WO2012118511A1 - Gazéification de matière carbonée - Google Patents

Gazéification de matière carbonée Download PDF

Info

Publication number
WO2012118511A1
WO2012118511A1 PCT/US2011/027070 US2011027070W WO2012118511A1 WO 2012118511 A1 WO2012118511 A1 WO 2012118511A1 US 2011027070 W US2011027070 W US 2011027070W WO 2012118511 A1 WO2012118511 A1 WO 2012118511A1
Authority
WO
WIPO (PCT)
Prior art keywords
reactor
methane
coal
water
gasifier
Prior art date
Application number
PCT/US2011/027070
Other languages
English (en)
Inventor
Daniel Steele
Robert B. Wilson
Ripudaman Malhotra
Brian Adair
Original Assignee
Sri International
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 Sri International filed Critical Sri International
Priority to EP11860093.1A priority Critical patent/EP2681292A4/fr
Priority to CN201180070638.7A priority patent/CN103842476A/zh
Priority to PCT/US2011/027070 priority patent/WO2012118511A1/fr
Publication of WO2012118511A1 publication Critical patent/WO2012118511A1/fr

Links

Classifications

    • C—CHEMISTRY; METALLURGY
    • C07—ORGANIC CHEMISTRY
    • C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
    • C07C29/00—Preparation of compounds having hydroxy or O-metal groups bound to a carbon atom not belonging to a six-membered aromatic ring
    • C07C29/15—Preparation of compounds having hydroxy or O-metal groups bound to a carbon atom not belonging to a six-membered aromatic ring by reduction of oxides of carbon exclusively
    • C07C29/151—Preparation of compounds having hydroxy or O-metal groups bound to a carbon atom not belonging to a six-membered aromatic ring by reduction of oxides of carbon exclusively with hydrogen or hydrogen-containing gases
    • C07C29/1516—Multisteps
    • C07C29/1518—Multisteps one step being the formation of initial mixture of carbon oxides and hydrogen for synthesis
    • 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
    • C10G2/00—Production of liquid hydrocarbon mixtures of undefined composition from oxides of carbon
    • C10G2/30—Production of liquid hydrocarbon mixtures of undefined composition from oxides of carbon from carbon monoxide with hydrogen
    • 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
    • C10G2/00—Production of liquid hydrocarbon mixtures of undefined composition from oxides of carbon
    • C10G2/30—Production of liquid hydrocarbon mixtures of undefined composition from oxides of carbon from carbon monoxide with hydrogen
    • C10G2/32—Production of liquid hydrocarbon mixtures of undefined composition from oxides of carbon from carbon monoxide with hydrogen with the use of catalysts
    • C10G2/33—Production of liquid hydrocarbon mixtures of undefined composition from oxides of carbon from carbon monoxide with hydrogen with the use of catalysts characterised by the catalyst used
    • C10G2/331—Production of liquid hydrocarbon mixtures of undefined composition from oxides of carbon from carbon monoxide with hydrogen with the use of catalysts characterised by the catalyst used containing group VIII-metals
    • C10G2/332—Production of liquid hydrocarbon mixtures of undefined composition from oxides of carbon from carbon monoxide with hydrogen with the use of catalysts characterised by the catalyst used containing group VIII-metals of the iron-group
    • 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
    • C10G2/00—Production of liquid hydrocarbon mixtures of undefined composition from oxides of carbon
    • C10G2/50—Production of liquid hydrocarbon mixtures of undefined composition from oxides of carbon from carbon dioxide with hydrogen
    • 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
    • C10G3/50—Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids in the presence of hydrogen, hydrogen donors or hydrogen generating compounds
    • C10G3/52—Hydrogen in a special composition or from a special source
    • 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
    • C10G50/00—Production of liquid hydrocarbon mixtures from lower carbon number hydrocarbons, e.g. by oligomerisation
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J3/00—Production of combustible gases containing carbon monoxide from solid carbonaceous fuels
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10K—PURIFYING OR MODIFYING THE CHEMICAL COMPOSITION OF COMBUSTIBLE GASES CONTAINING CARBON MONOXIDE
    • C10K1/00—Purifying combustible gases containing carbon monoxide
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10K—PURIFYING OR MODIFYING THE CHEMICAL COMPOSITION OF COMBUSTIBLE GASES CONTAINING CARBON MONOXIDE
    • C10K1/00—Purifying combustible gases containing carbon monoxide
    • C10K1/002—Removal of contaminants
    • C10K1/003—Removal of contaminants of acid contaminants, e.g. acid gas removal
    • C10K1/004—Sulfur containing contaminants, e.g. hydrogen sulfide
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10K—PURIFYING OR MODIFYING THE CHEMICAL COMPOSITION OF COMBUSTIBLE GASES CONTAINING CARBON MONOXIDE
    • C10K1/00—Purifying combustible gases containing carbon monoxide
    • C10K1/002—Removal of contaminants
    • C10K1/007—Removal of contaminants of metal compounds
    • 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
    • C10G2300/4081—Recycling aspects
    • 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
    • C10G2300/80—Additives
    • C10G2300/805—Water
    • 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
    • C10G2400/20—C2-C4 olefins
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J2300/00—Details of gasification processes
    • C10J2300/09—Details of the feed, e.g. feeding of spent catalyst, inert gas or halogens
    • C10J2300/0913—Carbonaceous raw material
    • C10J2300/093—Coal
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J2300/00—Details of gasification processes
    • C10J2300/09—Details of the feed, e.g. feeding of spent catalyst, inert gas or halogens
    • C10J2300/0953—Gasifying agents
    • C10J2300/0966—Hydrogen
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J2300/00—Details of gasification processes
    • C10J2300/09—Details of the feed, e.g. feeding of spent catalyst, inert gas or halogens
    • C10J2300/0983—Additives
    • C10J2300/0986—Catalysts
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J2300/00—Details of gasification processes
    • C10J2300/16—Integration of gasification processes with another plant or parts within the plant
    • C10J2300/164—Integration of gasification processes with another plant or parts within the plant with conversion of synthesis gas
    • C10J2300/1656—Conversion of synthesis gas to chemicals
    • C10J2300/1659—Conversion of synthesis gas to chemicals to liquid hydrocarbons
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J2300/00—Details of gasification processes
    • C10J2300/16—Integration of gasification processes with another plant or parts within the plant
    • C10J2300/164—Integration of gasification processes with another plant or parts within the plant with conversion of synthesis gas
    • C10J2300/1656—Conversion of synthesis gas to chemicals
    • C10J2300/1665—Conversion of synthesis gas to chemicals to alcohols, e.g. methanol or ethanol
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J2300/00—Details of gasification processes
    • C10J2300/18—Details of the gasification process, e.g. loops, autothermal operation
    • C10J2300/1807—Recycle loops, e.g. gas, solids, heating medium, water
    • 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
    • Y02P20/00—Technologies relating to chemical industry
    • Y02P20/10—Process efficiency
    • 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
    • Y02P20/00—Technologies relating to chemical industry
    • Y02P20/10—Process efficiency
    • Y02P20/129—Energy recovery, e.g. by cogeneration, H2recovery or pressure recovery turbines
    • 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
    • Y02P30/40—Ethylene production

