[go: up one dir, main page]

US20130289324A1 - Production of aromatics from renewable resources - Google Patents

Production of aromatics from renewable resources Download PDF

Info

Publication number
US20130289324A1
US20130289324A1 US13/996,425 US201113996425A US2013289324A1 US 20130289324 A1 US20130289324 A1 US 20130289324A1 US 201113996425 A US201113996425 A US 201113996425A US 2013289324 A1 US2013289324 A1 US 2013289324A1
Authority
US
United States
Prior art keywords
catalyst
oil
gallium
feedstock
algae
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.)
Abandoned
Application number
US13/996,425
Other languages
English (en)
Inventor
Geoffrey L. Price
Brian L. Goodall
Daniel J. Sajkowski
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.)
University of Tulsa
Sapphire Energy Inc
Original Assignee
Individual
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 Individual filed Critical Individual
Priority to US13/996,425 priority Critical patent/US20130289324A1/en
Assigned to UNIVERSITY OF TULSA reassignment UNIVERSITY OF TULSA ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: PRICE, GEOFFREY L
Assigned to SAPPHIRE ENERGY, INC. reassignment SAPPHIRE ENERGY, INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: GOODALL, BRIAN L, SAJKOWSKI, DANIEL J
Assigned to SAPPHIRE ENERGY, INC. reassignment SAPPHIRE ENERGY, INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: GOODALL, BRIAN L, SAJKOWSKI, DANIEL J
Assigned to UNIVERSITY OF TULSA reassignment UNIVERSITY OF TULSA ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: PRICE, GEOFFREY L
Publication of US20130289324A1 publication Critical patent/US20130289324A1/en
Abandoned legal-status Critical Current

Links

Images

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
    • C10G3/00—Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids
    • C10G3/42—Catalytic treatment
    • C10G3/44—Catalytic treatment characterised by the catalyst used
    • C10G3/48—Catalytic treatment characterised by the catalyst used further characterised by the catalyst support
    • C10G3/49—Catalytic treatment characterised by the catalyst used further characterised by the catalyst support containing crystalline aluminosilicates, e.g. molecular sieves
    • 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
    • B01J29/00—Catalysts comprising molecular sieves
    • B01J29/04—Catalysts comprising molecular sieves having base-exchange properties, e.g. crystalline zeolites
    • B01J29/06—Crystalline aluminosilicate zeolites; Isomorphous compounds thereof
    • B01J29/08—Crystalline aluminosilicate zeolites; Isomorphous compounds thereof of the faujasite type, e.g. type X or Y
    • B01J29/084—Y-type faujasite
    • 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
    • B01J29/00—Catalysts comprising molecular sieves
    • B01J29/04—Catalysts comprising molecular sieves having base-exchange properties, e.g. crystalline zeolites
    • B01J29/06—Crystalline aluminosilicate zeolites; Isomorphous compounds thereof
    • B01J29/40—Crystalline aluminosilicate zeolites; Isomorphous compounds thereof of the pentasil type, e.g. types ZSM-5, ZSM-8 or ZSM-11, as exemplified by patent documents US3702886, GB1334243 and US3709979, respectively
    • B01J29/405—Crystalline aluminosilicate zeolites; Isomorphous compounds thereof of the pentasil type, e.g. types ZSM-5, ZSM-8 or ZSM-11, as exemplified by patent documents US3702886, GB1334243 and US3709979, respectively containing rare earth elements, titanium, zirconium, hafnium, zinc, cadmium, mercury, gallium, indium, thallium, tin or lead
    • 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
    • B01J37/00—Processes, in general, for preparing catalysts; Processes, in general, for activation of catalysts
    • B01J37/02—Impregnation, coating or precipitation
    • B01J37/0201—Impregnation
    • 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
    • C10G3/00—Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids
    • C10G3/42—Catalytic treatment
    • 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
    • C10G3/00—Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids
    • C10G3/42—Catalytic treatment
    • C10G3/44—Catalytic treatment characterised by the catalyst used
    • 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
    • C10G3/00—Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids
    • C10G3/54—Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids characterised by the catalytic bed
    • 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
    • C10G3/00—Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids
    • C10G3/54—Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids characterised by the catalytic bed
    • C10G3/55—Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids characterised by the catalytic bed with moving solid particles, e.g. moving beds
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • 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
    • C10L1/04—Liquid carbonaceous fuels essentially based on blends of hydrocarbons
    • C10L1/06—Liquid carbonaceous fuels essentially based on blends of hydrocarbons for spark ignition
    • 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
    • B01J29/00—Catalysts comprising molecular sieves
    • B01J29/04—Catalysts comprising molecular sieves having base-exchange properties, e.g. crystalline zeolites
    • B01J29/06—Crystalline aluminosilicate zeolites; Isomorphous compounds thereof
    • B01J2029/062—Mixtures of different aluminosilicates
    • 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
    • B01J29/00—Catalysts comprising molecular sieves
    • B01J29/04—Catalysts comprising molecular sieves having base-exchange properties, e.g. crystalline zeolites
    • B01J29/046—Chromiasilicates; Aluminochromosilicates
    • 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
    • B01J29/00—Catalysts comprising molecular sieves
    • B01J29/04—Catalysts comprising molecular sieves having base-exchange properties, e.g. crystalline zeolites
    • B01J29/06—Crystalline aluminosilicate zeolites; Isomorphous compounds thereof
    • B01J29/08—Crystalline aluminosilicate zeolites; Isomorphous compounds thereof of the faujasite type, e.g. type X or Y
    • B01J29/085—Crystalline aluminosilicate zeolites; Isomorphous compounds thereof of the faujasite type, e.g. type X or Y containing rare earth elements, titanium, zirconium, hafnium, zinc, cadmium, mercury, gallium, indium, thallium, tin or lead
    • 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
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1011—Biomass
    • C10G2300/1014—Biomass of vegetal origin
    • 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
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1037—Hydrocarbon fractions
    • C10G2300/104—Light gasoline having a boiling range of about 20 - 100 °C
    • 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
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1037—Hydrocarbon fractions
    • C10G2300/1044—Heavy gasoline or naphtha having a boiling range of about 100 - 180 °C
    • 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
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1037—Hydrocarbon fractions
    • C10G2300/1048—Middle distillates
    • C10G2300/1051—Kerosene having a boiling range of about 180 - 230 °C
    • 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
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1037—Hydrocarbon fractions
    • C10G2300/1048—Middle distillates
    • C10G2300/1055—Diesel having a boiling range of about 230 - 330 °C
    • 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
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/40—Characteristics of the process deviating from typical ways of processing
    • C10G2300/4025—Yield
    • 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
    • C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
    • C10G2400/02—Gasoline
    • 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
    • C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
    • C10G2400/30—Aromatics
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • 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

