours by gravity, inertia, or centrifugal forces by centrifugal forces
    • 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
    • B01J23/00—Catalysts comprising metals or metal oxides or hydroxides, not provided for in group B01J21/00
    • B01J23/70—Catalysts comprising metals or metal oxides or hydroxides, not provided for in group B01J21/00 of the iron group metals or copper
    • B01J23/74—Iron group metals
    • B01J23/755—Nickel
    • 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
    • B01J23/00—Catalysts comprising metals or metal oxides or hydroxides, not provided for in group B01J21/00
    • B01J23/70—Catalysts comprising metals or metal oxides or hydroxides, not provided for in group B01J21/00 of the iron group metals or copper
    • B01J23/76—Catalysts comprising metals or metal oxides or hydroxides, not provided for in group B01J21/00 of the iron group metals or copper combined with metals, oxides or hydroxides provided for in groups B01J23/02 - B01J23/36
    • B01J23/84—Catalysts comprising metals or metal oxides or hydroxides, not provided for in group B01J21/00 of the iron group metals or copper combined with metals, oxides or hydroxides provided for in groups B01J23/02 - B01J23/36 with arsenic, antimony, bismuth, vanadium, niobium, tantalum, polonium, chromium, molybdenum, tungsten, manganese, technetium or rhenium
    • B01J23/85—Chromium, molybdenum or tungsten
    • B01J23/88—Molybdenum
    • B01J23/882—Molybdenum and cobalt
    • 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
    • B01J23/00—Catalysts comprising metals or metal oxides or hydroxides, not provided for in group B01J21/00
    • B01J23/70—Catalysts comprising metals or metal oxides or hydroxides, not provided for in group B01J21/00 of the iron group metals or copper
    • B01J23/76—Catalysts comprising metals or metal oxides or hydroxides, not provided for in group B01J21/00 of the iron group metals or copper combined with metals, oxides or hydroxides provided for in groups B01J23/02 - B01J23/36
    • B01J23/84—Catalysts comprising metals or metal oxides or hydroxides, not provided for in group B01J21/00 of the iron group metals or copper combined with metals, oxides or hydroxides provided for in groups B01J23/02 - B01J23/36 with arsenic, antimony, bismuth, vanadium, niobium, tantalum, polonium, chromium, molybdenum, tungsten, manganese, technetium or rhenium
    • B01J23/85—Chromium, molybdenum or tungsten
    • B01J23/88—Molybdenum
    • B01J23/883—Molybdenum and nickel
    • 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
    • B01J35/00—Catalysts, in general, characterised by their form or physical properties
    • B01J35/30—Catalysts, in general, characterised by their form or physical properties characterised by their physical properties
    • B01J35/31—Density
    • B01J35/32—Bulk density
    • 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
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    • B01J37/02—Impregnation, coating or precipitation
    • B01J37/0201—Impregnation
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    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J37/00—Processes, in general, for preparing catalysts; Processes, in general, for activation of catalysts
    • B01J37/20—Sulfiding
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    • C10B49/04—Destructive distillation of solid carbonaceous materials by direct heating with heat-carrying agents including the partial combustion of the solid material to be treated with hot gases or vapours, e.g. hot gases obtained by partial combustion of the charge while moving the solid material to be treated
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    • C10B53/00—Destructive distillation, specially adapted for particular solid raw materials or solid raw materials in special form
    • C10B53/02—Destructive distillation, specially adapted for particular solid raw materials or solid raw materials in special form of cellulose-containing material
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    • C10B57/00—Other carbonising or coking processes; Features of destructive distillation processes in general
    • C10B57/12—Applying additives during coking
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    • C10G1/00—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
    • C10G1/002—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal in combination with oil conversion- or refining processes
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    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
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    • C10G1/00—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
    • C10G1/008—Controlling or regulating of liquefaction processes
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    • C10G1/02—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by distillation
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    • 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
    • C10G1/00—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