Definitions

  • Coal liquefaction methods also known as coal-to-liquid (CTL) methods, refer to the process of converting coal into hydrocarbon liquids.
  • the hydrocarbon products are typically used as transportation fuels, and include diesel fuels and jet fuels.
  • CTL methods coal gasification is a companion process that plays an important initial role by converting the coal to syngas, which is a mixture of H 2 and CO.
  • syngas which is a mixture of H 2 and CO.
  • coal gasification is carried out in a gasification reactor into which coal is injected either by a gas-blown system or water slurry.
  • Gas- blown systems typically use air to blow the coal into the hot zone in the gasifier.
  • the syngas product is converted to transportation fuels via one of several methods (for example, in the Fischer- Tropsch process) depending on a variety of factors.
  • a process for liquefying a carbonaceous material comprising: (a) combining the carbonaceous material with methane and water in a gasification reactor to produce H 2 and CO; (b) combining the H 2 and CO from (a) with a catalyst in a methanol reactor to produce methanol; (c) combining the methanol from (b) with a catalyst in a reactor to form hydrocarbons and water; and (d) recycling the water formed in (c) to the gasification reactor to react with additional carbonaceous material and methane.
  • the carbonaceous material is coal.
  • the gasification reactor is supplied with heat energy from an electric heat producing means.
  • the hydrocarbons comprise propylene
  • the process further comprises isolating the propylene and combining the propylene with a catalyst in a reactor to form
  • hydrocarbons in the molecular weight range of transportation fuels are hydrocarbons in the molecular weight range of transportation fuels.
  • the hydrocarbons are in the molecular weight range of transportation fuels.
  • the coal/methane ratio is between about 1.75 and about 20.
  • At least 75 % of the methane and at least 75% of the coal is converted to CO or C0 2 and water in the gasification reactor.
  • at least a portion of the water in (a) is in the form of steam, and wherein the steam is added to the gasification reactor at a temperature greater than about 500 °C.
  • the H 2 and CO product from (a) has a CO/H 2 ratio in the range of 0.35/1 to 2.5/1.
  • the process is water neutral.
  • the contents of the gasification reactor are maintained above an average temperature of at least 1200 °C.
  • an oxidized catalyst is further added to the gasification reactor, and wherein the oxidized catalyst reacts with a portion of the methane or coal in the gasification reactor to generate heat.
  • the methane is provided in the form of a gas stream and wherein the coal is entrained in the methane gas stream.
  • the invention provides a process for converting a carbonaceous material to transportation fuel, the process comprising combining the carbonaceous material, methane, and water at elevated temperature in a gasification reactor to produce CO and H 2 in a CO/H 2 ratio of between 0.35/1 and 2.5/1, wherein one or more of the carbonaceous material, methane, and water is heated using an electric heat generating means, and wherein the CO and H 2 product of the gasification reactor has an adjustable ratio and is used to prepare a transportation fuel.
  • the CO and H 2 products from the above- described processes are converted to methanol in a methanol reactor.
  • C0 2 is present in the stream that is converted to methanol, such that the overall processes consume C0 2 .
  • the C0 2 may be obtained from any suitable source, including environmental C0 2 as well as products from other processes described herein (e.g. conversion of methane and carbonaceous material to syngas).
  • the invention provides a gasification reactor for converting a carbonaceous material to syngas comprising: (a) a reactor chamber; (b) means for supplying the carbonaceous material to the reactor chamber; (c) means for supplying methane to the reactor chamber; (d) means for supplying water to the reactor chamber; and (e) means for supplying electricity- generated heat energy to the carbonaceous material, methane, water, or combination thereof.
  • the carbonaceous material is coal.
  • the reactor chamber of the gasification reactor has a volume of at least 1.0 m .
  • the methods further comprise means for supplying to the gasification reactor chamber an oxidized catalyst suitable to oxidize methane and generate heat.
  • the water is supplied as high pressure and high temperature steam.
  • the means for supplying water is configured to take water from a propylene reactor that produces propylene and water from methanol.
  • the invention provides a liquefaction system for converting a carbonaceous material to a hydrocarbon fuel, the liquefaction system comprising: (a) a gasification reactor; (b) a purification stage configured to receive an output from the gasification reactor; (c) a methanol reactor configured to receive an output from the purification stage; (d) a propylene reactor configured to receive an output from the methanol reactor; and (e) a fuel reactor configured to receive an output from the propylene reactor, wherein the gasification reactor has an inlet for receiving an entrained flow of a carbonaceous material in gaseous methane and an inlet for receiving steam.
  • the gasification reactor is configured to receive electrical energy, and comprises a means for converting the electrical energy to heat energy.
  • FIG. 1 a block diagram is provided that illustrates one embodiment of the invention.
  • Coal, steam, and methane enter a gasifier and are converted to a syngas output that is converted downstream to a transportation fuel.
  • FIG. 2 a block diagram provides a more detailed description of a process according to the invention for preparing transportation fuel from coal and methane.
  • FIG. 3 there is provided a schematic diagram and equation illustrating the mass balance of a coal-conversion system according to the invention, as well as a graph showing heat of reaction as a function of 0 2 /coal ratio for various types of coal.
  • FIG. 3a provides a schematic of the inputs and outputs of a coal- conversion system.
  • FIG. 3b provides a graph showing heats of reaction for peat, lignite, bituminous, and anthracite coal.
  • FIG. 3c provides an equation showing the mass balance of the inputs and outputs of the coal-conversion system of FIG. 3a.
  • the invention provides methods and apparatus for producing hydrocarbon liquids from a carbonaceous material.
  • the hydrocarbon liquids are transportation fuels.
  • the invention provides methods and apparatus for producing syngas from a carbonaceous material.
  • the syngas product has a CO/H 2 ratio that is suitable for production of methanol from the syngas.
  • the invention provides methods and apparatus for producing methanol from a carbonaceous material via a syngas intermediate.
  • the invention provides methods and apparatus for producing propylene from a carbonaceous material.
  • the invention provides methods and apparatus for producing transportation fuels from a carbonaceous material. Such methods proceed via a syngas intermediate, may further involve a methanol intermediate, and may further involve a propylene intermediate.
  • the methods and apparatus of the invention are water neutral or water producing.
  • the invention provides methods and apparatus for producing transportation fuels from a carbonaceous material wherein the methods do not consume water.
  • the invention provides methods and apparatus for producing transportation fuels from a carbonaceous material wherein the methods are C0 2 neutral or consume C0 2 .
  • any C0 2 that is produced in the conversion of the carbonaceous material to syngas is consumed in a subsequent methanol-conversion step (i.e. the C0 2 is converted to methanol downstream from the syngas production).
  • the invention provides methods and apparatus for producing transportation fuels from a
  • the invention provides methods and apparatus for producing transportation fuels from a carbonaceous material wherein the methods are both water and C0 2 neutral, or produce water and consume C0 2 .
  • the invention provides methods and apparatus for operating a coal gasification reactor supplied with electrically-generated heat energy.
  • the invention provides methods and apparatus for producing transportation fuels from a carbonaceous material wherein little or no C0 2 is generated by the net process.
  • coal is used as an exemplary
  • the methods and apparatus of the invention involve reacting coal inside a gasification reactor.
  • the gasification reactor (also referred to herein as a "gasifier”) comprises inlet ports and outlet ports that allow the reactants to enter and the products to exit.
  • the gasification reactor further comprises a reaction chamber within which the reactants are allowed to react.
  • the gasification reactor may further comprise additional elements such as insulation, sensors, pollution control measures, and the like.
  • the gasifier comprises: a reactor chamber; means for supplying coal to the reactor chamber; means for supplying methane to the reactor chamber; means for supplying water to the reactor chamber; and means for supplying heat energy to the coal, methane, water, or a combination thereof.