  • This invention relates generally to a method for the production of aromatics from renewable sources. More specifically, the preferred embodiments related to converting fat- or other lipid-containing oils derived from biomass, such as oil from naturally-occurring non-vascular photosynthetic organisms and/or from genetically modified non-vascular photosynthetic organisms; canola oil and other oils derived from vegetables such as corn, soybean, sunflower, and sorghum; and/or oils from other plant matter, seeds, fungi, bacteria, and other organisms both living and recently living.
  • biomass such as oil from naturally-occurring non-vascular photosynthetic organisms and/or from genetically modified non-vascular photosynthetic organisms
  • canola oil and other oils derived from vegetables such as corn, soybean, sunflower, and sorghum
  • oils from other plant matter, seeds, fungi, bacteria, and other organisms both living and recently living such as corn, soybean, sunflower, and sorghum
  • Aromatics particularly benzene, toluene, ethylbenzene, and the xylenes (ortho, meta, and para isomers), which are commonly referred to as “BTEX” or more simply “BTX,” are extremely useful chemicals in the petrochemical industry. They represent the building blocks for materials such as polystyrene, styrene-butadiene rubber, polyethylene terephthalate, polyester, phthalic anhydride, solvents, polyurethane, benzoic acid, and numerous other components. Conventionally, BTEX is obtained for the petrochemical industry by separation and processing of fossil-fuel petroleum fractions, for example, in catalytic reforming or cracking refinery process units, followed by BTX recovery units.
  • the patent literature describes refinery schemes proposed for processing biomass to produce transportation fuels, such as gasoline, jet, and diesel. See, for example, North Carolina State University, WO 2008/103204, published 28 Aug. 2008, and entitled “Process for Convention of Biomass to Fuel”. See also, Aravanis, et al., Publication US2009/0126260, published 21 May 2009, entitled “Methods of Refining Hydrocarbon feedstocks”, and McCall, et al., Publication US2009/0158637, published 25 Jun. 2009, and entitled “Production of Aviation Fuel from Biorenewable Feedstocks”. The patent literature focuses, however, on transportation fuel production from renewable feedstocks, rather than aromatics production for the petrochemical industry.
  • the patent literature focuses on renewable feedstocks that are comprised mainly of triglycerides, for example, plant oils such as canola, soy bean, camelina and jatropha oils, and animal fats such as beef and lamb tallow and chicken fat, which are approximately 100% triglycerides.
  • plant oils such as canola, soy bean, camelina and jatropha oils
  • animal fats such as beef and lamb tallow and chicken fat, which are approximately 100% triglycerides.
  • the invention comprises methods, catalyst, and/or equipment for converting one or more renewable oils to aromatics, for example, for use in the petrochemical industry and/or for blending components or additives for fuels.
  • the invented processing methods comprise contacting one or more renewable oils with a catalytically-active form of gallium, for example, a catalyst comprising a catalytically-active form of gallium (also called “gallium-modified” catalyst herein).
  • a catalytically-active form of gallium also called “gallium-modified” catalyst herein.
  • Such gallium-modified catalyst may comprise a zeolite or other solid that retains gallium in a catalytically-active form, for example, as gallium cations.
  • the invention may comprise products made by said methods.
  • Said one or more renewable oils may be obtained from biomass, which is defined as a mass, or a material including a substantial amount of said mass, that is alive or that has been alive within the last 50 years.
  • biomass which is defined as a mass, or a material including a substantial amount of said mass, that is alive or that has been alive within the last 50 years.
  • examples of such renewable oils are canola oil and other lipids-based bio-oils derived from vegetables such as corn, soybean, sunflower, and sorghum; oil from naturally-occurring non-vascular photosynthetic organisms and/or from genetically modified non-vascular photosynthetic organisms, and/or oil from other plant matter, seeds, fungi, bacteria, and other organisms.
  • the bio-oils may be extracted from their respective biomass by conventional techniques.
  • the term non-vascular photosynthetic organism includes, but is not limited to, macroalgae, microalgae and cyanobacteria (blue-green algae).
  • said one or more renewable oils feature a H/C mole ratio of greater than 1.5 (typically 1.7-2.1), and oxygen content of about 1 to about 35 wt-% (typically 5-15 wt %).
  • the renewable oil(s) comprise large amounts of fatty acids or fatty acid esters, including free fatty acids and/or glycerol esters of fatty acids such as monoglycerides, diglycerides, and/or triglycerides.
  • the H/C mole ratio, oxygen content, and relative amounts of free fatty acids and glycerol esters in said one or more renewable oils may depend on the source of the renewable oil and/or on the techniques of extraction from the biomass and/or pre-processing prior to contact with the gallium-modified catalyst, for example.
  • the fatty acid moieties may range, for example, from about 4 to about 30 carbon atoms, but typically 10 to 25 carbon atoms, and even more typically, 16 to 22 carbon atoms. Most commonly, the fatty acid moieties are saturated or contain 1, 2 or 3 double bonds.
  • the renewable oil(s) contain at least some triglycerides that are glycerol esters of C16-C22 carboxylic acids and therefore may comprise C50+ compounds, however, many of the diglycerides and/or triglycerides in the renewable oil(s) decompose to their C-16-C-22 components upon heating to elevated temperature.
  • the renewable oil(s) may also comprise other materials such as carotenoids, hydrocarbons, phosphatides, simple fatty acids and their esters, terpenes, sterols, fatty alcohols, tocopherols, polyisoprene, carbohydrates and/or proteins.
  • some embodiments of the invention are expected to produce large amounts of hydrogen, and this hydrogen may be fed to hydrogen-consuming units in the refinery, for example, a hydrotreater or hydrocracker.
  • some embodiments of the invention may be used both for “green” BTEX production and for “green” hydrogen production.
  • the gallium-retaining solid is a shape-selective material, and more typically, the solid is a zeolitic material wherein at least some of the cation-exchange centers are populated with gallium.
  • the gallium-retaining solid(s) is/are gallium-doped version(s) of one or more zeolite-alumina matrix catalysts with pore sizes having 10 oxygen atoms in the pore mouth, for example, ZSM-5, ZSM-11, ZSM-23, MCM-70, SSZ-44, SSZ-58, SSZ-35, and ZSM-22.
  • the inventors have discovered that aromatics-production from the renewable oils is enhanced at higher gallium levels, with one level being Ga occupying at least 90% of the cation sites and the protons or other cations previously at those cation sites having been replaced by Ga.
  • An exemplary gallium level is 90-100% of the cation sites being replaced by Ga, which is called “1.0 Ga/framework-Al” herein.
  • Catalysts in certain embodiments of the invention may have gallium loadings above 1.0 Ga/framework-Al, that is, gallium present in an amount above that equal to 100% cation replacement.
  • extraframework Ga would exist, that is, Ga over and above the amount corresponding to 1 Ga/framework-Al and residing in zeolitic pores or on the exterior of the zeolite crystalline particles.
  • zeolite frameworks may contain other metals, for example, gallium, boron, iron, phosphorous, germanium, indium, etc. Zeolite frameworks containing other metals may be suitable for producing gallium-modified catalyst, for example, for loading with gallium in cationic form for use as catalysts in certain embodiments of the invention.
  • the solid may be adapted to retain gallium by processes known to those of skill in the catalyst arts, for example, incipient wetness impregnation of zeolite with a gallium-composition dissolved in water.
  • Methods for producing gallium-doped catalyst are also described in U.S. Pat. Nos. 4,727,206, 4,746,763, 4,761,511, and 5,149,679, the teachings of which are incorporated herein by this reference.
  • Said one or more renewable oils may comprise “whole crude oil”, that is, the entire oil extract from biomass, and/or one or more fractions of said whole crude oil.
  • Said one or more renewable oils may comprise whole crude oil(s)/fraction(s) that have been pre-processed before being fed to the gallium-catalyst process.
  • pre-processing in this context may include degumming, RBD (Refining, Bleaching, and Deodorizing, which is known in the art), thermal processing, hydrotreating, and/or other processes that deoxygenate or otherwise upgrade the renewable oil to some extent before being fed to the process comprising use of gallium-modified catalyst.
  • said one or more renewable oils may be co-processed (“co-fed”) with other oils, such as fossil petroleum oils/fractions, to the aromatics-production processes of this invention.
  • said existing, revamped, or new units for certain embodiments of the invention may include those that are the same or similar to fluidized catalytic cracking (FCC) units (for example, see FIG. 23 ), UOP CCRTM CyclarTM units (for example, see FIG. 24 ), a UOP CCR PlatformerTM naphtha reformer fixed-bed reactor(s), or other fixed-bed reactor units, all of which originated as fossil petroleum technology.
  • FCC units fluidized catalytic cracking
  • UOP CCRTM CyclarTM units for example, see FIG. 24
  • UOP CCR PlatformerTM naphtha reformer fixed-bed reactor(s) or other fixed-bed reactor units, all of which originated as fossil petroleum technology.
  • Said FCC units have been designed for gasoline component production from petroleum, including those FCC units that minimize benzene production relative to higher octane components in order to maximize octane.
  • Said UOP CCRTM CyclarTM units are moving-catalyst, continuous-catalyst-regeneration units designed for aromatics production from petroleum C3 and C4 feeds using gallium catalysts.
  • Said UOP CCRTM PlatformerTM units are moving-catalyst, continuous-catalyst-regeneration units designed for high-octane gasoline production from petroleum naphtha, and typically use platinum catalysts to produce aromatics-rich liquid product.
  • Said fixed-bed reactor units are also well known in the refinery arts, for example, “semi-regen” reformers that are designed for gasoline component production from petroleum naphtha, and typically use platinum or rhenium catalysts to produce aromatics-rich liquid product.
  • Feeding high percentages of renewable oils to process units based on fossil petroleum technology may require adaptation of equipment and operation upstream of the reactor(s)/riser(s) reaction zone, as none of the above-mentioned fossil petroleum units are designed specifically for said renewable oil feedstocks.
  • the equipment and operation downstream of the reaction zone in these units are more likely to effectively handle product streams from a high-percentage renewable oil(s) operation, due to the BTEX product from such embodiments being generally similar to the aromatics-rich products of the above-mentioned units.
  • modifications may be required in the equipment or operations downstream of the reaction zone to handle H2O, CO, and/or CO resulting from the high oxygen content of certain renewable oils.
  • pre-processing for deoxygenation of renewable oils, prior to being fed to said reaction zone may prevent excessive water production and hydrogen consumption in said reaction zone.
  • Feeding low-percentages of renewable oils to process units based on fossil petroleum technology may be a desirable option, especially because said one or more renewable oils are expected to be available only in relatively small quantities in the next few years. Therefore, co-processing of said one or more renewable oils with other feedstocks may be required and/or beneficial, resulting in process units that are “fed-in-part” with said one or more renewable oils, and “loaded-in-part” with gallium-modified catalyst. While “fed in full” means herein that about 100 wt % (for example, 99-100 wt %) of the feedstock for a process unit would be said one or more renewable oils, the term “fed-in-part” means herein that a lesser percentage of the feedstock would be said one or more renewable oils.
  • loaded-in-full means herein that about 100 wt % (for example, 99-100 wt %) of the catalyst for a process unit would be gallium-modified catalyst (for example, gallium-cation catalyst), the term “loaded-in-part” means that a lesser percentage would be gallium-modified catalyst.
  • Optimum operating conditions, including conditions of feedstock contact with catalyst, for such loaded-in-part and fed-in-part operations may be different from those suggested by the loaded-in-full and fed-in-full Examples later in this document.
  • higher temperatures for higher space velocities or fluidized bed or moving bed conditions may be needed.
  • optimum feedstock-catalyst-contact temperature may be as high as 600° C., but more typically may be in the 450-550° C. range, for example.
  • those of skill in the art may optimize the conditions of such loaded-in-part and fed-in-part operations without undue experimentation.
  • said one or more renewable oil(s) may be pre-processed prior to being fed or co-fed to a unit containing at least some gallium-modified catalyst.
  • pre-processing steps may comprise thermal-treatment and/or hydrotreatment of the renewable oil(s) or fractions thereof.
  • a processing scheme comprising hydrotreatment, or thermal-treatment followed by hydrotreatment, of algae oil, is expected to produce a desirable feed or co-feed for an FCC unit.
  • a processing scheme comprising thermal-treatment of a portion of algae oil, for example, a heavy fraction of algae oil, followed by hydrotreatment of both the thermally-treated and non-thermally-treated fractions of the renewable oil, may also produce a desirable feed or co-feed for an FCC unit.
  • Embodiments of the invention are not necessarily limited to the above-mentioned units or co-processing options.
  • Other processing units, flowschemes and/or other co-feedstocks may provide synergistic or beneficial results.
  • FIG. 1A is a schematic of the laboratory reactor system, using a single reactor, used in the experiments of Examples I, III, and IV,
  • FIG. 1B is a schematic of the laboratory reactor system, used in the experiments of Example II, that includes two reactors in series and is adapted for liquid product removal between reactors.
  • FIG. 2 is a graph of weight-percent yield of liquid products (triangles) and vapor products (squares) from Runs SAP275-279 on HZSM-5 catalyst (no gallium) in Example I, showing that increasing temperature decreases the yield of liquid products while increasing the amount of vapor products.
  • FIG. 3 is a graph of vapor product yields changing with increasing amounts of gallium (left to right) added to the catalyst for experiments SAP281-283 in Example I, showing particularly that propane and ethane changed with increasing gallium. Molecules shown in this graph represent ⁇ 98% of all vapor products from each experiment. Results for 0.0 Ga are the mean of SAP284-287 and the “error bars” show the 95% confidence interval.
  • FIG. 4 is a graph of yields of liquid product (triangles), vapor product (squares), and coke on catalyst (circles) vs. increasing gallium-loading of the catalyst in experiments SAP281-283 of Example I. With increasing gallium content, liquid yield (triangles) increased, coke (circles) stayed almost constant, and vapor products (squares) decreased. The mean of SAP284-287 (no Ga) is used in this graph for zero gallium content.
  • FIG. 5 is a graph of boiling point distribution of the organic phase products, for the various gallium loadings (increasing left to right) in Example I. The majority of the products fall in the 60-188° C. range.
  • FIG. 6 is a graph of benzene, toluene, ethyl-benzene, xylene, and total BTEX yields, in Example I, showing that BTEX yield increases with the gallium content of the ZSM-5 catalyst.
  • FIG. 7 is a graph of vapor product yields obtained from algae oil cracking at 400° C., over GaZSM-5 (bars on left) and HZSM-5 catalyst (bars on right) in Example III.
  • FIG. 8 is a graph of yields of individual BTEX components, total BTEX, and gasoline obtained from algae oil cracking over catalysts at 400° C., over GaZSM-5 catalyst (bars on left) and HZSM-5 catalyst (bars on right) in Example III.
  • FIG. 9 is a graph of gas phase products produced during cracking of gas oil in Example IV.
  • FIG. 10 is a graph of the BTEX and gasoline yield results from cracking of gas oil (Example IV) compared to BTEX and gasoline yield results from cracking of algae oil (Example III), both at 400 degrees C.
  • FIG. 11 is a graph of the simulated distillation curve of the Conoco Phillips gas oil of Example IV compared to the simulated distillation curve of algae oil of Example III, with a maximum gasoline boiling point line included for reference.
  • FIG. 12 is a graph of the simulated distillations for the gas oil product (Example IV), algae oil product (Example III) and canola oil product (Example I) for the respective cracking experiments.
  • FIG. 13 is a graph of conversion % vs. catalyst/oil ratio for the algae oil feed and vacuum gas oil samples of Example V.
  • FIG. 14 is a graph of coke wt % vs. conversion ratio for the algae oil feed and vacuum gas oil samples of Example V.