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    • C10G1/08—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal with moving catalysts
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    • 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
    • C10G3/00—Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids
    • C10G3/50—Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids in the presence of hydrogen, hydrogen donors or hydrogen generating compounds
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    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10K—PURIFYING OR MODIFYING THE CHEMICAL COMPOSITION OF COMBUSTIBLE GASES CONTAINING CARBON MONOXIDE
    • C10K1/00—Purifying combustible gases containing carbon monoxide
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    • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G OR C10K; LIQUIFIED PETROLEUM GAS; USE OF ADDITIVES TO FUELS OR FIRES; FIRE-LIGHTERS
    • C10L1/00—Liquid carbonaceous fuels
    • C10L1/02—Liquid carbonaceous fuels essentially based on components consisting of carbon, hydrogen, and oxygen only
    • C10L1/023—Liquid carbonaceous fuels essentially based on components consisting of carbon, hydrogen, and oxygen only for spark ignition
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    • C10L1/02—Liquid carbonaceous fuels essentially based on components consisting of carbon, hydrogen, and oxygen only
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    • 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
    • C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
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    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P30/00—Technologies relating to oil refining and petrochemical industry
    • Y02P30/20—Technologies relating to oil refining and petrochemical industry using bio-feedstock

Definitions

  • the invention relates to a process for producing hydrocarbons from biomass by contacting the biomass with a hydropyrolysis catalyst.
  • the invention further relates to an improved separation between the catalyst and solids produced in the process.
  • a multi-stage process for producing liquid products from biomass in which the biomass is hydropyrolyzed in a reactor vessel containing molecular hydrogen and a deoxygenating catalyst, producing a partially deoxygenated pyrolysis liquid, char, and first stage process heat.
  • the partially deoxygenated pyrolysis liquid is hydrogenated using a hydroconversion catalyst, producing a substantially fully deoxygenated pyrolysis liquid, a gaseous mixture comprising carbon monoxide and light hydrocarbon gases (C1-C4), and second stage process heat.
  • the gaseous mixture is then reformed in a steam reformer, producing reformed molecular hydrogen.
  • the reformed molecular hydrogen is then introduced into the reactor vessel for the hydropyrolysis of additional biomass.
  • This invention provides a process for converting biomass to products comprising: contacting the biomass with hydrogen in the presence of a fluidized bed of
  • hydropyrolysis catalyst in a reactor vessel under hydropyrolysis conditions and removing products and char from the reactor vessel wherein the products leave the fluidized bed at an exit bed velocity, the char has a settling velocity that is less than the exit bed velocity and hydropyrolysis catalyst has a settling velocity that is greater than the exit bed velocity.
  • This invention provides a process for converting biomass to products comprising: contacting the biomass with hydrogen in the presence of a fluidized bed of fresh hydropyrolysis catalyst in a reactor vessel under hydropyrolysis conditions; removing products and char from the reactor vessel; carrying out the contacting and removing steps for a period of time such that the fresh hydropyrolysis catalyst attrits in the fluidized bed to form small catalyst particles; and removing at least a portion of the small catalyst particles with the products and char wherein the products leave the fluidized bed at an exit bed velocity, the char has a settling velocity that is less than the exit bed velocity, the fresh hydropyrolysis catalyst has a settling velocity that is greater than the exit bed velocity, and the small catalyst particles have a settling velocity that is less than the exit bed velocity.
  • Fig. 1 depicts the process flow of the hydropyrolysis process.
  • Fig. 2 depicts the inside of the reactor vessel during operation.
  • Biomass feeds for the hydropyrolysis reactor may include a wide variety of biologically-derived materials, including everything from fat from rendering plants to dried chicken litter. Mixtures of materials from municipal solid waste dumps, for example, plastics, paper, cardboard, yard waste, food residue, etc., may be fed to the hydropyrolysis reactor. It is presumed that any material which breaks down, upon heating, into oxygenated hydrocarbons and/or non-oxygenated hydrocarbons with boiling points in the gasoline, diesel, or kerosene range could potentially be used as feedstock.