  • a means for supplying any of the abovementioned components may comprise one or more conduits connected to a source of the material to be supplied.
  • the source may be a reservoir of virgin feedstock, or may be a downstream process that has one of the reactants as an output (and which output is captured and recycled to the gasifier).
  • reactants refers to one or more materials that are supplied to the gasifier (e.g., coal, methane, water, etc.).
  • the gasifier typically further comprises one or more means for extracting a reaction product from the gasifier.
  • such means comprises one or more outlet ports in communication with conduits.
  • the outlet conduit or outlet port of the gasifier comprises a means for purifying the output stream (e.g., filters, scrubbers, etc.).
  • the reaction chamber of the gasification reactor has a volume greater than 0.5 m 3 , or greater than 1.0 m 3 , or greater than 5.0 m 3 , or greater than 10 m 3 , or greater than 20 m 3.
  • the reaction chamber of the gasification reactor is of a size suitable for commercial-scale gasification of coal.
  • commercial-scale is meant that the reactor is large enough to accommodate a throughput suitable for commercial production of gasification products.
  • the reaction chamber is larger than a laboratory-scale reaction chamber, which is typically significantly smaller than 1.0 m .
  • the input to the gasification reactor comprises a solid phase and a non-solid phase.
  • the solid phase comprises coal and may further comprise an optional catalyst.
  • the solid phase is in the form of particles as described below.
  • the non-solid phase comprises liquids and/or gases and in some embodiments the non-solid phase serves to entrain or fluidize the solid phase.
  • the non-solid phase is entirely gaseous.
  • the non-solid phase comprises a hydrogen source and an oxidant, more details of which are provided below.
  • the solid and non-solid phases are typically combined prior to entering the gasification reaction chamber, although in some embodiments they may be supplied separately.
  • the input to the gasifier is fed to the gasifier through one or more conduits that is/are in communication with one or more inlet ports of the gasifier.
  • each conduit is in communication with only one inlet port, although in other embodiments it may be desirable to split the flow through a conduit such that one or more input components enters the gasifier through more than one inlet port.
  • the solid phase comprises coal.
  • the coal is fed to the gasifier in the form of particles.
  • Such particles may be prepared from mined coal by any appropriate means, such as crushing or milling units commonly used in coal processing.
  • the coal particles fed to the gasifier may be characterized as having an average diameter within the range of between about 10 ⁇ to about 100 mm, or between about 0.1 mm to about 5 cm, or between about 1 mm to about 5 cm, or between about 1 cm to about 4 cm.
  • the average diameter may be greater than 10 ⁇ , or greater than 0.1 mm, or greater than 1 mm, or greater than 10 mm, or greater than 1.5 cm, or greater than 2 cm, or greater than 3 cm, or greater than 5 cm.
  • the diameter may be less than 10 cm, or less than 5 cm, or less than 4 cm, or less than 3 cm, or less than 2 cm, or less than 1 cm, or less than 0.5 cm, or less than 1 mm, or less than 0.1 mm.
  • average diameter refers to the widest dimension of the particles. When the coal is in the form of aggregated particles, the term “average diameter” refers to the widest dimension of the aggregates.
  • the solid phase is entrained by the non-solid phase - i.e., the solid phase is carried into and through the gasification reactor in a flow of gas and/or liquid.
  • the invention also applies, however, to embodiments wherein the solid phase is fluidized by the non-solid phase (i.e., the flow of gas/liquid is sufficient to separate the solid phase particles such that they behave as a fluid, but there is little or no bulk flow of the solid particles through the reactor), as well as to embodiments wherein the solid phase is maintained in a fixed bed (i.e., the solid phase remains immobile within the reactor chamber).
  • the solid and non-solid phases are supplied to the gasifier together, whereas in fluidized and fixed bed operations the solid phase and non- solid phase may be supplied to the reactor separately.
  • the solid phase is fed to the gasifier at a loading in the range of about 15 wt% to about 50 wt%, or about 25 wt% to about 40 wt %, wherein such percentages are measured with respect to the non-solid phase.
  • the solid phase loading may be greater than about 15%, or greater than about 20%, or greater than about 25%, or greater than about 30%, or greater than about 35%, or greater than about 40%, or greater than about 45%.
  • the solid phase loading may be less than about 50%, or less than about 45%, or less than about 40%, or less than about 35%, or less than about 30%, or less than about 25%, or less than about 20%.
  • the non-solid phase input to the gasifier typically comprises a hydrogen source and an oxidant.
  • the hydrogen source is a hydrocarbon.
  • suitable hydrocarbons are lower hydrocarbons, and particularly those that are gaseous under the reaction conditions of the gasifier such as methane, ethane, propane, butane, and the like.
  • the hydrogen source is methane.
  • the hydrogen source is not H 2 .
  • the hydrogen source is not H 2 produced by a water-gas shift reaction (i.e., CO + H 2 0 C0 2 + H 2 ).
  • H 2 is not obtained and added to the reactants separately from the hydrogen source.
  • small amounts of H 2 may be present in the hydrocarbon.
  • methane obtained from natural gas fields may contain H 2 , and this does not adversely affect the methods of the invention.
  • water may be present in the gasification reactor (as the oxidant - see below), water is not the hydrogen source.
  • the hydrogen atoms from the water are not converted to H 2 in the overall reaction.
  • the non-solid phase input to the gasifier further comprises an oxidant.
  • the oxidant is water, particularly in the form of steam.
  • the oxidant is not 0 2 or a gaseous mixture containing significant amounts of 0 2 (i.e., air). It will be appreciated, however, that water used as the oxidant may contain small amounts of 0 2 . Typically such small amounts need not be separated from the input water stream, as there is little or no adverse effect on the methods of the invention.
  • the input to the gasification reactor further comprises a catalyst.
  • a catalyst for example, an oxidation catalyst may be added to the input stream in order to partially oxidize the methane or carbonaceous material. Such oxidation can be used to provide heat to the gasifier. Such oxidation can also be used, in some embodiments, to obtain more complete conversion of the methane or coal reactants to CO and C0 2 .
  • Appropriate catalysts include, for example, robust catalyst such as the mixed metal oxides and transition metal catalysts that are used in the chemical process industry for selective oxidations (e.g., ammoxidation).
  • robust oxidation catalysts used in the emission control industry could be used, including such catalysts as "2-way catalysts" and others.
  • catalysts include alkali metal compounds such as alkali metal hydroxides.
  • Oxidation catalysts are typically available from commercial sources (e.g., Johnson Mathey or BASF) but may alternatively be synthesized in-house. Specific examples of catalysts include vanadium phosphorus oxide (VPO), ⁇ -FeOOH, and Bi 2 Mo06.
  • the coal is reacted in the gasifier with a hydrogen source and an oxidant at elevated temperature.
  • the hydrogen source is methane and the oxidant is steam.
  • the sole oxidant entering the gasifier is steam (i.e., no other oxidants such as oxygen, air, etc. are added).
  • the input flow to the gasifier comprises a slurry of coal particles in a non-solid (e.g., gaseous) phase
  • the output flow of the gasifier comprises gases only.
  • an output of the gasification reactor is a gaseous mixture that comprises CO and H 2 and is commonly referred to as syngas. Further disclosure describing the products of the gasifier is provided below.
  • the methods and apparatus of the invention further comprise a purification stage.
  • the purification stage is in fluid and/or gaseous communication with the gasifier.
  • the purification stage receives an output stream from the gasification reactor, such output being entirely gaseous or a mixture of gases and solid particles and/or liquids.
  • the syngas output of the gasifier may comprise one or more impurities in initial concentrations.
  • impurities include slag, mercury, ammonia, sulfur, sulfur-containing compounds such as H 2 S and COS, and ash.
  • Other impurities may be present depending on the type and source of coal that is used.
  • the syngas output of the gasifier may be sent to a purification stage.
  • the purification stage typically comprises scrubbers, catalysts, absorbents, or other means for purification, or combinations thereof.
  • Such methods of purification are generally known in the art, although purification methods currently or later developed may also be employed.
  • the purification stage comprises a reactor chamber within which one or more methods of purification (such as those previously mentioned) may be carried out on the gasifier output stream.