  • FIG. 15 is a graph of conversion % vs. catalyst/oil ratio for algae oil feed, hydrotreated algae oils, and vacuum gas oil, in Example VI. Note that this graph comprises the hydrotreated algae oil data added to the algae oil feed and vacuum gas oil data of FIG. 13 .
  • FIG. 16 is a graph of coke wt % vs. conversion for algae oil feed, hydrotreated algae oils, and vacuum gas oil, in Example VI. Note that this graph comprises the hydrotreated algae oil data added to the algae oil feed and vacuum gas oil data of FIG. 14 .
  • FIGS. 17-22 are graphs of the wt % yields of gasoline, LCO, DCO, TC2, TC3, and TC4, respectively, versus conversion %, for the algae oil feed, hydrotreated algae oils, and vacuum gas oil of Example VI.
  • FIG. 23 is a schematic illustration of one example of a conventional fluidized catalyst conversion unit (FCC), which may be adapted to operate in certain embodiments of the invention.
  • FCC fluidized catalyst conversion unit
  • FIG. 24 is a schematic illustration of one example of a conventional UOP CCRTM CyclarTM unit, which may be adapted to operate in certain embodiments of the invention.
  • Examples I-VII are roughly predictive of what would happen in commercial units.
  • the data in Examples I-III would be roughly predictive of an operation having packed bed gallium-cation catalyst loaded-in-full, renewable oil(s) fed-in-full (including canola oil and algae oil), the feed-catalyst contact at about 1.0 WHSV (weight hourly space velocity), and the temperature controlled in the range of 350-450 degrees C., for example, 400 degrees C.
  • the data in Example IV would be roughly predictive of a fossil petroleum gas oil feed processed over the selected gallium-modified catalyst and conditions from Example I and III, and, hence, that Example IV may be used to predict performance differences between the renewable oils and the gas oil.
  • Example V and VI would be roughly predictive of FCC processing of algae oil and hydrotreated algae oil, respectively.
  • the data in Example VII would be roughly predictive of thermal treatment of certain algae oils, as a pre-processing step prior to subsequent upgrading by hydrotreating and fluid catalytic cracking with gallium-modified catalyst.
  • Example IV The experimental data of Examples I-III support certain embodiments wherein renewable oil are processed effectively over gallium-modified catalyst while achieving very beneficial results in aromatics and hydrogen production, wherein optionally gas oil may also be effectively processed over the same gallium-modified catalyst (Example IV).
  • the combination of the gallium-cation catalyst data in Examples I-IV and the FCC data in Examples V and VI supports certain embodiments of the invention wherein algae oils are upgraded by a pre-processing step of hydrotreating, followed by fluid catalytic cracking (optionally with petroleum as a co-feed), wherein the FCC catalyst comprises supplemental gallium-cation catalyst to further enhance aromatics production from the algae oil in said fluid catalytic cracking.
  • Example VII supports certain embodiments of the invention wherein algae oils are upgraded by pre-processing steps of thermal treatment and hydrotreating, followed by FCC fluid catalytic cracking (optionally with petroleum as a co-feed), wherein the FCC catalyst comprises supplemental gallium-cation catalyst to further enhance aromatics production from the algae oil in said fluid catalytic cracking.
  • one or more renewable oils will be co-fed (or “fed-in-part”) with other oils wherein the combined feed contacts a gallium-modified catalyst.
  • the broad scope of the invention may comprise processing any amount of any renewable oil, including those obtained from biomass by solvent extraction, by the HTT techniques above, or other biomass treatment/extraction techniques and fractions thereof, in a operation with gallium-modified catalyst, with the renewable oil being any percentage of the total feedstock.
  • one or more renewable oils may constitute as little as about 1 wt % of the feedstock to a unit containing the gallium-cation-retaining catalyst, but due to the large BTEX benefit exhibited by the catalyst with renewable oil(s), the inventors anticipate that the renewable oil(s) will eventually constitute a major portion of the total feedstock of selected process units; for example, at least 5 wt %, at least 10 wt %, at least 50 wt-%, or at least 80 or 90 wt-% of the total feedstock to the process unit will be said one or more renewable oil in certain embodiments.
  • the renewable oil will be in the range of 5-100 wt %, 10-100 wt %, 50-100 wt-% of the feedstock, 80-100 wt % or 90-100 wt % of the feedstock to one or more selected units.
  • components for blending with said one or more renewable oils prior to processing over gallium-modified catalyst may be selected from the group consisting of: fossil fuel, petroleum, C3-C4, naphtha, gasoline, jet fuel, diesel, gas oil, heavy gas oil, and any combination thereof.
  • renewable oil(s) may be co-processed with gas oil/vacuum gas oil, for example.
  • C3-C4 co-processed with C3-C4, for example.
  • Certain of the feed-co-processing embodiments also comprise the gallium-modified catalyst being loaded/charged with other catalysts into the unit (a “loaded-in-part” operation), for example, with non-gallium-containing catalysts.
  • the gallium-modified catalyst may constitute any percentage of the catalyst load/stream.
  • the gallium-modified catalyst may constitute as little as about 1 wt % of the catalyst in the process unit, but, due to the large BTEX benefit exhibited by the catalyst with renewable oil(s), the inventors anticipate that the catalyst will eventually constitute at least 5 wt %, at least 10 wt %, at least 50 wt %, at least 80 wt %, or at least 90 wt % of the total catalyst in the unit.
  • the gallium-modified catalyst will be in the range of 5-100 wt %, 10-100 wt %, 50-100 wt %, 80-100 wt %, or 90-100 wt % of the total catalyst.
  • gallium-modified catalyst herein and in the claims is broadly defined as any solid comprising a catalytically-active form of gallium, which may include but is not necessarily limited to gallium-cation catalyst, gallium-doped zeolites, and the other examples of gallium-modified catalysts in this document.
  • renewable oil(s) could be fed-in-part to the FCC unit, along with gas oils or other petroleum feedstocks.
  • only a portion of the total feedstock fed to the FCC process unit would be renewable oil(s), for example, less than 99 wt % and more likely 1-20 wt % or 5-10 wt % of the total feedstock.
  • gallium-cation catalyst would be an additive/supplement to the catalyst stream of the FCC units, which normally consists essentially of acidic zeolite FCC catalyst such as zeolite Y catalyst.
  • only a portion of the total catalyst loading/charge (stream) would be gallium-modified catalyst, for example, less than 99 wt % and more likely 1-20 wt % or 5-10 wt % of the total catalyst load/stream.
  • the FCC catalyst and gallium-cation catalyst would be regenerated together in the regenerator section of the FCC unit. Reaction temperature may be adjusted in such scenarios, to optimize overall performance based on the mix of catalyst and feeds in the unit, and would be expected to be in the range of about 400-555 degrees C, for example.
  • Catalyst supplementation or change-out would not necessarily be required in order to feed said one or more renewable oils to a UOP CyclarTM unit, as such units have typically used gallium-cation catalysts for conversion of C3 and C4 feedstock.
  • catalyst regeneration in a CyclarTM unit would be expected to be effective, as the CyclarTM CCRTM regeneration section is designed for gallium-cation catalysts that are similar to those of certain embodiments of the invention. Therefore, due to existing CyclarTM units being loaded with and adapted for gallium catalyst, it may be possible to feed renewable oil(s) in-full, or in-part along with C3 and C4 feeds or other feeds, to CyclarTM or similar units.
  • gallium-cation catalysts are not expected to require the relatively complex regeneration process required for the platinum reforming catalysts typically used in PlatformersTM and many other naphtha reformers. Certain gallium-cation catalysts may be regenerated by a coke burning step, followed by reduction during processing of oil over the catalyst, that is, at the temperature and in the environment in which the renewable oil is being processed over the catalyst.
  • an oxidation-only regeneration section such as in an FCC unit, or a simple batch oxidization, may be effective for regeneration of certain catalysts of the invention, rather than oxygenation followed by a special reduction process and equipment such as is used in a UOP CCR PlatformerTM.
  • a special reduction process and equipment such as is used in a UOP CCR PlatformerTM.
  • one of the series-flow reactors would be loaded with the gallium-cation catalyst, for example, with the other reactors being loaded with conventional reforming catalyst, and with adaptation for separate regeneration of the reactors and, hence, of the multiple types of catalyst.
  • the protonated form of the zeolite/alumina matrix catalyst used in Examples I-IV may be described as the simplest form of the zeolite/alumina matrix catalyst, wherein the cation-exchange centers in the zeolite are fully populated with protons. Each cation center is associated with an aluminum atom incorporated in the framework of the zeolite. Therefore, one may say that the proton to framework-Al ratio of the protonated form is 1/1, and the form is called “HZSM-5” (the “H” or more strictly “H + ” being a proton), wherein ZSM-5 stands for “Zeolite Socony Mobil-5” (structure type MFI—mordenite framework inverted).
  • the gallium-loaded forms of the zeolite/alumina matrix catalyst used in Examples I-IV were prepared with gallium levels that are cited as a fraction of the cation sites replaced by gallium.
  • Catalysts were prepared with Ga levels equivalent to 1.0 Ga/framework-Al, 0.33 Ga/framework-Al, and 0.10 Ga/framework-Al. In these materials, Ga replaced protons. Therefore, for 1.0 Ga/framework, almost all the cation sites were occupied by Ga and almost all the protons had been replaced by Ga. Therefore, the “1.0 Ga/framework-Al” catalyst may be described as having 90%-100% of cation sites occupied by Ga or 95-100% of cation sites occupied by Ga.
  • the term “0 Ga/framework-Al” is used, which means zero protons replaced by Ga and which may be equivalently be referred to as “HZSM-5” (or the “fully protonated form” of the catalyst).
  • Exemplary catalysts have gallium as cations, which compensate for the anionic framework of the zeolite. It may be noted that, many embodiments of the catalysts of this invention are not acidic-type zeolites comprising gallium instead of aluminum in the framework.
  • Gallium catalysts have been described for producing aromatics from short-chain fossil-fuel hydrocarbons, especially C2, C3, and C4.
  • U.S. Pat. No. 4,727,206 discloses gallium catalyst for feedstocks having methane as a major component, with ethane and C3-C6 optionally being included in the feedstock.
  • U.S. Pat. No. 4,746,763 discloses gallium catalyst for processing of C2-C6 aliphatic compounds.
  • U.S. Pat. No. 4,761,511 describes catalysts for aromatics production and suggests that C2-C12 paraffins may be used as feedstock, but the patent teaches that C2-C8 paraffins are the preferred feedstock, and that C2-C4 paraffins are the especially preferred feedstock.
  • gallium catalysts to aromatics production and/or hydrogen production from renewable oils, especially those with substantial C12+ compounds, substantial C16-C22 fatty acid/ester chains, and/or even substantial C50+ compounds. It is not obvious to apply such gallium catalysts to renewable oils that comprise biological compounds which contain oxygen, such as fatty acids, triglycerides, aldehydes, ketones, esters, and/or alcohols, etc. that occur in significant amounts in naturally-occurring plant oils.
  • gallium catalysts which have been designed for and applied to C2-C4 feedstocks, to BTEX production and/or hydrogen production from renewable oils, and, particularly, from canola oil or algae oil.
  • the renewable crude oils of this disclosure may be extracted by various means from biomass that has been alive within the last 50 years.
  • the canola oil used in the experiments of Examples I and II was commercially-available canola oil, which is a well-known oil obtained from rapeseed.
  • the renewable algae oils used in the experiments of Examples III-V were examples of the category of renewable oils that may be extracted by various means from of naturally-occurring non-vascular photosynthetic organisms and/or from genetically-modified non-vascular photosynthetic organisms. Genetically modified non-vascular photosynthetic organisms can be, for example, where the chloroplast and/or nuclear genome of an algae is transformed with a gene(s) of interest.
  • non-vascular photosynthetic organism includes, but is not limited to, algae, which may be macroalgae and/or microalgae.
  • microalgae includes, for example, microalgae (such as Nannochloropsis sp.), cyanobacteria (blue-green algae), diatoms, and dinoflagellates.
  • Crude algae oil may be obtained from said naturally-occurring or genetically-modified algae wherein growing conditions (for example, nutrient levels, light, or the salinity of the media) are controlled or altered to obtain a desired phenotype, or to obtain a certain lipid composition or lipid panel.
  • the biomass is substantially algae, for example, over 80 wt % algae, or over 90 wt % algae, or 95-100 wt % algae (dry weight).
  • Algae biomass of particular interest comprises photosynthetic algae grown in light.
  • Other embodiments, however, may comprise obtaining algae biomass or other “host organisms” that are grown in the absence of light.
  • the host organisms may be photosynthetic organisms grown in the dark or organisms that are genetically modified in such a way that the organisms' photosynthetic capability is diminished or destroyed.
  • a host organism is not capable of photosynthesis (e.g., because of the absence of light and/or genetic modification)
  • the organism will be provided with the necessary nutrients to support growth in the absence of photosynthesis.
  • a culture medium in (or on) which an organism is grown may be supplemented with any required nutrient, including an organic carbon source, nitrogen source, phosphorous source, vitamins, metals, lipids, nucleic acids, micronutrients, and/or an organism-specific requirement.
  • Organic carbon sources include any source of carbon which the host organism is able to metabolize including, but not limited to, acetate, simple carbohydrates (e.g., glucose, sucrose, and lactose), complex carbohydrates (e.g., starch and glycogen), proteins, and lipids. Not all organisms will be able to sufficiently metabolize a particular nutrient and that nutrient mixtures may need to be modified from one organism to another in order to provide the appropriate nutrient mix. One of skill in the art would know how to determine the appropriate nutrient mix.
  • algae from which suitable oil may be extracted are Chlamydomonas sp. for example Chlamydomonas reinhardtii., Dunaliella sp., Scenedesmus sp., Desmodesmus sp., Chlorella sp., and Nannochloropsis sp.
  • Chlamydomonas sp. for example Chlamydomonas reinhardtii., Dunaliella sp., Scenedesmus sp., Desmodesmus sp., Chlorella sp., and Nannochloropsis sp.
  • cyanobacteria from which suitable crude oil may be obtained include Synechococcus sp., Spirulina sp., Synechocystis sp.
  • Athrospira sp. Prochlorococcus sp., Chroococcus sp., Gleoecapsa sp., Aphanocapsa sp., Aphanothece sp., Merismopedia sp., Microcystis sp., Coelosphaerium sp., Prochlorothrix sp., Oscillatoria sp., Trichodesmium sp., Microcoleus sp., Chroococcidiopisis sp., Anabaena sp., Aphanizomenon sp., Cylindrospermopsis sp., Cylindrospermum sp., Tolypothrix sp., Leptolyngbya sp., Lyngbya sp., or Scytonema sp.
  • Algae production and extraction technology are known in the art, including genetically-modified algae growth and extraction, and certain embodiments of the invention comprise crude algae oil feedstocks/fractions from any growth and extraction techniques.
  • Algae may be harvested and dried and then the oil extracted from lysed or destroyed cells. The cells may be chemically lysed, or mechanical force can be used to destroy cell walls. Oil may be extracted from the lysed/destroyed cells using an organic solvent such as hexane.
  • the algae oil used in Example III was oil extracted from algae biomass using hexane, and then treated by a conventional RBD process, such as that known in the food arts for vegetable oils. The algae oil if Example III was not hydrotreated, reformed, or cracked prior to being processed in the zeolitic catalyst cracking processes.
  • Certain embodiments comprise crude algae oils that are obtained by techniques comprising steps other than or in addition to solvent extraction.
  • certain embodiments comprise hydrothermal treatment of the biomass prior to solvent extraction of the crude algae oil, for example, by heptanes, hexanes, and/or MIB, and then processing by embodiments of the invention without RBD treatment.
  • Certain algae oil feedstocks therefore, have not been subjected to any RBD processing (the refining, bleaching, and deodorizing process conventionally known and used for high-triglyceride bio-oils), nor subjected to any of the individual steps of refining, bleaching or deodorizing, after being extracted and before certain upgrading processes of the invention.