  • Preferred biomass feedstocks include lignin, wood and algae.
  • Algae may include whole algae and algal residues, for example, residues derived after any extractive procedures to remove lipids, proteins and/or carbohydrates.
  • the biomass feed is typically prepared for use in the reaction by sizing and drying. The selection of biomass and the feed treatment process play a large role in the characteristics of the char formed in the reaction.
  • the other feed to the process is hydrogen.
  • the hydrogen may be imported for use in the process or produced in a steam reformer.
  • the steam reformer may be fed light hydrocarbons (C1-C4) and carbon monoxide produced in the hydropyrolysis process.
  • the hydropyrolysis reaction is carried out under suitable hydropyrolysis conditions that provide for the production of a partially deoxygenated pyrolysis liquid, char, light hydrocarbons (C1-C4) and carbon monoxide.
  • the temperature of the reaction may be in the range of from about 300 °C to about 600 °C, preferably in the range of from about 350 °C to about 540 °C and more preferably in the range of from about 399 °C to about 450 °C.
  • the pressure of the reaction may be in the range of from about 1.38 MPa to about 6.00 MPa, preferably in the range of from about 1.72 MPa to about 5.50 MPa, more preferably in the range of from about 2.06 MPa to about 5.00 MPa and most preferably in the range of from about 2.76 MPa to about 4.14 MPa.
  • the hydropyrolysis catalyst in the reactor is in the form of a fluidized bed.
  • the velocity of the feed and products upward through the bed is sufficient to maintain the catalyst in a fluidized state.
  • Most of the products are in a gaseous form under the hydropyrolysis reaction conditions and therefore pass in an upward direction through the bed. They pass through the upper portion of the bed and exit the catalyst bed.
  • the velocity at which the gaseous products exit the catalyst bed is referred to herein as the exit bed velocity.
  • the exit bed velocity will be a result of the feed rate, reaction rate, reactor pressure and temperature and reactor dimensions.
  • the settling velocity of a particle is the terminal velocity a particle reaches when traveling in a fluid and is achieved when the drag force of the fluid on the particle is equal and opposite to the force of gravity on the particle.
  • the settling velocity of a particle is a function of the density of the particle, the diameter of the particle, the fluid (gas) density and gravitational acceleration. See Kunii, Daizo and Octave Levenspiel, Fluidization Engineering. 2 nd ed. (Butterworth-Heinemann 1991), p. 80, which is herein incorporated by reference. The shape and other factors are incorporated into an experimentally determined dimensionless drag coefficient.
  • the settling velocity of the individual particles and the gas velocity in the bed can be combined to arrive at a net particle velocity, i.e., the gas velocity in the bed minus the settling velocity of the particle will be the net velocity of the particle.
  • a net particle velocity i.e., the gas velocity in the bed minus the settling velocity of the particle will be the net velocity of the particle.
  • a char particle with a net upward velocity will be carried out of the bed and entrained with the gaseous products because the gas velocity is greater than the settling velocity of the char particles.
  • a catalyst particle will have a net negative (downward) velocity when the settling velocity of the catalyst particle is greater than the gas velocity in the bed, and the catalyst particle will tend to remain in the catalyst bed.
  • the majority of the catalyst it is preferred for the majority of the catalyst to remain in the fluidized catalyst bed and for the majority of the char to be entrained with the gaseous products and carried out of the reaction. It is important to keep as much catalyst as possible in the fluidized bed to maintain the reaction activity and prevent contamination of the char by the metals on the catalyst.
  • the exit bed velocity is a function of the process conditions and the reactor configuration. Specifically, the exit bed velocity can be calculated as the volumetric flow rate of gaseous products exiting the bed divided by the cross sectional area of the reactor at the top of the fluidized catalyst bed. It is preferred for the settling velocity of the catalyst to be at least 1.5 times the settling velocity of the char to achieve an effective separation between the char and catalyst, but the main factor in carrying out this separation is the exit bed velocity.