  • the purification stage does not comprise a separate reaction chamber, but rather comprises one or more purification means in-line with the conduits that carry the gasifier output stream out of the gasifier and to the next processing or storage stage.
  • the output of the purification stage is typically a gaseous product stream having one or more impurities at final concentrations, wherein the final concentration of one or more of the impurities is significantly reduced from the initial concentration.
  • the output of the purification stage in some embodiments is a syngas comprising one or more impurities (e.g., mercury, ash, etc. as described previously) at concentrations 10 times less, or 20 times less, or 50 times less, or 100 times less, or greater than 100 times less than the concentrations of those impurities at the output of the gasifier (i.e., the input of the purification stage). It will be
  • impurity levels of the "output" stream of the purification stage can be measured at the outlet of the reaction chamber.
  • impurity levels of the "output" stream of the purification stage can be measured at the point of input to the next stage in the process.
  • the methods and apparatus of the invention further comprise a methanol reactor.
  • the methanol reactor is configured to accept an output stream from the purification stage (when the purification stage is present) or from the gasifier directly (when the purification stage is not present). Thus, either directly or via the purification stage, the methanol reactor is in fluid/gaseous communication with the gasification reactor.
  • the methanol reactor is in fluid/gaseous communication with the gasification reactor such that fluid/gas products from the gasification reactor (e.g., syngas) can be transmitted to the methanol reactor, or such that fluid/gas products from the methanol reactor (e.g., isolated methane) can be transmitted to the gasification reactor.
  • fluid/gas products from the gasification reactor e.g., syngas
  • fluid/gas products from the methanol reactor e.g., isolated methane
  • two separate conduits connect the methanol reactor with the gasification reactor, such that fluids/gases can be transmitted in both directions.
  • the stream that enters the methanol reactor comprises syngas, and the methanol reactor converts the syngas to methanol.
  • the methanol reactor converts the syngas to methanol.
  • Various methods for conversion of syngas to methanol are known in the art, and may be used in conjunction with the present invention. It will be appreciated that the physical characteristics of the methanol reactor (e.g., size, number and type of inlet ports, etc.) as well as the operating conditions (e.g., temperature, pressure, etc.) will vary depending upon the method that is selected.
  • one method for forming methanol from syngas uses a catalyst (e.g., a mixture of copper, zinc oxide, and alumina), high temperatures (e.g., 250 °C), and high pressures (e.g., 5-10 MPa).
  • a catalyst e.g., a mixture of copper, zinc oxide, and alumina
  • high temperatures e.g., 250 °C
  • high pressures e.g., 5-10 MPa
  • the gasifier is operated at a sufficiently high pressure such that no additional compression is required to meet the methanol reactor's operating pressure.
  • the yield of methanol is thermodynamically limited, so the product must be removed in a high-pressure separation before the remaining syngas is recycled back to the methanol reactor.
  • the output of the methanol reactor comprises methanol.
  • the methanol is captured and transferred to the next stage in the process, which in some
  • the output of the methanol reactor further comprises residual methane.
  • residual methane in the output stream of the methanol reactor is separated from the main product stream and is recycled back to the gasifier.
  • the methanol reactor comprises a means for separating methanol from methane in the output of the reactor, and there is a fluid/gaseous connection that allows methane to be transmitted back to the gasifier.
  • the recycling pathway may comprise, in some embodiments, a compressor and/or heater that increases the pressure and/or temperature of the methane prior to being supplied to the gasifier.
  • the recycled methane stream may be combined with the virgin methane being supplied to the gasifier, or may be fed to the gasifier through a separate inlet port.
  • the output of the methanol reactor may further comprise hydrogen, as well as varying amounts of one or more additional components such as carbon monoxide, carbon dioxide, water/steam, inert gases, etc. Such components may be removed from the output stream by conventional methods as needed.
  • both the hydrogen and methane are separated from the methanol in the output stream of the methanol reactor.
  • the hydrogen and methane are recycled back to the gasifier.
  • only the methane is separated from the methanol reactor output stream and recycled back to the gasifier.
  • the input stream to the methanol reactor (i.e., the output stream from the gasifier or purification stage) additionally comprises carbon dioxide.
  • the output of the methanol reactor may further comprise water, and the water output may be captured and recycled to the gasifier if desired.
  • the syngas product from the gasifier has a ratio suitable for direct conversion to methanol. That is, it is not necessary to add additional hydrogen or to otherwise adjust the CO/H 2 ratio of the syngas product from the gasifier prior to the syngas entering the methanol reactor.
  • methanol is produced without the need for production of H 2 from a water-gas shift reaction.
  • the CO/H 2 ratio in the syngas product can be adjusted, for example, by adjusting the methane-to-coal ratio of the feedstock.
  • the methods and apparatus of the invention further comprise a propylene reactor.
  • the propylene reactor is configured to accept an output stream from the methanol reactor.
  • the propylene reactor is in
  • the stream that enters the propylene reactor comprises methanol and may further comprise water.
  • the propylene reactor converts the methanol to propylene.
  • a variety of methods are known for conversion of methanol to propylene, and these may be used in conjunction with the present invention.
  • An example is the Methanol-to-Propylene (MTP®) technology developed by Lurgi GmbH. It will be appreciated that the physical characteristics of the propylene reactor (e.g., size, number and type of inlet ports, etc.) will vary depending upon the method that is selected.
  • propylene is produced by a self-condensation of methanol followed by an elimination of water.
  • the output of the propylene reactor comprises a propylene stream.
  • Typical methods yield byproducts which include light paraffins, ethylene, butylene, and a small amount of fuel gas.
  • Water is also present in the output of the propylene reactor. After the reactor, a distillation is required to remove the water from the hydrocarbons. In some embodiments of the methods of the invention, the water is fed back to the slurry preparation and gasifier.
  • the output of the propylene reactor further comprises water, which is typically in the form of steam.
  • the steam may be separated from the output stream and recycled back to the gasification reactor.
  • the methods and apparatus of the invention further comprise a hydrocarbon reactor (which may also be referred to herein as a "diesel reactor”).
  • the hydrocarbon reactor is configured to accept an output stream from the propylene reactor.
  • the hydrocarbon reactor is in fluid/gaseous communication with the propylene reactor.
  • the stream that enters the hydrocarbon reactor comprises propylene, and the hydrocarbon reactor converts the propylene to heavier hydrocarbons.
  • the hydrocarbon reactor converts propylene to a hydrocarbon mixture suitable for use as a transportation fuel such as JP-8, kerosene, automotive gasoline, or the like. Additional components may be added to the hydrocarbon reactor as needed.
  • the output of the hydrocarbon reactor is JP- 8.
  • the output of the hydrocarbon reactor is suitable for use as automotive diesel fuel.
  • product hydrocarbons undergo a final distillation to recover the desired materials (e.g., JP-8 or other transportation fuels).
  • the residual hydrocarbons from such purifications can either be recycled back to the gasifier to be decomposed into syngas or sold as fuels.
  • the output from the methanol reactor can be directly fed to the hydrocarbon reactor (i.e., no propylene reactor is present).
  • the hydrocarbon reactor i.e., no propylene reactor is present.
  • the hydrocarbon reactor converts the methanol directly to hydrocarbon fuels.
  • Methods for converting methanol to hydrocarbon fuels are known, and any such process may be employed as desired.
  • using a zeolite catalyst methanol can be converted to hydrocarbon fuels such as gasoline fuel.
  • Inputs and materials used in the processes of the invention include a carbonaceous material, a hydrogen source, an oxidant, energy in the form of heat, and an optional catalyst. Each of these components is described in more detail in the following paragraphs.
  • the methods of the invention involve conversion of carbonaceous materials to hydrocarbon fuels.