  • Certain embodiments of said hydrothermal treatment comprise an acidification step. Certain embodiments of the hydrothermal treatment comprise heating (for clarity, here, also called “heating to a first temperature”), cooling, and acidifying the biomass, followed by re-heating and solvent addition, separation of an organic phase and an aqueous phase, and removal of solvent from the organic phase to obtain an oleaginous composition.
  • a pretreatment step optionally may be added prior to the step of heating to the first temperature, wherein the pretreatment step may comprise heating the biomass (typically the biomass and water composition of step (a) below) to a pretreatment temperature (or pretreatment temperature range) that is lower than said first temperature, and holding at about the pretreatment temperature range for a period of time.
  • the first temperature will typically be in a range of between about 250 degrees C. and about 360 degrees, as illustrated by step (b) listed below, and the pretreatment temperature will typically be in the range of between about 80 degrees C. and about 220 degrees C.
  • the holding time at the pretreatment temperature range may be between about 5 minutes and about 60 minutes.
  • acid may be added during the pretreatment step, for example, to reach a biomass-water composition pH in the range of about 3 to about 6. It should be noted that the hydrothermal-treatment and solvent-extraction methods may be conducted as a batch, continuous, or combined process.
  • Certain embodiments of the hydrothermal-treatment and solvent-extraction procedures may comprise:
  • HTT crude algae oils may differ from the composition of solvent-extracted and RBD-treated algae oils such as that in Example III, and certain embodiments of the invention may comprise said one or more renewable oils comprising, consisting essentially of, or consisting of said HTT crude algae oils or fractions thereof.
  • Examples I-III detail processing of canola oil or algae oil in multiple tests using zeolite-alumina matrix catalysts, including catalyst in protonated form and in gallium-cation-retaining form.
  • the tests showed excellent yields of BTEX from both canola oil and algae oil, especially when the gallium-form was used, and may be indicative of the BTEX yields and/or yields trends that may be achieved with certain other renewable oils, including those from other plant, non-vascular photosynthetic organism, vegetable, seed, fungi, and bacteria sources.
  • Example IV details processing of fossil petroleum gas oil over a selected gallium-cation-retaining catalyst from Examples I-III, for comparison to the results from the renewable oil processing.
  • Examples V and VI detail processing of algae oil and hydrotreated algae oil by fluid catalytic cracking, compared to fossil petroleum vacuum gas oil, and describe certain embodiments wherein the FCC catalyst is supplemented with gallium-modified catalyst.
  • Example VII describes processing of algae oil by thermal treatment, followed by hydrotreatment and fluid catalytic cracking, and describes certain embodiments wherein the FCC catalyst is supplemented with gallium-modified catalyst.
  • Example VIII describes an exemplary FCC process unit commercial application, including structure details of the fluidized bed and systems for making-up/supplementing catalyst and additives to said fluidized bed.
  • Example IX describes an exemplary purpose-built process unit commercial application, which may be similar to a UOP CyclarTM unit and is designed for a feedstock comprised substantially or entirely of renewable oil.
  • the canola oil of Examples I and II was a commercially-available oil obtained from rapeseed, containing approximately 60-70 wt-% C18:1 and approximately 12 wt % oxygen.
  • the algae oil of Example III was of the type analyzed in Tables 1-3 below.
  • One may note the 48.8 wt-% free fatty acids, with 45.5 wt-% being C18:1 free fatty acids (carbon chain length 18, monounsaturated).
  • a portion of the free fatty acids in this algae oil may be those naturally-occurring in the algae and a portion may be fatty acids “freed” from their glyceride compounds during extraction from the algae.
  • Examples I and III used the 20 g scale reactor system 10 schematically portrayed in FIG. 1A .
  • the reactor system was controlled by a LabVIEWTM program and National Instruments DAQ hardware.
  • a dual piston chromatography pump 12 pulled reactant from a flask of feedstock 14 , and pumped it up to a furnace 16 containing the reactor 18 .
  • the feed pump was an ISCO piston pump with 500 cc capacity which was able to handle the highly viscose algae oil.
  • No feedstock preheat furnace 20 was used because it was determined previously that it was thermally cracking the canola oil before it could reach the catalyst.
  • the reactant mixed with a heated nitrogen stream 22 just before entering the top of the reactor 18 .
  • Reactor effluents passed through a cooling coil 26 and a liquid trap 28 , both contained in ice baths 30 .
  • the cooled vapor left the liquid trap and passed through a micro-GC 32 and then on to a vent.
  • An Agilent 2804 micro-GC measured the composition of the vapor phase every 4 minutes.
  • the reactor 18 in Examples I and III was a 1 ⁇ 2 inch diameter stainless steel reactor tube, measured 24 inches long, and contained a 10 g catalyst bed 24 centered within the furnace's 18′′ heated zone. Glass beads 40 packed in the bottom of the reactor supported the catalyst bed and glass beads 42 above the bed helped to vaporize the feed before it reached the catalyst.
  • using a preheat furnace for the feedstock resulted in thermal cracking of the canola oil before it could reach the catalyst, and so the feedstock preheat furnace 20 was not used in the experiments in Examples I-III.
  • thermocouples inserted axially into the catalyst zone of the tubular reactor measured the temperature 2 inches below the top and 2 inches above the bottom of the catalyst bed in Examples I and III.
  • Thermocouples also were mounted in the heated spaces of the furnace.
  • a LabVIEWTM-based control program adjusted the furnace temperature so that the average of the top and bottom catalyst temperatures stayed on setpoint.
  • the same program also controlled the pump and gas flow controllers, while logging all temperatures and flowrates.
  • the programmable ChromtechTM dual-piston pump supported flowrates from 0.001 to 12.00 mL min, although the viscosity of the canola oil limited the pump to flowrates of not more than around 1 mL/min without providing backpressure.
  • the ISCO pump used to deliver algae oil was programmable to deliver from 0.001 to 204 cc/min of feed.
  • a pair of Brooks Instruments mass flow controllers worked in tandem to accurately provide nitrogen flow rates up to 10 SLM. This one-reactor system and its use are further described below in Example I.
  • Example II used a reactor system modified, as shown schematically in FIG. 1B , to include two reactors in series with liquid removal between the two reactors.
  • Each of the two reactor structures, reactor loading, temperature control, product condensation, and product stream measurement and analysis for Example II were substantially the same as the equipment and methods described above for the single-reactor Examples I and III. The two-reactor system and its use are further described below within Example II.
  • Example IV utilized equipment and procedures that were substantially similar or the same as those used in Examples I and III, as will be understood from reading Example IV.
  • Example V utilized equipment and procedures for FCC MAT testing, and
  • Example VI utilized equipment and procedures for hydrotreating followed by FCC MAT testing, as will be understood from reading these examples, respectively.
  • Catalytic cracking of canola oil was conducted over a gallium-doped HZSM-5 zeolite catalyst, hereafter called “GaZSM-5”, in a 20 g scale reactor system
  • GaZSM-5 gallium-doped HZSM-5 zeolite catalyst
  • BTEX xylenes
  • Large yields of both BTEX and light paraffin were observed when cracking canola oil over the protonated form of ZSM-5, a.k.a., HZSM-5, in comparison to the other zeolites the inventors have used to crack canola oil, for example, in comparison to zeolite- ⁇ .
  • the gallium-doped catalyst increases olefin production due to the dehydrogenation capability of the gallium, and that the catalyst dehydrogenates and cracks the C16-C18 chains of the renewable oil to smaller olefins, especially C5+ olefins. Due to the shape selectivity of the catalyst, these C5+ olefins are then cyclized to C5 and C6 ring compounds which are further converted to aromatics.
  • the high BTEX selectivity of the catalyst when processing the renewable oils is due in some part to light paraffin conversion but also, importantly, to direct conversion of long chains to BTEX without first being cracked to C2-C4.
  • Gallium-doped HZSM-5 was prepared at Ga/framework-Al ratios of 1/10, 1/3, and 1/1; meaning that roughly 1/10, 1/3, or all of the cation sites hosted Ga cations. In the case of 1/10 and 1/3 Ga/framework-Al ratios, the remaining cation sites still hosted protons.
  • the first step in production of catalysts was to form pellets from powdered HZSM-5, which was Mobil ZSM-5 base catalyst purchased in powdered form from Zeolyst International. This was accomplished using Zeolyst CBV5524G powder (50/1 SiO 2 /Al 2 O 3 ) which was bound with 20 wt % Al 2 O 3 and extruded into 1/16′′ pellets and calcined.
  • the proton content of this material was measured using the temperature programmed desorption of n-propanamine and found to have an actual SiO 2 /Al 2 O 3 ratio of 61/1 (see V. Kanazirev, K. M. Dooley, G. Price, J. Catal. 146 (1994) 228-236 for this methodology)
  • the 1/1 GaZSM-5 was then prepared by incipient wetness impregnation of a 25 g batch of HZSM-5 pellets with 4.77 g Ga(NO 3 ) 3 .xH 2 O, where x is determined by microbalance drying experiments to be approximately 9-11, dissolved in 22.97 g water.
  • the wet catalyst was dried overnight in an oven at 120° C.
  • the 1/3 and 1/10 catalysts were prepared in a similar fashion, using 1.52 and 0.51 g Ga(NO 3 ) 3 .H 2 O, respectively.
  • the Ga/HZSM-5 Prior to catalytic cracking, the Ga/HZSM-5 was heated to 500° C. in flowing N 2 (converting the nitrate to the oxide), and then activated at 500° C. under a 100 mL/min stream of 30% hydrogen in nitrogen. The activation process is known to accelerate the ion-exchange of Ga cations for protons in the zeolite.
  • Canola oil was cracked over a HZSM-5 material (that is, no gallium) at 350, 400, 450, and 500° C. to determine which temperature would produce the most BTEX.
  • the cracking results showed the most BTEX at 400° C., so the GaZSM-5 experiments were also done at that temperature.
  • the total mass balance for each run was performed based upon the difference between grams of reactant fed and product collected.
  • Product collected was separated into three parts: 1) the gaseous product which is continuously measured by the micro-GC system, 2) a condensed liquid product which is collected from the reactor's effluent in a trap thermostatted at 0° C., and 3) the coke which is left on the catalyst.
  • the mass of condensed liquid product was measured, then a water phase was separated from an organic phase, and the organic phase analyzed by simulated distillation and GC-MS. When spent catalyst charges were removed from the reactor, a small sample was used in a microbalance system to determine coke content.
  • the rest of the spent catalyst was then subjected to coke removal in the calcining furnace using a synthetic air made of O 2 in Ar.
  • the total vapor product recovered was determined by integrating the micro-GC measurements of the gaseous product composition over time and using the known N 2 flowrate as an internal standard.
  • the propane yield decreased from 21.8% to 14.6% as the Ga content went up.
  • the ethane yield went from 3.1% to 0.25%, while the hydrogen yield increased from 0.3% to 1.2%.
  • the gasoline range material is the fraction which boils below 225° C.
  • Gasoline requirements (D4814) specify that 10, 50, 90, and 100% of the fuel should boil by certain temperatures, respectively called T10, T50, T90, and FBP (final boiling point).
  • the FBP is fixed at 225° C., but the other temperatures vary both seasonally and regionally. These temperatures provided the break points for evaluating the composition of the organic phase liquid products shown in FIG. 5 .
  • HZSM-5 is well known for producing high yields of BTEX, which all have boiling points in the 60-188° C. range.
  • the gallium-doped catalyst performed significantly better than the HZSM-5 in BTEX production, as evidenced by the yields shown in FIG. 5 .
  • Ga/framework-Al increased from 0 to 1.0, the yield of products between 60-188° C. increased from 34.6% to 40.8% based on canola oil converted.
  • the liquid products were also analyzed by GC-MS to quantify the BTEX content, which increased with the gallium content of the ZSM-5 catalyst.
  • the benzene (B.P. 80.1° C.) yield increased from 7.5% to 8.4% as the Ga/framework-Al increased from 0 to 1.0 and comprised nearly all the material in the 60-93.5° C. range.
  • Toluene (B.P. 110.6° C.) behaved similarly and had the greatest change in yield, going from 15.4% up to 19.3%. It also made up just over half of the material in the 93.5-188° C. boiling point range.
  • the C8 aromatic yields ethylbenzene, B.P.
  • HZSM-5 catalysts are well known for their ability to produce high levels of benzene, toluene, and xylenes. Cracking canola oil with a standard HZSM-5 catalyst yielded about 32.3% BTEX at 400° C., but, by adding gallium to the catalyst, the inventors observed an increase in the BTEX yield, of 7 wt-%, to achieve about 39.3% under the same conditions.
  • BTEX aromatics comprised 77% of the organic liquid products, so, in addition to representing a possible renewable source of aromatics for the chemical industry, it might be possible to blend it directly into kerosene or diesel to obtain a jet fuel nearly identical to Jet A-1. Additional testing will be needed to measure the products from these experiments for the chief properties of jet fuel, such as freezing point, vapor pressure, viscosity, flash point, and heat of combustion.
  • Catalytic conversion of canola oil to aromatics was conducted using two reactors in series.
  • the goal of the work in this Example was to optimize the formation of benzene, toluene, ethylbenzene, and xylenes (BTEX), which are valuable for gasoline or use as chemicals.
  • Canola oil cracking on H-ZSM-5 has been shown to generate substantial amounts of light paraffins, for example, 25 wt % oil fed, as shown in Example I.
  • This Example continues experimentation directed toward achieving “green BTEX” production, by increased conversion of light paraffins to BTEX and, the inventors believe, by direct conversion of long chains to BTEX.
  • a multiple-reactor system is employed wherein vapor products from a primary reactor cracking canola oil over H-ZSM-5 or GaZSM-5 were fed to a secondary reactor containing GaZSM-5 and converted to BTEX.
  • “primary” means the first reactor to which the oil feedstock is fed
  • “secondary” means the second reactor to which the gas/vapour effluent from the primary reactor is fed.
  • the secondary reactor containing GaZSM-5 raised the BTEX yield achieved from cracking canola oil over H-ZSM-5 (in first reactor) from 39.5 wt % oil fed to 43.8 wt %, that is, an increase of 4.3 wt-% yield.
  • the secondary reactor containing GaZSM-5 also raised the BTEX yield achieved from cracking canola oil over GaZSM-5 (in the first reactor) from 46.3 wt % oil fed to 51.2 wt %, that is, an increase of 4.9 wt-% yield.
  • the cracking experiments using the protonated form of ZSM-5 catalyst used Zeolyst H-ZSM-5 with a 25/1 Si/framework-Al ratio.
  • the experiments using the Ga cracking catalyst also used the same Zeolyst H-ZSM-5 material, with gallium loaded by incipient wetness addition of Ga(NO 3 ) 3 at a loading of 1 Ga/framework-Al.
  • the terminology “GaZSM-5(1-1)” is used to emphasize that the loading is 1 Ga-1 Al.
  • the cracking process was performed in a two-reactor configuration, made up of two reactors in series shown in FIG. 1B . Both reactors were mounted vertically within the furnace. A thermocouple was centered in each reactor tube to monitor the temperature in the catalyst bed. This temperature was taken as reaction temperature and was maintained at a constant set-point by a LabVIEW based control program that adjusted the furnace power.
  • the liquid product from the first reactor (11 mm I.D. and 521 mm overall length) was condensed in the glass cylinder and the vapor product entered the second reactor (11 mm I.D. and 419 mm overall length) for further reaction.
  • the liquid product from the second reactor was condensed in the glass cylinder and the vapor product flowed to a Micro GC (Agilent G2804A) that analyzed the gas composition every four minutes.
  • the details of the two-reactor system 10 ′ of FIG. 1B are called-out as follows: nitrogen cylinder 51 , gas regulator 52 , valve 53 , mass controller 54 , syringe pump 55 , first (primary) reactor 56 , catalyst 57 in primary reactor, first (primary) furnace 58 , thermocouple in the primary reactor (not shown), glass cylinder 60 , ice-cooled condenser 61 , liquid products 62 , secondary furnace 63 , secondary reactor 64 , catalyst 65 in secondary reactor, glass cylinder 66 and ice-cooled condenser 67 for secondary reactor effluent, liquid products 68 of secondary reactor effluent, and gas chromatograph 67 .
  • the first experiment was done with H-ZSM-5 loaded in the first reactor, and GaZSM-5(1-1) in the second reactor.
  • a second experiment was done with GaZSM-5(1-1) loaded in both reactors in series.