  • the hydropyrolysis catalyst can be any catalyst known to one of ordinary skill in the art to be useful in this reaction.
  • a suitable catalyst for use in this process has certain physical characteristics that affect its performance in the fluidized bed hydropyrolysis reactor.
  • the settling velocity of the catalyst determines whether the catalyst will remain in the fluidized bed or be eluted from the reactor and carried out with the gaseous products. If the settling velocity of the catalyst is greater than the exit bed velocity then the catalyst will remain in the fluidized bed and not be entrained with the gaseous products.
  • the settling velocity of the catalyst may be any velocity greater than the exit bed velocity, preferably greater than 110% of the exit bed velocity, more preferably greater than 125% of the exit bed velocity and most preferably greater than 150% of the exit bed velocity.
  • Suitable hydropyrolysis catalysts include supported and bulk catalysts.
  • a suitable catalyst for this is a sulfided CoMo or NiMo catalyst impregnated on a spherical alumina support. These catalysts are placed on spherical supports to minimize attrition for use in a fluid bed reactor.
  • Another suitable catalyst is a nickel aluminate or nickel catalyst impregnated on a spherical alumina support. In all cases the catalyst must have enough activity to add hydrogen to the structure and minimize coking reactions.
  • Glass-ceramic catalysts can be extremely strong and attrition resistant and can be prepared as thermally impregnated or as bulk catalysts. When employed as a sulfided NiMo, Ni/NiO, or Co based glass-ceramic catalyst, the resulting catalyst is an attrition resistant version of a readily available, but soft, conventional NiMo, Ni/NiO, or Co based catalyst. Glass-ceramic sulfided NiMo, Ni/NiO, or Co based catalysts are particularly suitable for use in a hot fluidized bed because these materials can provide the catalytic effect of a conventional supported catalyst, but in a much more robust, attrition resistant form. In addition, due to the attrition resistance of the catalyst, the biomass and char are simultaneously ground into smaller particles as the hydropyrolysis reactions proceed within the hydropyrolysis reactor.
  • char is produced.
  • Char is the solid biomass residue remaining after the hydropyrolysis reaction.
  • the char is preferably entrained with the gaseous products and carried out of the reactor.
  • the physical characteristics of the char determine whether it will be entrained with the gaseous products. Specifically, if the settling velocity of the char is less than the exit bed velocity then the char will be entrained with the gaseous products and carried out of the reactor.
  • the char will not necessarily be uniform as its characteristics are determined by the type of biomass, the biomass pretreatment steps, and the hydropyrolysis reaction conditions. Further, the char may be reduced in size by the vigorous mixing in the fluidized bed.
  • the settling velocity of the char may be any velocity less than the exit bed velocity, preferably less than 90% of the exit bed velocity, more preferably less than is understood that the individual char particles formed in the reactor may have an initial settling velocity greater than the exit bed velocity, but that over time, the settling velocity of the char particles may be reduced by contact with the catalyst and other char particles until the settling velocity of the char particles is less than the exit bed velocity.
  • the settling velocity of the catalyst after it has been in the fluidized bed reactor will decrease over time as the catalyst attrits due to the vigorous mixing in the fluidized bed. As the average settling velocity of the catalyst particles decreases, it will reach a point where the settling velocity of the atlingered catalyst or the small catalyst particles that are broken off of the catalyst will be less than the exit bed velocity and the atlingered catalyst or small catalyst particles will be entrained and carried over with the gaseous products.
  • a suitable catalyst is preferably attrition resistant so this process of attrition of the catalyst will happen very slowly.
  • the gaseous products will contain solid particles, such as char and catalyst particles which are entrained with the gaseous products. These solid particles must be removed from the gaseous products before the gaseous products are further processed, and it is preferred for the char to be separated from the catalyst particles. This separation can be carried out by any suitable method including filters, cyclones, or other centrifugal or centripetal separators.