  • Suitable carbonaceous materials include coal (lignite, sub-bituminous, bituminous, and anthracite), petroleum and petroleum residues (e.g., refining residues), oil shale, coke, peat, asphalts, or combinations thereof.
  • the carbonaceous material is a lower rank coal such as lignite, or sub-bituminous coal.
  • coal is used throughout this application as an exemplary carbonaceous material, but such use is merely for ease of description and is not intended to be limiting.
  • the product syngas composition is controlled by adding a hydrogen source to the gasifier. Because many sources of carbonaceous materials are rich in carbon but poor in hydrogen, the hydrogen source allows an increase in the ratio of H 2 /CO in the syngas output.
  • the hydrogen source is a hydrocarbon.
  • the hydrogen source is methane.
  • the methane may be obtained from any suitable source.
  • the methane may be coalbed methane (i.e., methane extracted from coal deposits), or methane from natural gas fields, or methane captured from solid waste landfills or from animal farms (e.g., methane from ruminant farms such as cattle belch methane).
  • the methane may also be recaptured methane generated downstream and recycled to the gasifier, as described herein.
  • Other sources of methane and any combination of the above-mentioned sources may be used.
  • the methanol reactor portion of the methods and apparatus of the invention convert syngas to methanol, and the output of the methanol reactor typically comprises a mixture of methanol and methane.
  • This methane may be separated from the methanol; accordingly, in some embodiments, the methane fed to the gasification further comprises methane recaptured and recycled from the output stream of the methanol reactor.
  • the hydrogen source is another hydrocarbon
  • the hydrogen source is a mixture of various compounds, such as natural gas or biogas. In some embodiments, the hydrogen source is a combination of one or more of the abovementioned sources, such as methane and biogas.
  • the methods disclosed herein use methane as a hydrogen source in converting coal to transportation fuels.
  • Methane is advantageous for a variety of reasons, including: (i) methane has a high H/C ratio; (ii) methane provides more energy to the process than traditional hydrogen sources such as water; (iii) coal bed methane and other sources of methane can be used; and (iv) the overall impact on the environment is positive if coal bed methane is captured and used (as opposed to venting it to the atmosphere during coal mining).
  • methane as the hydrogen source, a simplified mass balance for the overall process is as follows, where the overall process produces, rather than consumes, water:
  • the method is flexible because the methane feed rate may be varied (n) depending on the coal's hydrogen content (x).
  • hydrogen gas is added to the gasifier as a hydrogen source.
  • Hydrogen gas may be the sole hydrogen source, but more commonly it augments another hydrogen source such as methane.
  • the hydrogen may be obtained from any suitable source, such as a water gas shift (WGS) unit.
  • WGS water gas shift
  • the recycle stream from the methanol reactor contains hydrogen gas (in addition to methane) which is added to the gasifier.
  • up to 50% of the total volume of gases fed to the gasifier is hydrogen gas, although lesser amounts (such as up to 40%, or up to 30%, or up to 20%, or up to 10%) are also possible.
  • An oxidant is provided to the gasifier because the carbonaceous material and hydrogen source typically lack sufficient oxygen for conversion to CO and H 2 in suitable ratios.
  • the oxidant that is fed to the gasification reactor is water.
  • additional or alternative oxidizing agents e.g., an oxidizing catalyst, oxygen gas, etc.
  • water is the only oxidant fed to the gasifier.
  • the water is in the form of high temperature steam.
  • the steam may be added to the gasification reactor at a temperature of greater than 400 °C, or greater than 500 °C, or greater than 600 °C, or greater than 700 °C, or greater than 800 °C, or greater than 900 °C, or greater than 1000 °C, or greater than 1100 °C, or greater than 1200 °C, or greater than 1300 °C, or greater than 1400 °C.
  • the steam may be characterized as high pressure. For example, pressures of between about 200 psia and 1500 psia (or greater), or between 400 psia and 1000 psia, are suitable.
  • the pressure of the steam may be greater than 200 psia, or greater than 400 psia, or greater than 600 psia, or greater than 800 psia, or greater than 1000 psia, or greater than 1500 psia. Also for example, the pressure may be less than 1500 psia, or less than 1000 psia, or less than 500 psia.
  • the water oxidant may be obtained from any suitable source.
  • the water fed to the gasification reactor comprises, in whole or in part, water recycled (i.e., recaptured) from the propylene reactor. That is, the output of the propylene reactor, which comprises water and hydrocarbons, is separated into components and the resulting water is fed back to the gasification reactor.
  • the systems of the invention suitable for converting coal to hydrocarbon fuels are substantially water-neutral, meaning that there is little or no net loss or gain of water when all reactions are taken into account.
  • the systems of the invention are water positive, meaning that there is a net production of water when all reactions are taken into account.
  • consumption relative to coal consumption is less than about 10 mol% (i.e., for every mole of converted coal there is less than 0.1 mol of water consumed), or less than about 5 mol%, or less than about 1 mol%.
  • the process is water positive, and water production relative to coal consumption is greater than about 1 mol% (i.e., for every mole of converted coal there is produced 0.01 mol of water), or greater than about 2 mol%, or greater than about 5 mol%, or greater than about 10 mol%, or greater than about 20 mol%, or greater than about 25 mol%, or greater than about 40 mol%.
  • an oxidizing agent for the purpose of driving combustion of methane and/or coal within the gasifier, such as when additional heat is needed within the gasifier (see below for further details).
  • the oxidizing agent for combusting methane and/or coal may be selected from steam, oxygen gas, catalytic oxidizing agents, and combinations thereof. When a catalytic oxidizing agent is used, the agent can be regenerated and reused.
  • heat energy is supplied to the gasifier and/or one or more of the reactants that are fed to the gasifier.
  • the heat energy is supplied via an electrical heat-producing means, examples of which include screen heaters, plasma arc torches, and the like.
  • the electrical heat-producing means of the invention may be supplied with electricity that is generated by any suitable means, although renewable energy sources are preferred in some
  • renewable energy sources include wind, solar,
  • geothermal, hydroelectric, and ocean waves are geothermal, hydroelectric, and ocean waves.
  • other sources such as combustion of biomass or traditional non-renewable sources such as coal or petroleum may also be used to supply electric energy to the apparatus of the invention.
  • any combination of these and other sources of electric energy may be used.
  • heat energy may be supplied to the gasifier by oxidation of a carbonaceous material.
  • oxidation of biogas or methane via an oxidation catalyst can be used to generate heat in the gasifier.
  • the heat energy is used to heat one or more of the reactants fed to the gasifier.
  • the reactant(s) may be supplied heat energy as they pass the inlet port to the gasifier, before they reach the inlet port, or after they have entered the gasifier reaction chamber, or any combination thereof.
  • a screen heater or plasma arc torch is disposed at an inlet port to the gasifier, and one or more of the reactants are fed to the gasifier by passing through the heater.
  • the gasifier reaction chamber itself may be heated by an electrical heat generating means.
  • An example of such an embodiment includes electrical resistors disposed throughout or upon the walls of the reaction chamber.
  • the electrical energy may be used to heat water supplied to the gasifier.
  • the water supplied to the gasifier is in the form of steam, and the electrical heat generating means increases the temperature of the steam as described above.
  • the water supplied to the gasifier is in the form of liquid water, and the electrical heat generating means raises the temperature of the water (and, in some embodiments, converts the water to steam).
  • the electrical energy is used to heat methane supplied to the gasifier.
  • the methane may be heated prior to or after combination with coal particles, and prior to or after introduction to the gasifier reaction chamber.
  • the electrical energy is used to heat coal particles supplied to the gasifier.
  • the coal may be heated prior to or after combination with methane, and prior to or after introduction to the gasifier reaction chamber.
  • the electrical energy is used to heat both methane and coal particles supplied to the gasifier.
  • any C0 2 generated by the combustion of methane and/or coal within the gasifier is retained (rather than separated and vented) and consumed in downstream processes as described herein, such that the overall process of coal liquefaction does not produce C0 2 .