  • Reaction temperatures were set according to the performance of the loaded catalysts, wherein the optimum reaction temperatures, determined in previous experimentation, of H-ZSM-5 and GaZSM-5(1-1) for cracking canola oil are 400° C. and 350° C., respectively. So, the first reactor (receiving canola oil as feed) was set at reaction temperature 400° C. when containing H-ZSM-5, and 350° C. when containing GaZSM-5.
  • the second reactor containing GaZSM-5(1-1) for both experiments, was set to 450° C. to convert the vapor products from the first reactor, based on the inventors' earlier work that showed 450° C. was the optimum temperature for propane conversion to BTEX over GaZSM-5(1-1).
  • the first reactor contained 10 g catalyst and the second reactor contained 5 g catalyst.
  • Experiment SAP359 is the experiment number for the run wherein H-ZSM-5 was followed by GaZSM-5(1-1) (primary and secondary reactors, respectively)
  • experiment SAP360 is the experiment number for the run wherein GaZSM-5 was followed by GaZSM-5 (primary and secondary reactors, respectively).
  • GaZSM-5(1-1) was heated to 500° C. in flowing nitrogen and then activated at 500° C. under a 100 ml/min stream of 30% hydrogen in nitrogen for at least 1 hr.
  • the activation process drives Ga cations into the zeolite pores and it replaces protons in the zeolite.
  • the reactor was cooled to the desired reaction temperature.
  • Co-feed nitrogen was set to 46.5 ml/min and the canola oil flow rate was set to 0.182 ml/min. The experiment lasted about 2 hrs and 20 g reactant was fed over that time period.
  • the total mass balance for each run was performed based upon the difference in grams of the reactant fed and products collected.
  • the products mainly comprise three parts, gas, liquid and coke.
  • Table 8 gives the reaction conditions and product mass obtained from canola oil cracking in each reactor, as well as the total mass balances. The mass balance was within 5 wt % for these two runs.
  • Table 9 contains the composition of the products summarized in Table 8 calculated as the weight percent of total oil fed.
  • the 9.81 wt % hexanes+ yield of the SAP359 gas product was particularly high, compared to the 2.4 wt % yield of hexanes+ in SAP284-287 (cracking canola oil over H-ZSM-5 at 400° C., see Example I). This led the inventors to suspect that the BTEX products were not completely condensing upon leaving the second reactor. Therefore, three gas product samples were taken during SAP360 at 30 minute intervals and analyzed using an Agilent 5975 GC-MS to identify the vapor phase products, especially the hexane+ fraction reported by the micro-GC. The GC-MS was set up to only identify molecules larger than C3.
  • the flame ionization detector showed 4 primary peaks, which were identified by the mass spectrometer as benzene, toluene, and xylenes. Some other molecules were present, but in such low concentrations that they could not be identified. So, the hexanes+ in the gas as analyzed by the micro-GC can be regarded as principally aromatics and were included in the BTEX and gasoline range yield totals.
  • Adding another reactor to convert vapor product obtained from canola oil cracking can improve OLP yield and BTEX yield.
  • the hexanes+ fraction in the gas products are un-condensed aromatics.
  • the best total yields of BTEX in this Example were achieved when all (both) reactors were loaded with gallium-loaded catalyst. Specifically, cracking canola oil over GaZSM-5 at 350° C. produced 46.3% BTEX (assuming hexanes+ were un-condensed aromatics), and adding the second reactor loaded with GaZSM-5 at 450° C. increased the total BTEX yield to 51.22 wt %.
  • the BTEX yield of 39.45 wt % from cracking canola oil over H-ZSM-5 at 400° C. increased to 43.82 wt % with the addition of the second reactor containing GaZSM-5 catalyst at 450° C.
  • Possible optimization parameters include gallium loading levels in both reactor beds, amount of catalyst in each bed, temperatures of each bed, space velocities relative to feedstocks flowrate and relative to nitrogen feed, and other possible parameters.
  • Algae oil (sample NL-72-32-03) was subjected to catalytic cracking over a gallium-doped ZSM-5 (GaZSM-5, 1.0 Ga/framework-Al in the zeolite) and the proton form of ZSM-5 (HZSM-5) at 400° C.
  • GaZSM-5 gallium-doped ZSM-5
  • HZSM-5 proton form of ZSM-5
  • the goal of this work was to compare the formation of aromatics from algae oil between these two catalysts, specifically benzene, toluene, ethylbenzenes, and xylenes (BTEX), for fuel blending or for use as feedstocks in the chemical industry. It was observed that GaZSM-5 produced more BTEX and less paraffins (especially propane) compared to HZSM-5, during algae oil cracking at the same reaction temperature.
  • GaZSM-5 was made according to the methods reported in Example I starting with the same Zeolyst CBV5524G powder (50/1 SiO2/Al2O3) which was converted into pellets as in Example I then loaded with gallium in an identical way to Example I.
  • the only gallium loading level which was used in this study corresponded to 1.0 Ga/framework-Al in the zeolite, referred to in this Example as “GaZSM-5.”
  • the base ZSM-5 material was used in its fully protonated form referred to as “HZSM-5.” Since HZSM-5 gave the highest BTEX yield at 400° C. for a canola oil feedstock in previous work, the algae oil cracking experiments were also done at that temperature.
  • the GaZSM-5 catalyst was activated at 500° C. under a 100 ml/min stream of 30% hydrogen in nitrogen for at least 1 hour. This activation process is known to accelerate the ion-exchange of Ga cations for protons in the zeolite.
  • the reactor was brought to 500° C., and the catalyst was activated
  • Reactor temperature was set to 400° C.
  • Nitrogen co-feed was established at 0.0465 SLM
  • Table 10 gives the overall mass balances obtained from algae oil cracking over GaZSM-5 and HZSM-5. It can be seen clearly GaZSM-5 produced more liquid and less gas compared to HZSM-5. The detailed product analysis is discussed below.
  • the C1-C3 paraffin yield decreased with the addition of gallium to the catalyst.
  • the propane yield decreased from 14.0 wt % to 6.4 wt %.
  • GaZSM-5 gave a 2.0 wt % yield of hydrogen, compared to HZSM-5 giving only 0.5 wt % yield of hydrogen.
  • the liquid products were also analyzed by GC-MS to quantify the BTEX content.
  • Gasoline yield was obtained via simulated distillation.
  • GaZSM-5 produced almost 40.8 wt % yield of BTEX in the liquid product, compared to HZSM-5 producing 34.1 wt % yield of BTEX.
  • GaZSM-5 gave 42.4 wt % yield of gasoline in the liquid and HZSM-5 gave 38.1 wt %.
  • BTEX yield and gasoline yield were increased by 6.7 wt % and 4.3 wt %, respectively, in the liquid phase. It also showed that BTEX are the major products in the gasoline for these two materials.
  • the composition of BTEX in the gasoline is as high as 96.4%, compared to 89.6% for the HZSM-5.
  • FIG. 8 shows the overall yields obtained from these two catalysts.
  • the overall BTEX yield and gasoline range product yield were 46.8% and 48.3%, respectively, with 96.9% of gasoline range molecules being BTEX.
  • the composition of BTEX in the liquid product (including hexanes+) was 83.6%. These excellent yields may be compared to those for HZSM-5, which were 38.9% overall BTEX yield and 42.9% gasoline yield.
  • 90.7% of the gasoline fraction was BTEX
  • 78.2% of the total liquid product (including hexanes+) was BTEX. Therefore, FIG. 8 shows that the total BTEX yield (“overall BTEX yield”) was increased by 7.9% by adding gallium to the HZSM-5, and gasoline yield was also increased by 5.4%.
  • Example III Conclusions from Example III, and Comparison of Example I (Canola Oil) and Example III (Algae Oil)
  • HZSM-5 Adding gallium to HZSM-5 increases BTEX yield and gasoline yield for algae oil cracking at 400° C. GaZSM-5 also produced significantly more hydrogen than HZSM-5, which is consistent with an increased aromatics production.
  • This Example describes the catalytic cracking of gas oil (from Conoco Phillips) over HZSM-5 and Ga-doped ZSM-5 (GaZSM-5) at 400 degrees C., for comparison to canola oil and algae oil results from Examples I and III.
  • the goal of this work was to compare the formation of aromatics between these two catalysts, specifically benzene, toluene, and xylenes (BTEX), for fuel blending, or for use as feedstocks in the chemical industry. It was observed that Ga/ZSM-5 produced more BTEX and less paraffins (especially propane) compared to HZSM-5 gas oil cracking at the same reaction temperature. However, the boost in BTEX yield when Ga was added to the catalyst was much greater for the renewable oils (algae and canola oils) and the overall gasoline yields are also greater for the renewable oils.
  • GaZSM-5 was made according to the method reported in Example I, but the only gallium loading level that was used in this Example corresponded to 1.0 Ga/framework-Al in the zeolite (Ga/ZSM-5).
  • the base ZSM-5 material was used in its fully protonated form (H-ZSM-5). Because H-ZSM-5 gave the highest BTEX yield at 400 degrees C. for algae oil feedstock in Example III, the gas oil cracking experiments of this Example were also done at this temperature.
  • the Ga/ZSM-5 catalyst was activated at 500 degrees C. under a 100 ml/min stream of 30% hydrogen in nitrogen for at least 1 hour. This activation process is known to accelerate the ion-exchange of Ga cations for protons in the zeolite.
  • the catalyst was dried at 400° C. with nitrogen flow rate of 46.5 ml/min for 2 hours prior to utilization as a cracking catalyst.
  • Reactor temperature was set to 400° C.
  • the total mass balance for each run was performed based upon the difference between grams of reactant fed and product collected.
  • Product collected is separated into three parts: 1) the gaseous product which, is continuously measured by the micro-GC system, 2) a condensed liquid product which, was collected from the reactor's effluent in a trap and glass adapter at 0° C., and 3) the coke which, is left on the catalyst and simply measured by mass difference between the fresh and used catalyst.
  • Table 11 gives the overall mass balances obtained from gas oil cracking over Ga/ZSM-5 and H-ZSM-5. It can be seen clearly Ga/ZSM-5 produced more liquid and less gas compared to H-ZSM-5. The detailed product analysis is discussed below.
  • FIG. 9 shows the gas phase products produced during cracking of gas oil. It is clear that the C1-C3 paraffin yield decreased with doping of the zeolite with gallium, and the amount of propane decreased by a factor of three. It is also clear that a higher amount of hydrogen product was present in the run utilizing Ga/ZSM-5 compared to the run utilizing H-ZSM-5. The increased hydrogen product with the gallium-doped zeolite correlated well with the previous work involving algae (Example III) and canola oil (Example I) cracking over Ga/ZSM-5, showing that an increased amount of BTEX is formed through the addition of Ga.
  • a simulated distillation of the Conoco Phillips gas oil is compared to the simulated distillation of algae oil in FIG. 11 .
  • Simulated distillation of the canola oil is not shown in FIG. 11 because canola oil breaks down before it vaporizes.
  • These feedstock simulated distillation curves may be compared to the product simulated distillations that are given in FIG. 12 .
  • Gasoline yields of each of the products from gas oil, canola oil, and algae oil over the H-ZSM-5 and GaZSM-5 catalysts were also obtained via simulated distillation, and these results are included in the last line of Table 12. It may be noted that, when the feedstock was gas oil, addition of Ga had virtually no effect on the gasoline yields, which were about 48% in both cases. However, for the renewable oils, a significant effect of the addition of Ga was noted.
  • FIG. 12 also shows how much different the products from the various feedstocks were.
  • the renewable oils produced much lighter liquid products than the gas oil produced.
  • the algae oil and canola oil feedstocks were heavier than gas oil, a much greater disparity in the overall reduction in boiling point distribution of the feedstock resulted when the renewable oils were the feedstocks.
  • An algae oil was obtained from Nannochloropsis salina by HTT hydrothermal-treatment and heptane solvent extraction, according to method steps a-j listed above in the section entitled “Alternative Techniques of Obtaining Crude Algae Oil from Biomass”.
  • the hydrothermal treatment step (step b in the method listed above) was conducted at 260 C for 0.5 hour. See the “Algae Oil Feed” analysis in Tables 4-6, above.
  • the algae oil feed was catalytically cracked in a Micro Catalytic Cracking (MAT) system.
  • MAT equipment and tests are well known in petroleum refining R & D, and have been designed and evolved over the years to be highly correlated with large-scale fluidized catalytic cracking (FCC) units.
  • FCC fluidized catalytic cracking
  • the predictive ability of MAT tests is rather remarkable considering they require only grams of feed, whereas commercial FCC units can process over 100 mbpd of feed.
  • the MAT tests like commercial FCC units, operate at cracking temperatures of about 1000 degrees F. and with very short catalyst-feed contact times (1-5 seconds), and use zeolite-based catalysts at atmospheric pressure.
  • MAT testing was used to compare FCC processing of algae oil feed (“crude algae oil”) and FCC processing of a reference petroleum feedstock from a European refinery, specifically, a petroleum-derived vacuum gas oil (VGO) containing roughly 10 mass % resid, having an API of 22, and a sulfur level of 0.61 wt %.
  • VGO petroleum-derived vacuum gas oil
  • Table 13 shows the yield structure in MAT testing of the standard VGO (first column of data) and the algae oil feed (second column of data), with the difference calculated and shown in the third data column.
  • FIG. 13 compares the conversion (percent of the feed converted to distillate and to lighter components such as gasoline, plus coke) at a range of catalyst-to-oil ratios (C/O) for the algae oil feed and the reference petroleum VGO feed.
  • C/O catalyst-to-oil ratios
  • FIG. 14 shows that the coke yield for the algae oil feed is significantly higher than for the VGO. This is important because commercial-scale FCC units operate in such a way that the heat balance drives the conversion of feeds to lower levels when they have high coke yields. Consequently, the algae oil feed of this Example is expected to exhibit much lower conversion than VGO in commercial units due to its high coke yield.
  • FIGS. 17-22 The yields of gasoline, LCO (distillate range material), DCO, TC2, TC3, and TC4 from the algae oil and VGO are shown in FIGS. 17-22 , respectively. Note that the corresponding yields from hydrotreated algae oils, in Example VII below, are also shown in FIGS. 17-22 , for study of the effect of hydrotreating prior to FCC processing.
  • the algae oil feed of this Example exhibits coke yields that may be problematic for many FCC units.
  • certain unhydrotreated algae oils for example, certain unhydrotreated HTT hydrothermally-treated and solvent-extracted algae oils
  • Example V Hydrotreatment of the algae oil feed of Example V was performed at various conditions (Runs 4SEBR, 5 SEBR, and 6SEBR) to obtain oil products. These experimental runs were conducted in a semi-batch reactor (continuous flow of H2 while the oil and catalyst remained in a well-stirred reactor at pressure and temperature). At the end of each 1 hour residence time run, the oil was removed and analyzed as a product sample called “oil product”. See the analysis of the three hydrotreated oil products, compared to the algae oil feed (of Tables 4-6), in Tables 14-16, below.
  • catalytic hydrotreating Three variations of catalytic hydrotreating were conducted at the same temperature (370 degrees C.) with the same catalyst, but at three pressures ranging from 1000 psi to 1800 psi. Specifically, 4SEBR, 5SEBR, and 6SEBR were conducted at 1000 psig, 1500 psig, and 1800 psig pressure, respectively.
  • the hydrotreatment catalyst was a commercially-available NiMo/Al2O3 that had been pre-sulfided and handled prior to the semi-batch reaction such that re-oxidation did not occur.
  • NiMo/Al2O3 catalyst used for these hydrotreating experiments was a sample of catalyst used for processing Canadian oil sands, believed to have a pore structure with BET surface area in the range of 150-250 m2/g, micropores in the average diameter range of 50-200 Angstroms, and macropores in the range of 1000-3000 Angstroms.
  • Table 17 shows the yield structure in MAT testing of the standard VGO (first column of data) and of the high-severity-hydrotreated oil (6SEBR, second column of data), with the difference calculated and shown in the third data column.
  • FIG. 15 shows the reactivity of the three hydrotreated algae oils, compared to the algae oil feed of Example V and VGO, in the FCC process.
  • the algae oil that had been hydrotreated at higher severity (6SEBR, 1800 psig) showed superior reactivity compared to the algae oils hydrotreated at lower severity (4 and 5SEBR), with the higher-severity-hydrotreated oil being more reactive than the VGO. That is, conversion of the high-severity-hydrotreated algae oil in the MAT test is higher than that for VGO at the same C/O range of about 2-2.5.
  • the moderately-hydrotreated oil (5SEBR, 1500 psig) was about as reactive as the VGO, whereas the material produced from hydrotreating at 1000 psi was, very surprisingly, less reactive than the VGO and the crude algae oil feed.
  • hydrotreating improved the coke yields relative to those from the crude algae oil of Example V.
  • the coke yield from the 1800-psig-hydrotreated algae oil was similar to that of the VGO at the same conversion of about 70 wt %.
  • FIGS. 17-22 show weight % yield key products (y-axis) plotted against conversion (x-axis) as obtained by varying C/O. These key yields are discussed in the following paragraph.