  • the gaseous products are passed through a cyclone to remove the char and then through a filter to remove the catalyst fines.
  • Char may be removed by cyclone from the gaseous products stream or by way of coarse filtering. If the char is separated by hot gas filtration, then the dust cake caught on the filters will have to be periodically removed. It will be easier to remove because the hydrogen produced in the hydropyrolysis reaction will have stabilized the free radicals and saturated the olefins produced in the reaction. In conventional fast pyrolysis, the removal of this dust cake is much more difficult because the char tends to coat the filter and react with oxygenated pyrolysis vapors to form viscous coatings.
  • a cyclone is first used to collect char fines from the process vapors leaving the fluidized bed, and a porous filter is then used to collect catalyst particles (which have a greater particle density, but a much smaller diameter than the char).
  • a porous filter is then used to collect catalyst particles (which have a greater particle density, but a much smaller diameter than the char).
  • two porous filters may be used in parallel, so that one may be cleaned via backpulsing while the other is online.
  • Electrostatic precipitation or a virtual impactor separator may also be used to remove char and ash particles from the hot gaseous products stream before cooling and condensation of the pyrolysis liquid.
  • the char may be removed by bubbling the gaseous products stream through a recirculating liquid that is preferably the high boiling point portion of the finished oil from the process. Char and catalyst fines may be captured in this liquid, which can then be filtered to remove the char and catalyst particles and/or recirculated to the hydropyrolysis reactor.
  • NiMo or CoMo catalysts deployed in an ebullated bed, are used for char removal and to provide further deoxygenation simultaneous with the removal of fine particulates.
  • These catalyst particles are large, preferably from 1/8 to 1/16 inch in size so they are easily separable from the fine char carried over from the hydropyrolysis reaction.
  • the partially deoxygenated pyrolysis liquid, together with hydrogen, carbon monoxide, carbon dioxide, water and light hydrocarbon gases (C1-C4) from the hydropyrolysis reaction may be fed to a hydroconversion reactor or another type of reaction zone that is used to further process the pyrolysis liquid.
  • the hydroconversion reactor is operated at a lower temperature than the hydropyrolysis reaction, in the range of from about 315 °C to about 425 °C and at about the same pressure.
  • the liquid hourly space velocity of this step is in the range of from about 0.3 to about 2.0.
  • the catalyst used in this reactor should be protected from catalyst poisons, such as sodium, potassium, calcium, phosphorous and other metals that may be present in the biomass.
  • the catalyst will be protected from olefins and free radicals by the catalytic upgrading carried out in the hydropyrolysis reactor.
  • Catalysts typically selected for this step are high activity hydroconversion catalysts, for example, sulfided NiMo and sulfided CoMo catalysts.
  • the catalyst is used to catalyze a water-gas shift reaction of CO + H 2 0 to make C0 2 + H 2 , thereby enabling in-situ production of hydrogen in the
  • the gases exiting the hydroconversion step are mainly carbon monoxide, carbon dioxide, methane, ethane, propane, and butanes that can be sent to an optional steam reformer together with water to form hydrogen to be used in the process. A portion of these gases may also be burned to produce heat needed for the steam reformer step.
  • a hydropyrolysis reaction system 100 comprises a
  • hydropyrolysis reactor 110 that contains a bed of fluidized catalyst.
  • Biomass is fed into the reactor through biomass feed line 120 and hydrogen is fed into the reactor by hydrogen feed line 122.
  • the hydrogen and biomass react in the presence of the catalyst and the products, including pyrolysis liquids, light gases, carbon monoxide and char are carried out of the reactor via product line 124.
  • the products are passed through a cyclone 130 where the char is separated out via line 126 and the products are removed via line 128.
  • Other embodiments include the use of a filter and/or other means for separating the solids from the product. Small catalyst particles may also be carried out of the reactor via line 124 and these would be separated from the products, either with the char or separately.