  • the primary output of the gasification reactor is a syngas product, and the syngas product is converted in downstream processes to additional products such as transportation fuels.
  • additional products such as transportation fuels.
  • various materials are prepared (e.g., methanol, propylene, hydrocarbons) as intermediates.
  • Such intermediates may also be considered products and/or raw materials for additional processes not mentioned herein.
  • an output of the gasification reactor is a gaseous mixture that comprises CO and H 2 and is commonly referred to as syngas.
  • the exact composition of the syngas output will depend on the reactants fed to the gasifier, and it will be appreciated that the syngas composition can be controlled by appropriately modifying the input to the gasifier.
  • the amount of H 2 relative to CO in the syngas can be increased by increasing the concentration of methane relative to coal.
  • the amount of H 2 relative to CO can also be increased by modifying the coal source - i.e., using a lower ranked coal that contains a higher hydrogen concentration.
  • the methods and apparatus of the invention do not require or involve addition of H 2 gas to the gasifier in order to achieve the desired syngas composition. Furthermore, typically, the methods and apparatus of the invention do not involve adding water to the gasifier inlet stream in order to achieve the desired syngas composition (although water may be present in the form of steam and act as an oxidant, as described in more detail herein).
  • the syngas output of the gasifier according to the invention comprises CO/H 2 in a molar ratio of between 0.35/1 and 2.5/1.
  • the CO/H 2 ratio is greater than 0.35/1, or greater than 0.5/1, or greater than 1/1, or greater than 1.5/1, or greater than 1.8/1.
  • the CO/H2 ratio is less than 2.5/1, or less than 2.3/1, or less than 2/1, or less than 1.5/1, or less than 1/1.
  • the syngas output of the gasifier according to the invention typically comprises CO/H 2 in a molar ratio of between 1.5/1 and 2.5/1, or between 1.7/1 and 2.3/1, or between about 1.9/1 and about 2.1/1.
  • the syngas output of the gasifier may comprise CO/H 2 in a ratio of about 1.9/1 or about 2.0/1, or about 2.1/1.
  • the syngas output comprises a CO/H 2 ratio suitable for forming methanol in a methanol reactor.
  • the syngas content can be modified by changing the ratio and/or composition of input materials (e.g., using relatively more methane, or relatively lower rank coal, etc.). This is particularly useful because different target products downstream (e.g., aviation fuels, automotive fuels, etc.) may require different syngas compositions for maximum conversion efficiency.
  • the syngas output of the gasifier may comprise one or more components such as C0 2 and water.
  • Water and C0 2 are typically carried through the apparatus into the methanol reactor where they are either consumed or recycled back to the gasifier.
  • the syngas output of a gasifier according to the invention is substantially free of nitrogen gas.
  • substantially free is meant that the amount of nitrogen gas relative to CO is less than 5 mol%, or less than 3 mol%, or less than 1 mol%, or less than 0.5 mol%.
  • the amount of nitrogen gas is preferably less than 10 mol%, or less than 5 mol%, or less than 3 mol%, or less than 1 mol%.
  • the syngas output of a gasifier according to the invention is substantially free of oxygen gas.
  • substantially free is meant that the amount of oxygen gas relative to CO is less than 5 mol%, or less than 3 mol%, or less than 1 mol%, or less than 0.5 mol%.
  • the amount of oxygen gas is less than 10 mol%, or less than 5 mol%, or less than 3 mol%, or less than 1 mol%.
  • the syngas product may be converted through a methanol intermediate to transportation fuels according to the methods disclosed herein.
  • Preferred transportation fuels include jet fuels (e.g., JP-8, Jet-A, JP-5, kerosene, etc.), automotive fuels (diesel, gasoline, etc.), watercraft fuels, and the like.
  • the jet fuel JP- 8 is described herein as having the formula CnH 21 , although it will be appreciated that this is only an approximation and an average formula.
  • the transportation fuel products prepared by the methods herein may be further modified and/or formulated with additives as desired.
  • the methods and apparatus of the invention provide for gasification of coal in a methane-blown gasifier, wherein steam is used as the primary oxidant.
  • methane-blown is meant that the coal particles are carried into the gasifier by a stream of methane gas.
  • the gasifier is not air-blown or oxygen-blown.
  • a stream of coal particles entrained in methane is referred to herein as an "input stream" for the gasifier.
  • steam is added to the input stream prior to the input stream enters the gasifier reaction chamber.
  • the input stream may be mixed with steam as it enters the gasifier reaction chamber.
  • the reaction chamber of the gasifier comprises less than 5 mol%, or less than 3 mol%, or less than 1 mol% of nitrogen gas, and/or less than 5 mol%, or less than 3 mol%, or less than 1 mol% of oxygen gas. In some embodiments, during operation of the gasifier, the reaction chamber is substantially free of nitrogen gas, oxygen gas, or both.
  • the hydrogen source is added to the gasifier in order to provide complete conversion of the coal to syngas, as described herein. Additionally, when the hydrogen source is a hydrocarbon, some of the carbon from the hydrocarbon is converted to CO in the gasifier. In some embodiments, little or no carbonaceous material and little or no hydrocarbon hydrogen source are combusted within the gasifier. For example, in some embodiments, when methane is used as the hydrogen source, substantially none of the methane that is input to the gasification reactor is combusted within the gasifier. In some embodiments, less than 25%, or less than 20% or less than 15%, or less than 10%, or less than 5%, or less than 3%, or less than 1% of the methane is combusted within the gasification chamber.
  • substantially none of the coal that is input to the gasification reactor is combusted within the gasifier. In some embodiments, less than 25%, or less than 20% or less than 15%, or less than 10%, or less than 5%, or less than 3%, or less than 1% of the coal is combusted within the gasification chamber. In some embodiments, it has been observed that char particles catalyze the conversion of methane to syngas, and thus the degree of conversion depends on the coal density in the reaction zone.
  • component(s) of the input to the gasifier is/are heated prior to entering the reaction chamber.
  • the steam, methane, or both may be heated, preferably using the means for supplying electrical heat energy described herein.
  • the internal gasifier temperature during operation is maintained above 500 °C, or above 600 °C, or above 700 °C, or above 800 °C, or above 900 °C, or above 1000 °C, or above 1100 °C, or above 1200 °C, or above 1300 °C, or above 1400 °C, or above 1500 °C.
  • internal gasifier temperature is meant the average temperature of the gaseous components within the gasifier reaction chamber at the point where the temperature is measured. Typically, internal gasifier temperature is measured at or near the bottom of the gasifier, or near to where the reactants enter the gasifier.
  • the temperature of the input stream(s) can be measured and maintained as desired.
  • the temperature of the steam and/or methane stream(s) is/are individually maintained at above 500 °C, or above 600 °C, or above 700 °C, or above 800 °C, or above 900 °C, or above 1000 °C, or above 1100 °C, or above 1200 °C, or above 1300 °C, or above 1400 °C, or above 1500 °C.
  • Such temperatures may be measured just before the stream(s) enter the gasifier reaction chamber or just after the stream(s) enter the reaction chamber. It will be appreciated that these temperature values may be obtained and maintained by adjusting the amount of electrically-generated heat energy that is applied to the system, as described above.
  • the gasifier is operated at an internal gasifier pressure of greater than 1 atm.
  • the gasifier is operated at an internal gasifier pressure in the range of about 1 atm to about 100 atm (or greater), as discussed above with respect to the pressure of steam used in the gasifier.
  • the term "internal gasifier pressure” refers to the average pressure of the gaseous components within the gasifier reaction chamber at the point where the pressure is measured.
  • the overall heat of reaction may be calculated using reported heating values for coal and the heats of formation for the various reactant and products. The results of these calculations are shown in Table 1.
  • ⁇ ⁇ is negative (exothermic) for the overall simplified process. This indicates that, with perfect heat integration, the overall process would produce heat; that is, no additional energy would be required. However, even though the overall reaction is exothermic, additional energy is required at the gasifier to carry out endothermic reforming reactions (i.e., production of syngas) at high temperatures. This additional energy can be added to the system in a variety of ways, and preferably using electrically generated heat energy as described in more detail herein.