  • FIG. 17 shows that gasoline yields were lower from algae oil feed of Example V and its hydrotreated counterparts (the oil products from 4-6SEBR), compared to those from VGO at similar conversions.
  • FIG. 18 shows that distillate yields (LCO or “light cycle oil”) were higher from algae oil feed and its hydrotreated counterparts, compared to those from VGO at similar conversions.
  • FIG. 19 shows that DCO yields (“decanted oil”, the heaviest and least-valued product from catalytic cracking) were markedly lower for from algae oil feed (crude algae oil) and its hydrotreated counterparts, compared to DCO from the VGO at similar conversions.
  • FIGS. 20-22 show the yields of specific components lighter than gasoline, that is, TC2, TC3, and TC4.
  • the yield structure obtained by MAT (FCC) testing of the high-severity-hydrotreated algae oil (6SEBR) suggest the high-severity-hydrotreated algae oil may have a higher value than VGO, even when the cost of the high-pressure hydrotreating is taken into account.
  • the lower coke-on-FCC-catalyst of the high-severity-hydrotreated algae oil (6SEBR) helps the heat balance in the FCC, which in turn improves conversion and yields.
  • algae oil will be hydrotreated prior to being upgraded in an FCC operation.
  • an FCC operation would be characterized by being loaded-in-part with gallium-cation-catalyst and fed-in-part with algae-oil.
  • Improved coke yields vs conversion for the hydrotreated algae oil may affect the optimum catalyst and algae oil percentages, but the gallium catalyst and algae oil percentages described above (for example, 1-20 wt %, or 5-10 wt %) are expected to be reasonable starting places for optimization of the hydrotreated algae oil FCC embodiments.
  • certain methods of upgrading algae oil may comprise:
  • FCC unit comprising at least some gallium-modified catalyst selected from any of the gallium-catalyst embodiments described in this disclosure, for example, at least some gallium-cation catalyst.
  • Certain alternative embodiments may comprise step (b) instead being: hydrotreating the crude algae oil over one or more hydrotreating catalysts characterized by BET surface areas in the range of about 150-250 m2/g, and comprising macropores of at least 1000 Angstroms, wherein said one or more hydrotreating catalysts may comprise Ni/Mo and/or Co/Mo on alumina or silica-alumina supports having said pore structure.
  • Certain alternative embodiments may comprise step (b) instead being: hydrotreating the crude algae oil over one or more hydrotreating catalysts comprising macropores in the range of at least about 1000 Angstroms.
  • End products from the above processes of this Example may include one or more of BTX plant feedstock, gasoline, kerosene, jet fuel, diesel fuel, or lube base stock, for example.
  • Certain methods of this Example may comprise, consist essentially of, or consist of method steps a-e above.
  • Algae oils/fractions may range from very little to all of the feedstock for the processing unit(s) in steps b and e above, for example, from about 0.1 volume percent up to 100 volume percent of the liquid feedstock being fed to said processing unit(s).
  • the hydrotreated oil derived from the crude algae oil will be a minor portion of the entire FCC feedstock (for example, 1-20 wt % or 5-10 wt %) and the gallium-cation catalyst will be only a portion of the entire FCC catalyst loading (for example, 1-20 wt % or 5-10 wt %).
  • Certain crude algae oils may be thermally treated prior to being fed to FCC operations such as described in Example VI. Because of the complex composition and/or the high molecular weight materials of said certain algae oils extracted from biomass, thermal treatment prior to processing in any catalytic unit may be effective in reducing one or more of the following characteristics: oxygen content and/or other heteroatom content, metals content, high molecular weight content, 1000 degree F.+ content, 1020 degree F.+ content, boiling range/distribution, viscosity, and/or catalyst poisons and/or coke-on-catalyst precursors.
  • catalyst deactivation due to poisoning of catalyst active sites (such as acidic sites being poisoned by basic nitrogen compounds) and/or producing coke-on-catalyst.
  • thermal treatment will reduce most or all of these characteristics.
  • thermal treatment of whole crude algae oil obtained from biomass is expected to mitigate catalyst deactivation and/or coke-on-catalyst production caused by the crude algae oil, thereby extending catalyst life in such units as a hydrotreater, or improving heat balances in continuous catalyst regeneration systems such as FCC units.
  • the thermal treatment methods of this Example may be used in conjunction with hydrotreating over large-pore catalysts (see Example VI) to improve catalyst lives and/or heat balances in downstream units.
  • a thermal treatment method may be applied to certain crude algae oils, the method comprising:
  • End products from the above process may include one or more of BTX plant feedstock, gasoline, kerosene, jet fuel, diesel fuel, or lube base stock, for example.
  • Certain methods of this Example may comprise, consist essentially of, or consist of method steps a-g above.
  • Algae oils/fractions may range from very little to all of the feedstock for the processing unit(s) in steps b, d, and g above, for example, from about 0.1 volume percent up to 100 volume percent of the liquid feedstock being fed to said processing unit(s).
  • the hydrotreated oil derived from the crude algae oil will be only a portion of the entire FCC feedstock (for example, 1-20 wt % or 5-10 wt %) and the gallium-modified catalyst will be only a portion of the entire FCC catalyst loading (for example, 1-20 wt % or 5-10 wt %).
  • the above steps of this Example may be modified so that only a portion of the crude algae oil, such as a heavy fraction, is thermally-treated, but both the thermally-treated portion (minus any solids/coke and gasses formed in the thermal treating) and the un-thermally-treated portion of the crude algae oil are combined for hydrotreating and subsequent fluid catalytic cracking.
  • Certain embodiments may comprise “spiking” relatively small amounts of renewable oil(s) into a refinery unit previously operating on non-renewable feedstocks, and providing at least some gallium-cation catalyst in the unit.
  • relatively small amounts may be meant that the renewable oil may be added as 1-20 wt % (more typically 5-10 wt %) of a unit's feedstock, with gallium-cation catalyst being added as 1-20 wt % (more typically 5-10 wt %) of the unit's catalyst.
  • Such a “spiking” approach may be particularly effective in an fluidized catalyst process unit, for example, an FCC unit, as further described below.
  • conventional FCC feedstock is heated and sprayed into the base of a riser (a vertical or upward-sloped pipe), where the pre-heated feedstock contacts fluidized zeolite catalyst typically at about 950 to 1030 degree F. (approximately 510 to 555 degree C.).
  • the hot catalyst vaporizes the feedstock and catalyzes the cracking reactions that break down the high molecular weight hydrocarbons into lighter components including LPG (liquid petroleum gas such as C3-C4 olefins), and acyclic or cyclic hydrocarbons (C5-C12).
  • LPG liquid petroleum gas such as C3-C4 olefins
  • C5-C12 acyclic or cyclic hydrocarbons
  • the catalyst-hydrocarbon mixture flows upward through the riser for just a few seconds (for example, 2-4 seconds) and then the mixture is separated via cyclones.
  • the catalyst-free hydrocarbons are routed to a fractionation column for separating shorter hydrocarbon products (for example, C3-C12 hydrocarbons) from the heavier fuels.
  • the shorter hydrocarbons many of which are suitable as gasoline products, are more volatile than the heavier fuels.
  • the heavier fuels include diesels and jet fuels that fractionally distill between approximately 200 degree C. and 350 degree C. at atmospheric pressure.
  • the cracking catalyst is “spent” by reactions that deposit coke on the catalyst and greatly reduce activity and selectivity.
  • the process of coke formation is important to the overall process because it increases the H/C (hydrogen to carbon) ratio of the gaseous products to a range more suitable for gasoline.
  • the spent catalyst is disengaged from the cracked hydrocarbon vapors and sent to a stripper where it is contacted with steam to remove hydrocarbons remaining in the catalyst pores.
  • the spent catalyst then flows into a fluidized-bed regenerator where air (or in some cases air plus oxygen) is used to burn off the coke to restore catalyst activity and also provide the necessary heat for the next reaction cycle.
  • the regenerated catalyst then flows to the base of the riser, repeating the cycle.
  • Catalyst and additives are typically added to FCC units using systems each comprising a bin and a lock hopper.
  • the minimum catalyst addition rates are determined by the physical attrition and loss of the FCC catalyst as fines that escape capture in the cyclone systems in both the regenerator flue gas and the oil that goes from the riser/reactor to the main fractionators. Thus, catalyst fines show up in the slurry oil that is also sometimes called decant oil or DCO.
  • Catalyst/additives are added to the FCC at rates above this physical loss depending on the activity for conversion and yields that are desired in the FCC. For example, if a higher activity of catalyst/additive is required, fresh catalyst/additive will be added at a higher rate.
  • a refinery unit may be purpose-built for processing solely renewable oil(s) over catalyst that is only, or substantially, a gallium-cation catalyst, to produce excellent yields of BTEX and/or gasoline and hydrogen.
  • One such purpose-built unit may be similar to a UOP CyclarTM unit, which comprises a moving bed of said gallium-cation catalyst and a coke-burning regeneration section, as schematically portrayed in FIG. 24 .
  • a purpose-built fixed-bed reactor unit may be effective. Regeneration in both units may be limited to solely coke-burning followed by reduction during normal operation in the reactor.
  • Both units would be optimized with respect to temperature, pressure, flowrates, gallium loading, etc., as would be understood by those of skill in the art.
  • These purpose-built units would preferably operate on 80-100 wt %, and more preferably 90-100 wt % renewable oil(s), for example, algae oil, with the catalyst being 80-100 wt %, or more preferably, 90-100 wt %, gallium-cation-retaining catalyst.
  • Information regarding conventional UOP CyclarTM units may be obtained from UOP, Des Plaines, Ill., U.S.A.
  • Information regarding fixed-bed reactor units may be obtained from several petroleum refinery unit design companies.
  • Example I-IX it may be noted from the above detailed description, including Example I-IX, that many embodiments may be described as a process for producing BTEX or gasoline, the process comprising: contacting, at elevated temperature, a feedstock comprising at least one renewable oil with a catalyst comprising a catalytically-active form of gallium to produce a product stream comprising BTEX.
  • the renewable oil may be canola oil, algae oil, algae oil extracted from a green alga or a blue-green alga, or other renewable oil(s), or fractions thereof, for example. It may be noted from the data herein that certain embodiments of the process the renewable oil is canola oil, that BTEX may be in said product stream in a yield of greater than 35 wt-%.
  • the renewable oil is algae oil
  • BTEX may be in said product stream in a yield of greater than 42 wt-%.
  • said product stream comprises a yield of greater than 15% wt-% Benzene.
  • Said catalyst may a zeolitic catalyst that is gallium-modified to comprise gallium cations in a ratio of about 1/1 Ga/framework-Al, for example.
  • Said contacting may done in many reactors/vessels/risers, for example: in a single reactor, a series of reactors, a series of at least a first reactor and a second reactor, wherein liquid is removed from the intermediate product stream between the first and second reactors, and vapor from the first reactor is fed to said second reactor, a fixed-bed reactor, in a moving catalyst bed, and/or a riser of a fluidized catalytic cracking unit, for example.
  • the contacting may take place at 510 to 555 degree C. temperature or at 400-555 degrees C. temperature, for example.
  • Said contacting may take place for 2-4 seconds.
  • said renewable oil is algae oil that has not been processed between being extracted from algae and said contacting.
  • said algae oil has been processed in a RBD process and/or a degumming process, but in certain embodiments the algae oil has not been processed in a RBD process and/or a degumming process.
  • said algae oil has been hydrotreated prior to said contacting.
  • the catalyst may be a gallium-doped form of one or more zeolite-alumina matrix catalysts with pore sizes having 10 oxygen atoms in the pore mouth, for example, selected from the group consisting of: ZSM-5, ZSM-11, ZSM-23, MCM-70, SSZ-44, SSZ-58, SSZ-35, and ZSM-22.
  • Certain embodiments may be described as: a process for producing aromatics (for BTEX feedstocks or for gasoline, for example) and/or hydrogen from renewable oil, the process comprising: providing a reactor vessel or riser containing catalyst, said catalyst comprising a gallium-cation catalyst; and contacting a feedstock with said catalyst at elevated temperature; wherein said feedstock comprises renewable oil selected from the group consisting of: oil derived from biomass living in the past 50 years; canola oil; oils extracted from vegetables including corn, soybean, sunflower, and sorghum; algae oil from naturally-occurring algae; algae oil from genetically modified algae; oil from seeds; oil from fungi; and oil from a photosynthetic or non-photosynthetic bacteria.
  • Said renewable oil may be various percentage of the entire feedstock to these various processes, for example, in the range of about 1 wt % (or even less, for example, 0.01 wt %) up to 100 wt % of said feedstock.
  • said renewable oil may 1-20 wt %, 50-100 wt %, 80-100 wt % of said feedstock, or 90-100 wt % of the total feedstock.
  • the catalyst comprising a catalytically-active form of gallium and/or the gallium-cation catalyst mentioned above may, in certain embodiments, comprise any percentage of the total catalyst of the process, for example 1 wt % (or even less, for example, 0.01 wt %) up to 100 wt % of said feedstock.
  • the catalyst comprising a catalytically-active form of gallium and/or the gallium-cation catalyst may be 1-20 wt %, 50-100 wt %, 80-100 wt %, or 90-100 wt % of said feedstock.
  • the weight percentage of catalyst comprising a catalytically-active form of gallium and/or the gallium-cation catalyst in the reactor vessel or riser will be equal to the weight percentage of renewable oil in the feedstock to the process.
  • the riser is a fluidized catalytic cracking unit (FCC) riser and the catalyst further comprises a Y-Zeolite FCC catalyst in said riser, so that the FCC operates on catalyst/additives comprising catalyst comprising catalytically-active form of gallium and/or the gallium-cation catalyst, Y-zeolite, and optionally other conventional FCC additives.
  • the reactor vessel is a moving-bed vessel adapted so that said catalyst moves through the reactor vessel by gravity.
  • the temperature of contact with the catalyst is an elevated temperature is in the ranges of 375-425 degrees C. or 350-555 degrees C., but in other embodiments, it may be different from these ranges based on the requirements of catalysts with which the gallium catalyst is mixed.
  • renewable oil(s) obtained from non-vascular photosynthetic organism(s), for example, naturally-occurring algae or cyanobacteria, or genetically-modified algae or cyanobacteria.
  • the renewable oil mixed or otherwise combined with other components that are selected from the group consisting of: one or more fossil oil fractions, one or more refined fossil oil products or fractions, naphtha, gasoline, jet fuel, diesel, and any combination thereof.
  • Certain embodiments of the invention may comprise any renewable oil product made by an upgrading process comprising any of the processes described above, for example, a BTEX-rich stream for a petrochemical plant or other uses, or gasoline and/or other fuels.
  • ranges of temperature, holding time/residence time/LHSV, gas to oil ratios, BET surface in m2/g, pore sizes in Angstroms, pressure in psig, and/or other ranges of variables are given for many embodiments of the invention. It should be understood that the ranges are intended to include all sub-ranges, and to include each incremental amount of temperature, holding time/residence time/LHSV, gas to oil ratios, BET surface in m2/g, pore sizes in Angstroms, pressure in psig, and other variable, within each broad range given.
  • certain embodiments may include any of the following sub-ranges or any pressure within any of the following sub-ranges: 1000-1050, 1050-1100, 1100-1150, 1150-1200, 1200-1250, 1250-1300, 1300-1350, 1350-1400, 1400-1450, 1450-1500, 1500-1550, 1550-1600, 1600-1650, 1650-1700, 1700-1750, 1750-1800, 1800-1850, 1850-1900, 1900-1950, and 1950-2000 psig.
  • broad ranges of 300-425, 300-450, and 350-555 degrees C. are mentioned, certain embodiments may include any temperature within any of these ranges, or any 10 degrees C.
  • Examples of 10 degrees sub-ranges for the range of 300-450 degrees C. are: 300-310, 310-320, 320-330, 330-340, 340-350, 350-360, 360-370, 370-380, 380-390, 390-400, 400-410, 410-420, 420-430, 430-440, 440-450 degrees C. Examples of 10 degrees sub-ranges for the range of 350-555 degrees C.