  • a hydropyrolysis reactor 210 contains a fluidized bed of hydropyrolysis catalyst 230.
  • the biomass is fed through line 220 and the hydrogen is fed through line 222.
  • the arrows 240 depict the exit bed velocity of the gases leaving the top of the catalyst bed.
  • the particles 232 are either solid char particles or small catalyst particles that are entrained with the gaseous product stream that is removed via line 224.
  • a hydropyrolysis reactor was operated under conditions consistent with those described above, in order to demonstrate removal of biomass char and attrited catalyst particles from a catalyst bed via entrainment.
  • the hydropyrolysis reactor consisted of a tubular vessel, with an interior diameter of 1.28 inches.
  • a catalyst bed was disposed within the reactor.
  • Hydrogen at a temperature of approximately 371 °C, was fed into the bottom of the bed of catalyst in order to fluidize it.
  • the catalyst particles Prior to loading, the catalyst particles were sieved, so that each particle was small enough to pass through a sieve with a screen opening of 500 microns, but large enough to be retained on a sieve with a screen opening of 300 microns.
  • the reactor was operated at 2.41 MPa and thermocouples, disposed within the fluidized bed, indicated that the average temperature of the bed was approximately 404 °C. This bed temperature was maintained and controlled by electric heaters. The flow rate of hydrogen into the bottom of the bed was such that the exit velocity of vapors leaving the bed (exit bed velocity) was 0.13 meter/second.
  • a heated filter assembly was disposed downstream of the fluidized-bed hydropyrolysis reactor, and was used to trap any particles, consisting of either char or attrited catalyst, that left the fluidized bed during the experiment. The filter was maintained at a temperature high enough to prevent any of the vapors from condensing to form liquids in the filter assembly.
  • the reactor was then fed a feedstock consisting of powdered hardwood.
  • the feedstock had a maximum particle size small enough to pass through a screen with an opening of 250 microns.
  • the feedstock was effectively cooled and transported in such a manner that individual feedstock particles could not interact with each other, and could not heat up significantly, during transport into the fluidized bed.
  • Once the feedstock particles arrived in the bed they were heated very rapidly to the temperature of the bed, via interaction with hot hydrogen, process vapors and catalyst particles present in the bed. Each feedstock particle was rapidly devolatilized, and the resulting vapors then had the opportunity to react with hydrogen present in the reactor. These reactions were facilitated by the presence of the catalyst particles.
  • the system was operated over a period of three days. 2100 grams of feedstock were loaded into the system the first day; 2100 grams of feedstock were again loaded into the system on the second day, and 1800 grams of feedstock were loaded into the system on the third day. After the system was shut down, 15 grams of unprocessed feedstock were recovered. Thus, 5985 grams of feedstock were processed in the hydropyrolysis reactor.
  • the process vapors from the hydropyrolysis reactor were sent on to a second-stage reactor after they passed through the filter assembly.
  • the process vapors were contacted with a fixed bed of catalyst, and further
  • the bulk density of the catalyst in the fluidized bed was found to be 0.9 g/cc. This difference in the bulk densities of the char and the catalyst particles was partly responsible for the effective separation of the char from the bed, since particles of the lower-density char could be readily carried out of the bed, while particles of higher-density catalyst were retained.

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BR112014011536B1 (pt) 2020-02-18
CA2855791A1 (en) 2013-05-23
ZA201402620B (en) 2015-10-28
AR088849A1 (es) 2014-07-10
US20150133704A1 (en) 2015-05-14
CN103930524B (zh) 2016-12-07
CA2855791C (en) 2020-09-22
EP2751224A4 (en) 2015-10-14
BR112014011536A2 (pt) 2017-05-02
US20170198222A1 (en) 2017-07-13
US9657232B2 (en) 2017-05-23
NZ624595A (en) 2016-11-25
CN103930524A (zh) 2014-07-16

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