  • both coal gasification and steam reforming of methane proceeds simultaneously.
  • Steam reforming of methane produces hydrogen from hydrocarbons and, as in the coal gasifiers described herein, is carried out at high temperature and pressure (e.g., 800+°C and 20+ bar). Additionally, higher
  • the energy provided to the gasifier is generated by a combination of renewable (e.g., hydroelectric, hydrothermal, solar, wind, etc.) and non-renewable (e.g., petroleum, coal, etc.) energy sources.
  • renewable e.g., hydroelectric, hydrothermal, solar, wind, etc.
  • non-renewable e.g., petroleum, coal, etc.
  • Option A utilizes the energy created by the partial oxidation of methane in air to form CO and H 2 for the production of methanol. This reaction is exothermic and provides the necessary energy to maintain the gasifier' s high operating temperature.
  • the use of air requires a larger gasifier per barrel of JP-8 than oxygen blown gasifiers.
  • the syngas cleanup processes and methanol reactors have to be larger to handle the large nitrogen flow rates. After the methanol reactor, the nitrogen and un-reacted methane are separated. The nitrogen is vented to the atmosphere while the methane is recycled back to the gasifier.
  • Option B utilizes the complete combustion of a small methane stream to provide the required energy.
  • Option C utilizes a complete combustion of biomass to provide the required energy. As in Option B there is some C0 2 emission, but in this case it is assumed that the vast majority of the C0 2 is "recycled" by the growth of new biomass. Preferred biomass sources can most efficiently be converted to energy with minimal impact on the environment.
  • Option D utilizes a source of electrical energy that does not emit C0 2 . Options include solar, geothermal, hydroelectric, wave, and wind- generated power. The electrical power can heat the gasifier, for example, utilizing resistance heating. Each option requires varying amounts of methane or an alternative source of energy. The magnitudes of these inputs are estimated and summarized in the Table below.
  • the methods of the invention provide for greater than 75% conversion of the methane and greater than 75% conversion of the coal to CO and/or C0 2 within the gasifier. For example, greater than 80% conversion, or greater than 85% conversion, or greater than 90% conversion, or greater than 95% conversion of the methane is achieved. Also for example, greater than 80% conversion, or greater than 85% conversion, or greater than 90% conversion, or greater than 95% conversion of the coal is achieved.
  • FIG. 1 An embodiment of the invention is illustrated in block form in FIG. 1.
  • coal, water, and methane are fed to a gasifier.
  • the output of the gasifier (comprising syngas and impurities) is fed to a cleanup stage, where impurities such as slag, ammonium, sulfur, and mercury are removed.
  • the cleaned syngas product is fed to a methanol reactor, and the output of the methanol reactor comprises methanol and methane.
  • the methane is separated and fed to a compressor before being added back to the gasifier.
  • the methanol is sent to a propylene reactor, which outputs water and propylene.
  • the water output of is recycled back to the gasifier, while the propylene output is fed to a diesel reactor and converted to jet fuel (JP-8).
  • FIG. 2 A more detailed block diagram of a process according to the invention is shown in FIG. 2.
  • oxygen gas can be used as the oxidizing agent in the methods of the invention.
  • FIG. 3 Such an embodiment is illustrated in FIG. 3, where (a) and (c) provide a block diagram and an equation, respectively, that show the inputs and outputs. Coal, methane, and oxygen are inputs to the process, while water and JP-8 are outputs of the process.
  • the heat of reaction is shown as a function of 0 2 /coal ratio for various types of coal. For any given ratio of 0 2 /coal, lower ranks of coal provide a more exothermic reaction.
  • the methods and apparatus according to the invention produce syngas in a new manner that is preferable to previous methods for producing syngas.
  • syngas product is ideally suited for the production of hydrocarbon fuels.
  • Some of the processes mentioned herein for converting syngas to transportation fuels are known generally (e.g., conversion of syngas to methanol, conversion of methanol to propylene, and conversion of propylene to hydrocarbon fuels).
  • the known individual processes are uniquely adapted and integrated into the overall processes of the invention by taking advantage of byproducts and selecting processes that are most suitable (e.g., selecting a methanol-to-propylene conversion method that produces water as a byproduct and recycling the water, thereby making the methods of the invention water neutral).
  • Operating conditions for each stage in the overall processes of the invention may be optimized to ensure that the various stages work together. This allows tailoring of the overall processes to provide maximum environmental friendliness, energy-efficiency, atom-efficiency, and yield of desired products.
  • the methods By not using coal to produce hydrogen via WGS, the methods also increase the carbon yield of the coal to JP-8 transformation, thus reducing the size of the gasification unit. Furthermore, the methods are carbon-efficient, as all or nearly all of the carbon in the coal is incorporated into the fuel product, and nearly 60% of the carbon in the product is from the coal (base case).
  • some benefits of the methods disclosed herein include: improvements in the operating range of gasifier operation with a simultaneous lowering of the capital costs; provision of a clean syngas for the synthesis of transportation fuels such as JP-8 (which previously required advanced gas cleaning technologies to prevent the poisoning of catalysts and avoid introducing unacceptable environmental contaminants into the final product); the elimination, or at least substantial reduction in the size of, an air separation unit (ASU); and reducing the size of downstream equipment by eliminating or substantially reducing the volume of nitrogen in the syngas (dilution is avoided by using methane to blow the coal into the gasifier). Furthermore, the methane can be received from a pipeline at a pressure which limits or even eliminates the need to compress the feed gas.
  • ASU air separation unit
  • Some advantages of the methanol-to-diesel route described herein include increased product control and no additional production of C0 2 .
  • using the methanol route allows any C0 2 produced in the gasifier to be consumed in the methanol reactor to form methanol and water.
  • the output of the methanol reactor has a methane component
  • the methanol reactor is described as having a means for separating the methanol from the methane at the output of the reactor. It will be appreciated, however, that such separation may also be
  • Char conversion is the principal factor in determining the size of the gasifier, which is the single most expensive item in the Coal to Liquid (CTL) process.
  • CTL Coal to Liquid
  • Preferred methods for CTL that can cost-effectively produce transportation fuels such as JP-8 should achieve 90% conversion of the fed coal.
  • the reactor designs of the invention allow for a pre- reactor for methane steam reforming. In some cases, this allows for the simultaneous high conversion of methane and coal in the single reactor configuration.
  • the output of the pre-reactor is the input for the main reactor where the coal is gasified.
  • the gas feed system applies a slight amount of preheating to the gases through external heating tapes wrapped around the gas inlet plumbing.
  • Three heaters delivering approximately 144 W each are used on the gas delivery tubing while a separate power supply heats the steam generation section to 290 °C.
  • heat losses are high and there is low surface area for heat transfer.
  • Modeling software estimates equilibrium conditions at which the specified compositions are achieved. The conditions are verified in the batch reactor if necessary to find pressure, temperature, component yields, and an upper bound for the residence time of a full-scale gasifier.
  • the laboratory gasifier provides initial kinetic data for a lower bound on residence time and potentially initial yield results.
  • the results from the laboratory gasifier serve as inputs for the modeling software, which predicts a residence time and the product yields of a full-scale gasifier.
  • the software can model a variety of different gasifiers, including entrained flow, transport, fixed bed, and fluidized bed gasifiers. The results from the modeling can then be input into the process model.
  • a radiant coal flow reactor system is used for studying the pyrolysis, combustion, and steam gasification of coals and other solid fuels under pressures of up to 40 atm (see Figure 12).
  • steam is injected into the entrainment gas flow at concentrations and pressures typical of full-scale gasifier facilities (up to 25% by gas volume at 40 atm or more).
  • the key advantage of this entrained flow facility is that all products can be captured and analyzed, resulting in close mass balances to useful tolerances.
  • the facility is modified to study the methods of the invention such that methane, in combination with steam, is used as the entrainment gas.

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)
  • Combustion & Propulsion (AREA)
  • Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)

Abstract

L'invention concerne des procédés et un appareil pour convertir finalement une matière carbonée en hydrocarbures liquides, appropriés pour une utilisation, par exemple, en tant que carburants de transport. Dans une première étape, la matière carbonée est convertie en un produit gaz de synthèse et, dans des étapes ultérieures, le produit gaz de synthèse est converti en hydrocarbures liquides voulus. Dans un mode de réalisation, du charbon et du méthane sont convertis en gaz de synthèse et le produit gaz de synthèse est converti en hydrocarbures par un intermédiaire méthanol. Un exemple d'utilisation pour les procédés et l'appareil de l'invention est dans la préparation de carburéacteurs.
PCT/US2011/027070 2011-03-03 2011-03-03 Gazéification de matière carbonée WO2012118511A1 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
EP11860093.1A EP2681292A4 (fr) 2011-03-03 2011-03-03 Gazéification de matière carbonée
CN201180070638.7A CN103842476A (zh) 2011-03-03 2011-03-03 碳质材料的气化
PCT/US2011/027070 WO2012118511A1 (fr) 2011-03-03 2011-03-03 Gazéification de matière carbonée

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/US2011/027070 WO2012118511A1 (fr) 2011-03-03 2011-03-03 Gazéification de matière carbonée

Publications (1)

Publication Number Publication Date
WO2012118511A1 true WO2012118511A1 (fr) 2012-09-07

Family

ID=46758243

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2011/027070 WO2012118511A1 (fr) 2011-03-03 2011-03-03 Gazéification de matière carbonée

Country Status (3)

Country Link
EP (1) EP2681292A4 (fr)
CN (1) CN103842476A (fr)
WO (1) WO2012118511A1 (fr)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2784288A1 (fr) * 2013-03-28 2014-10-01 Lumenion AG Centrale électrique et procédé de génération d'énergie électrique
CN105542832A (zh) * 2015-12-15 2016-05-04 七台河宝泰隆煤化工股份有限公司 一种焦炭制轻烃的方法

Families Citing this family (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN105062592B (zh) * 2015-07-31 2017-09-26 赛鼎工程有限公司 碎煤加压气化合成气经甲醇合成汽油、联产液化天然气和用于焦油深加工的综合利用工艺
CN107177394B (zh) * 2017-07-05 2020-11-20 安徽省宗正农业科技开发有限公司 一种耐贮存的生物质燃料的加工方法
CN114023176A (zh) * 2021-11-03 2022-02-08 嘉兴中科海石合金技术有限公司 地球深处石油生成原理的科学演示装置及方法

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JPH0967582A (ja) * 1995-08-31 1997-03-11 Hitachi Ltd 水素・一酸化炭素混合ガスの製造方法及び製造装置
US6200430B1 (en) * 1998-01-16 2001-03-13 Edgar J. Robert Electric arc gasifier method and equipment
US20020155043A1 (en) * 1999-04-28 2002-10-24 Yakobson Dennis L. Plasma reforming/Fischer-Tropsch synthesis
JP2002363578A (ja) * 2001-06-01 2002-12-18 Babcock Hitachi Kk 水素・一酸化炭素混合ガスの製造方法および製造装置ならびに燃料・電力併産プラント
US20050107482A1 (en) * 2003-11-19 2005-05-19 Van Egmond Cornelis F. Methanol and ethanol production for an oxygenate to olefin reaction system
US20050256212A1 (en) * 2002-02-05 2005-11-17 Norbeck Joseph N Production of synthetic transporation fuels from carbonaceous material using self-sustained hydro-gasification

Family Cites Families (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2005113425A1 (fr) * 2004-05-20 2005-12-01 The Petroleum Oil And Gas Corporation Of South Africa (Pty) Ltd. Recuperation d'eaux usees provenant de processus de synthese

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JPH0967582A (ja) * 1995-08-31 1997-03-11 Hitachi Ltd 水素・一酸化炭素混合ガスの製造方法及び製造装置
US6200430B1 (en) * 1998-01-16 2001-03-13 Edgar J. Robert Electric arc gasifier method and equipment
US20020155043A1 (en) * 1999-04-28 2002-10-24 Yakobson Dennis L. Plasma reforming/Fischer-Tropsch synthesis
JP2002363578A (ja) * 2001-06-01 2002-12-18 Babcock Hitachi Kk 水素・一酸化炭素混合ガスの製造方法および製造装置ならびに燃料・電力併産プラント
US20050256212A1 (en) * 2002-02-05 2005-11-17 Norbeck Joseph N Production of synthetic transporation fuels from carbonaceous material using self-sustained hydro-gasification
US20050107482A1 (en) * 2003-11-19 2005-05-19 Van Egmond Cornelis F. Methanol and ethanol production for an oxygenate to olefin reaction system

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
See also references of EP2681292A4 *

Cited By (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2784288A1 (fr) * 2013-03-28 2014-10-01 Lumenion AG Centrale électrique et procédé de génération d'énergie électrique
KR20140118918A (ko) * 2013-03-28 2014-10-08 루메니온 에이지 발전 장치 및 전력을 발생시키는 방법
JP2014194218A (ja) * 2013-03-28 2014-10-09 Lumenion Ag 電力を発生させる発電装置および方法
RU2577038C2 (ru) * 2013-03-28 2016-03-10 Луменион АГ Силовая установка и способ генерирования электрической энергии
KR101694860B1 (ko) * 2013-03-28 2017-01-10 루메니온 에이지 발전 장치 및 전력을 발생시키는 방법
US9683491B2 (en) 2013-03-28 2017-06-20 Lumenion Ag Power plant and method for generating electrical power
CN105542832A (zh) * 2015-12-15 2016-05-04 七台河宝泰隆煤化工股份有限公司 一种焦炭制轻烃的方法
CN105542832B (zh) * 2015-12-15 2017-08-11 七台河宝泰隆煤化工股份有限公司 一种焦炭制轻烃的方法

Also Published As

Publication number Publication date
CN103842476A (zh) 2014-06-04
EP2681292A4 (fr) 2014-11-12
EP2681292A1 (fr) 2014-01-08

Similar Documents

Publication Publication Date Title
US6306917B1 (en) Processes for the production of hydrocarbons, power and carbon dioxide from carbon-containing materials
US8444725B2 (en) System and process for producing synthetic liquid hydrocarbon
USRE40419E1 (en) Production of synthetic transportation fuels from carbonaceous material using self-sustained hydro-gasification
US20080275278A1 (en) Reduced-Emission Gasification and Oxidation of Hydrocarbon Materials for Liquid Fuel Production
EP3303524B1 (fr) Procédé de production d'un gaz naturel de substitution à partir d'un gaz de synthèse
US11572512B2 (en) Gasification process
US20150005399A1 (en) Method and device for producing synthetic gas and method and device for synthesizing liquid fuel
AU2008298514A1 (en) Integration of an integrated gasification combined cycle power plant and coal to liquid facility
EP2681292A1 (fr) Gazéification de matière carbonée
US10273422B2 (en) Integrated biofuels process configurations, employing a 2-stage bio-reforming reactor system, in which renewable carbon content of gasoline and diesel are optimized for value
KR20210097189A (ko) 스팀/co2 개질에 의한 수소 및 ft 생성물의 제조
CN107267218B (zh) 固体燃料热解气化的方法及系统
US9163185B2 (en) Gasification of a carbonaceous material
WO2014163586A1 (fr) Gazéificateur de métal fondu
Weber et al. Energy efficiency of an integrated process based on gasification for hydrogen production from biomass
US20240140793A1 (en) Enhanced gasification system and method
US20240139788A1 (en) Enhanced gasification system and method
US20240141242A1 (en) Enhanced gasification system and method
WO2024089471A1 (fr) Système et procédé de gazéification améliorée
WO2024089472A1 (fr) Système et méthode de gazéification améliorée
WO2024091394A9 (fr) Système et procédé de gazéification améliorée
Justinus et al. Production of Synthesis Gas and/or Hydrogen from Biomass Via Fast-Pyrolysis and Reforming Process

Legal Events

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

Ref document number: 11860093

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase

Ref country code: DE

REEP Request for entry into the european phase

Ref document number: 2011860093

Country of ref document: EP

WWE Wipo information: entry into national phase

Ref document number: 2011860093

Country of ref document: EP