Landscapes

  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Engineering & Computer Science (AREA)
  • Organic Chemistry (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Crystallography & Structural Chemistry (AREA)
  • Materials Engineering (AREA)
  • Catalysts (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
US13/996,425 2010-12-24 2011-12-27 Production of aromatics from renewable resources Abandoned US20130289324A1 (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
US13/996,425 US20130289324A1 (en) 2010-12-24 2011-12-27 Production of aromatics from renewable resources

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
US201061427160P 2010-12-24 2010-12-24
US13/996,425 US20130289324A1 (en) 2010-12-24 2011-12-27 Production of aromatics from renewable resources
PCT/US2011/067444 WO2012088546A1 (en) 2010-12-24 2011-12-27 Production of aromatics from renewable resources

Publications (1)

Publication Number Publication Date
US20130289324A1 true US20130289324A1 (en) 2013-10-31

Family

ID=46314518

Family Applications (1)

Application Number Title Priority Date Filing Date
US13/996,425 Abandoned US20130289324A1 (en) 2010-12-24 2011-12-27 Production of aromatics from renewable resources

Country Status (8)

Country Link
US (1) US20130289324A1 (es)
EP (1) EP2655559A4 (es)
CN (1) CN103384714A (es)
AU (1) AU2011348031A1 (es)
CA (1) CA2819172A1 (es)
MX (1) MX2013007004A (es)
SG (1) SG190965A1 (es)
WO (1) WO2012088546A1 (es)

Cited By (25)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20140316176A1 (en) * 2013-04-19 2014-10-23 Albemarie Corporation Deep Deoxygenation of Biocrudes Utilizing Fluidized Catalytic Cracking Co-Processing with Hydrocarbon Feedstocks
CN105112095A (zh) * 2015-09-10 2015-12-02 长沙理工大学 一种生物基燃油碱性氮化物和磷脂脱除的方法
US9321703B2 (en) 2014-01-08 2016-04-26 Siluria Technologies, Inc. Ethylene-to-liquids systems and methods
US9328297B1 (en) 2015-06-16 2016-05-03 Siluria Technologies, Inc. Ethylene-to-liquids systems and methods
US9527054B2 (en) 2014-05-09 2016-12-27 Uop Llc Apparatuses and methods for cracking hydrocarbons
US9598328B2 (en) 2012-12-07 2017-03-21 Siluria Technologies, Inc. Integrated processes and systems for conversion of methane to multiple higher hydrocarbon products
WO2018058172A1 (en) * 2016-09-29 2018-04-05 Licella Pty Ltd Biooil refining methods
US20180148654A1 (en) * 2015-08-06 2018-05-31 Uop Llc Process for reconfiguring existing treating units in a refinery
US10787400B2 (en) 2015-03-17 2020-09-29 Lummus Technology Llc Efficient oxidative coupling of methane processes and systems
US10793490B2 (en) 2015-03-17 2020-10-06 Lummus Technology Llc Oxidative coupling of methane methods and systems
US10829424B2 (en) 2014-01-09 2020-11-10 Lummus Technology Llc Oxidative coupling of methane implementations for olefin production
US10836689B2 (en) 2017-07-07 2020-11-17 Lummus Technology Llc Systems and methods for the oxidative coupling of methane
US10870611B2 (en) 2016-04-13 2020-12-22 Lummus Technology Llc Oxidative coupling of methane for olefin production
US10927056B2 (en) 2013-11-27 2021-02-23 Lummus Technology Llc Reactors and systems for oxidative coupling of methane
US10960343B2 (en) 2016-12-19 2021-03-30 Lummus Technology Llc Methods and systems for performing chemical separations
US11001543B2 (en) 2015-10-16 2021-05-11 Lummus Technology Llc Separation methods and systems for oxidative coupling of methane
US11001542B2 (en) 2017-05-23 2021-05-11 Lummus Technology Llc Integration of oxidative coupling of methane processes
US11008265B2 (en) 2014-01-09 2021-05-18 Lummus Technology Llc Reactors and systems for oxidative coupling of methane
JP2021113336A (ja) * 2014-07-01 2021-08-05 アネロテック・インコーポレイテッドAnellotech, Inc. 触媒急速熱分解プロセスによってバイオマスを低硫黄、低窒素、及び低オレフィン含有量のｂｔｘに転換するためのプロセス
US11186529B2 (en) 2015-04-01 2021-11-30 Lummus Technology Llc Advanced oxidative coupling of methane
US11242298B2 (en) 2012-07-09 2022-02-08 Lummus Technology Llc Natural gas processing and systems
US11254626B2 (en) 2012-01-13 2022-02-22 Lummus Technology Llc Process for separating hydrocarbon compounds
US11299680B1 (en) * 2020-12-01 2022-04-12 Chevron U.S.A. Inc. Catalytic cracking of glyceride oils with phosphorus-containing ZSM-5 light olefins additives
US20230312434A1 (en) * 2020-08-20 2023-10-05 Petróleo Brasileiro S.A. - Petrobras Process for obtaining aromatics and aromatic stream
US12227466B2 (en) 2021-08-31 2025-02-18 Lummus Technology Llc Methods and systems for performing oxidative coupling of methane

Families Citing this family (15)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP3252128B1 (en) 2006-04-03 2019-01-02 Pharmatherm Chemicals Inc. Thermal extraction method for producing a taxane extract
US20110284359A1 (en) 2010-05-20 2011-11-24 Uop Llc Processes for controlling afterburn in a reheater and for controlling loss of entrained solid particles in combustion product flue gas
US8499702B2 (en) 2010-07-15 2013-08-06 Ensyn Renewables, Inc. Char-handling processes in a pyrolysis system
US9441887B2 (en) 2011-02-22 2016-09-13 Ensyn Renewables, Inc. Heat removal and recovery in biomass pyrolysis
US9347005B2 (en) 2011-09-13 2016-05-24 Ensyn Renewables, Inc. Methods and apparatuses for rapid thermal processing of carbonaceous material
US10400175B2 (en) 2011-09-22 2019-09-03 Ensyn Renewables, Inc. Apparatuses and methods for controlling heat for rapid thermal processing of carbonaceous material
US10041667B2 (en) 2011-09-22 2018-08-07 Ensyn Renewables, Inc. Apparatuses for controlling heat for rapid thermal processing of carbonaceous material and methods for the same
SG11201401011VA (en) * 2011-10-28 2014-08-28 Sapphire Energy Inc Processes for upgrading algae oils and products thereof
US9109177B2 (en) 2011-12-12 2015-08-18 Ensyn Renewables, Inc. Systems and methods for renewable fuel
US9670413B2 (en) 2012-06-28 2017-06-06 Ensyn Renewables, Inc. Methods and apparatuses for thermally converting biomass
TWI645026B (zh) 2013-06-26 2018-12-21 安信再生公司 可再生燃料之系統及方法
EP3337966B1 (en) 2015-08-21 2021-12-15 Ensyn Renewables, Inc. Liquid biomass heating system
WO2018125753A1 (en) 2016-12-29 2018-07-05 Ensyn Renewables, Inc. Demetallization of liquid biomass
EP4520804A1 (de) * 2023-09-06 2025-03-12 OMV Downstream GmbH Verfahren zur verarbeitung eines silizium-haltigen kohlenwasserstoffstroms
EP4520803A1 (de) * 2023-09-06 2025-03-12 OMV Downstream GmbH Verfahren zur verarbeitung eines phosphor-haltigen kohlenwasserstoffstroms

Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6211104B1 (en) * 1997-10-15 2001-04-03 China Petrochemical Corporation Catalyst for catalytic pyrolysis process for the production of light olefins and the preparation thereof
US20090227823A1 (en) * 2008-03-04 2009-09-10 University Of Massachusetts Catalytic pyrolysis of solid biomass and related biofuels, aromatic, and olefin compounds

Family Cites Families (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
BRPI0502577B1 (pt) * 2005-07-07 2015-11-03 Petroleo Brasileiro Sa processo de craqueamento catalítico para produção de diesel a partir de óleos vegetais
ITMI20052303A1 (it) * 2005-12-01 2007-06-02 Aser S R L Processo per la produzione di esteri da oli vegetali o grassi animali con l'impiego di catalizzatori a base di composti di vanadio
CN101679874B (zh) 2007-03-08 2013-10-23 维仁特公司 由氧化烃合成液体燃料和化学品
CL2008002681A1 (es) * 2007-09-18 2009-10-16 The Univ Of Tulsa Proceso de craqueo catalítico de aceite de algas por contacto con composición catalítica que comprende un tamiz molecular de zeolita con anillos de 12 miembros.
FR2932811B1 (fr) * 2008-06-24 2010-09-03 Inst Francais Du Petrole Procede de conversion de charges issues de sources renouvelables en bases carburants gazoles de bonne qualite mettant en oeuvre un catalyseur de type zeolithique
WO2010002886A1 (en) * 2008-06-30 2010-01-07 Kior, Inc. Producing fuel and speciality chemicals from biomass containing triglycerides and cellulose
CN101684056B (zh) * 2008-09-27 2013-04-24 中国石油化工股份有限公司 一种动植物油脂制芳烃的方法
TW201028464A (en) * 2008-12-08 2010-08-01 Grace W R & Co Process of cracking biofeeds using high zeolite to matrix surface area catalysts
KR101140340B1 (ko) * 2009-11-17 2012-05-03 한국에너지기술연구원 생물체에서 유래된 지질과 하이드로탈사이트를 이용한 탄화수소 생산방법.
US8575408B2 (en) * 2010-03-30 2013-11-05 Uop Llc Use of a guard bed reactor to improve conversion of biofeedstocks to fuel

Patent Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6211104B1 (en) * 1997-10-15 2001-04-03 China Petrochemical Corporation Catalyst for catalytic pyrolysis process for the production of light olefins and the preparation thereof
US20090227823A1 (en) * 2008-03-04 2009-09-10 University Of Massachusetts Catalytic pyrolysis of solid biomass and related biofuels, aromatic, and olefin compounds

Cited By (46)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11254626B2 (en) 2012-01-13 2022-02-22 Lummus Technology Llc Process for separating hydrocarbon compounds
US11242298B2 (en) 2012-07-09 2022-02-08 Lummus Technology Llc Natural gas processing and systems
US10183900B2 (en) 2012-12-07 2019-01-22 Siluria Technologies, Inc. Integrated processes and systems for conversion of methane to multiple higher hydrocarbon products
US11168038B2 (en) 2012-12-07 2021-11-09 Lummus Technology Llc Integrated processes and systems for conversion of methane to multiple higher hydrocarbon products
US9598328B2 (en) 2012-12-07 2017-03-21 Siluria Technologies, Inc. Integrated processes and systems for conversion of methane to multiple higher hydrocarbon products
US10787398B2 (en) 2012-12-07 2020-09-29 Lummus Technology Llc Integrated processes and systems for conversion of methane to multiple higher hydrocarbon products
US20140316176A1 (en) * 2013-04-19 2014-10-23 Albemarie Corporation Deep Deoxygenation of Biocrudes Utilizing Fluidized Catalytic Cracking Co-Processing with Hydrocarbon Feedstocks
US9944859B2 (en) * 2013-04-19 2018-04-17 Phillips 66 Company Albermarle Corporation Deep deoxygenation of biocrudes utilizing fluidized catalytic cracking co-processing with hydrocarbon feedstocks
US10647923B2 (en) * 2013-04-19 2020-05-12 Phillips 66 Company Deep deoxygenation of biocrudes utilizing fluidized catalytic cracking co-processing with hydrocarbon feedstocks
US20180187090A1 (en) * 2013-04-19 2018-07-05 Phillips 66 Company Deep Deoxygenation of Biocrudes Utilizing Fluidized Catalytic Cracking Co-Processing with Hydrocarbon Feedstocks
US11407695B2 (en) 2013-11-27 2022-08-09 Lummus Technology Llc Reactors and systems for oxidative coupling of methane
US10927056B2 (en) 2013-11-27 2021-02-23 Lummus Technology Llc Reactors and systems for oxidative coupling of methane
US10894751B2 (en) 2014-01-08 2021-01-19 Lummus Technology Llc Ethylene-to-liquids systems and methods
US10301234B2 (en) 2014-01-08 2019-05-28 Siluria Technologies, Inc. Ethylene-to-liquids systems and methods
US9321703B2 (en) 2014-01-08 2016-04-26 Siluria Technologies, Inc. Ethylene-to-liquids systems and methods
US11254627B2 (en) 2014-01-08 2022-02-22 Lummus Technology Llc Ethylene-to-liquids systems and methods
US9321702B2 (en) 2014-01-08 2016-04-26 Siluria Technologies, Inc. Ethylene-to-liquids systems and methods
US9512047B2 (en) 2014-01-08 2016-12-06 Siluria Technologies, Inc. Ethylene-to-liquids systems and methods
US10829424B2 (en) 2014-01-09 2020-11-10 Lummus Technology Llc Oxidative coupling of methane implementations for olefin production
US11208364B2 (en) 2014-01-09 2021-12-28 Lummus Technology Llc Oxidative coupling of methane implementations for olefin production
US11008265B2 (en) 2014-01-09 2021-05-18 Lummus Technology Llc Reactors and systems for oxidative coupling of methane
US9527054B2 (en) 2014-05-09 2016-12-27 Uop Llc Apparatuses and methods for cracking hydrocarbons
AU2020200798B2 (en) * 2014-07-01 2022-03-24 Anellotech, Inc. Processes for converting biomass to BTX with low sulfur, nitrogen and olefin content via a catalytic fast pyrolysis process
JP7368415B2 (ja) 2014-07-01 2023-10-24 アネロテック・インコーポレイテッド 触媒急速熱分解プロセスによってバイオマスを低硫黄、低窒素、及び低オレフィン含有量のｂｔｘに転換するためのプロセス
JP2021113336A (ja) * 2014-07-01 2021-08-05 アネロテック・インコーポレイテッドAnellotech, Inc. 触媒急速熱分解プロセスによってバイオマスを低硫黄、低窒素、及び低オレフィン含有量のｂｔｘに転換するためのプロセス
US11084988B2 (en) * 2014-07-01 2021-08-10 Anellotech, Inc. Processes for converting biomass to BTX with low sulfur, nitrogen and olefin content via a catalytic fast pyrolysis process
US10787400B2 (en) 2015-03-17 2020-09-29 Lummus Technology Llc Efficient oxidative coupling of methane processes and systems
US10793490B2 (en) 2015-03-17 2020-10-06 Lummus Technology Llc Oxidative coupling of methane methods and systems
US11542214B2 (en) 2015-03-17 2023-01-03 Lummus Technology Llc Oxidative coupling of methane methods and systems
US11186529B2 (en) 2015-04-01 2021-11-30 Lummus Technology Llc Advanced oxidative coupling of methane
US10865165B2 (en) 2015-06-16 2020-12-15 Lummus Technology Llc Ethylene-to-liquids systems and methods
US9328297B1 (en) 2015-06-16 2016-05-03 Siluria Technologies, Inc. Ethylene-to-liquids systems and methods
US11008520B2 (en) * 2015-08-06 2021-05-18 Uop Llc Process for reconfiguring existing treating units in a refinery
US20180148654A1 (en) * 2015-08-06 2018-05-31 Uop Llc Process for reconfiguring existing treating units in a refinery
CN105112095A (zh) * 2015-09-10 2015-12-02 长沙理工大学 一种生物基燃油碱性氮化物和磷脂脱除的方法
US11001543B2 (en) 2015-10-16 2021-05-11 Lummus Technology Llc Separation methods and systems for oxidative coupling of methane
US10870611B2 (en) 2016-04-13 2020-12-22 Lummus Technology Llc Oxidative coupling of methane for olefin production
US11505514B2 (en) 2016-04-13 2022-11-22 Lummus Technology Llc Oxidative coupling of methane for olefin production
WO2018058172A1 (en) * 2016-09-29 2018-04-05 Licella Pty Ltd Biooil refining methods
US10960343B2 (en) 2016-12-19 2021-03-30 Lummus Technology Llc Methods and systems for performing chemical separations
US11001542B2 (en) 2017-05-23 2021-05-11 Lummus Technology Llc Integration of oxidative coupling of methane processes
US10836689B2 (en) 2017-07-07 2020-11-17 Lummus Technology Llc Systems and methods for the oxidative coupling of methane
US20230312434A1 (en) * 2020-08-20 2023-10-05 Petróleo Brasileiro S.A. - Petrobras Process for obtaining aromatics and aromatic stream
US12540106B2 (en) * 2020-08-20 2026-02-03 Petróleo Brasileiro S.A.—Petrobras Process for obtaining aromatics and aromatic stream
US11299680B1 (en) * 2020-12-01 2022-04-12 Chevron U.S.A. Inc. Catalytic cracking of glyceride oils with phosphorus-containing ZSM-5 light olefins additives
US12227466B2 (en) 2021-08-31 2025-02-18 Lummus Technology Llc Methods and systems for performing oxidative coupling of methane

Also Published As

Publication number Publication date
MX2013007004A (es) 2013-12-06
EP2655559A1 (en) 2013-10-30
SG190965A1 (en) 2013-07-31
WO2012088546A1 (en) 2012-06-28
CA2819172A1 (en) 2012-06-28
AU2011348031A1 (en) 2013-06-27
AU2011348031A2 (en) 2013-08-01
EP2655559A4 (en) 2014-07-23
CN103384714A (zh) 2013-11-06

Similar Documents

Publication Publication Date Title
US20130289324A1 (en) Production of aromatics from renewable resources
AU2017216346B2 (en) Chemicals and fuel blendstocks by a catalytic fast pyrolysis process
Choi et al. The direct production of jet-fuel from non-edible oil in a single-step process
Shimada et al. Deoxygenation of triglycerides by catalytic cracking with enhanced hydrogen transfer activity
US8513476B2 (en) Process for producing light olefins from a feed containing triglycerides
JP2009526114A (ja) 流動接触分解方法
JP2015506397A (ja) 留出生成物及び／又はｃ２〜ｃ４オレフィンを製造する方法
SG181433A1 (en) Process and system to convert light olefins to diesel and other distillates
Shimada et al. Catalytic cracking of wax esters extracted from Euglena gracilis for hydrocarbon fuel production
US20240018070A1 (en) A method for producing a cracking product fraction comprising propylene, c4 olefins, or both
EP2771433B1 (en) Processes for upgrading algae oils and products thereof
KR20230069226A (ko) 바이오계 탄화수소의 제조를 위한 공정
Chen et al. Comparison of canola oil conversion over MFI, BEA, and FAU
US20180010052A1 (en) H2 and bio-fuels production from renewable feedstocks
Bielansky Alternative feedstocks in fluid catalytic cracking
CN107964419A (zh) 一种生物油脂的加工工艺
JP7750955B2 (ja) リン含有ｚｓｍ－５軽質オレフィン添加剤を用いたグリセリド油の接触分解
US11680210B2 (en) Catalytic cracking of glyceride oils with deactivated phosphorus-containing ZSM-5 light olefins additives

Legal Events

Date Code Title Description
AS Assignment

Owner name: SAPPHIRE ENERGY, INC., CALIFORNIA

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:GOODALL, BRIAN L;SAJKOWSKI, DANIEL J;SIGNING DATES FROM 20130528 TO 20130602;REEL/FRAME:030577/0610

Owner name: UNIVERSITY OF TULSA, OKLAHOMA

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:PRICE, GEOFFREY L;REEL/FRAME:030577/0137

Effective date: 20130524

AS Assignment

Owner name: SAPPHIRE ENERGY, INC., CALIFORNIA

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:GOODALL, BRIAN L;SAJKOWSKI, DANIEL J;SIGNING DATES FROM 20130528 TO 20130602;REEL/FRAME:030660/0245

Owner name: UNIVERSITY OF TULSA, OKLAHOMA

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:PRICE, GEOFFREY L;REEL/FRAME:030660/0358

Effective date: 20130524

STCB Information on status: application discontinuation

Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION