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US20080016756A1 - Conversion of carbonaceous materials to synthetic natural gas by reforming and methanation - Google Patents

Conversion of carbonaceous materials to synthetic natural gas by reforming and methanation Download PDF

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Publication number
US20080016756A1
US20080016756A1 US11/880,750 US88075007A US2008016756A1 US 20080016756 A1 US20080016756 A1 US 20080016756A1 US 88075007 A US88075007 A US 88075007A US 2008016756 A1 US2008016756 A1 US 2008016756A1
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methanation
zone
product stream
gaseous product
carbonaceous material
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Stanley R. Pearson
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Clean Energy LLC
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Clean Energy LLC
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Assigned to CLEAN ENERGY, L.L.C. reassignment CLEAN ENERGY, L.L.C. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: PEARSON, STANLEY R.
Publication of US20080016756A1 publication Critical patent/US20080016756A1/en
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    • 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
    • C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
    • C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
    • C10L3/08—Production of synthetic natural gas
    • 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
    • C10J3/02—Fixed-bed gasification of lump fuel
    • C10J3/20—Apparatus; Plants
    • C10J3/22—Arrangements or dispositions of valves or flues
    • C10J3/24—Arrangements or dispositions of valves or flues to permit flow of gases or vapours other than upwardly through the fuel bed
    • C10J3/26—Arrangements or dispositions of valves or flues to permit flow of gases or vapours other than upwardly through the fuel bed downwardly
    • 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
    • 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
    • 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
    • C10K1/02—Dust removal
    • 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
    • C10K1/08—Purifying combustible gases containing carbon monoxide by washing with liquids; Reviving the used wash liquors
    • C10K1/10—Purifying combustible gases containing carbon monoxide by washing with liquids; Reviving the used wash liquors with aqueous liquids
    • C10K1/101—Purifying combustible gases containing carbon monoxide by washing with liquids; Reviving the used wash liquors with aqueous liquids with water only
    • 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
    • C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
    • C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
    • C10L3/10—Working-up natural gas or synthetic natural gas
    • C10L3/101—Removal of contaminants
    • C10L3/102—Removal of contaminants of acid contaminants
    • 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
    • C10J2300/0916—Biomass
    • 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
    • C10J2300/0916—Biomass
    • C10J2300/092—Wood, cellulose
    • 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
    • C10J2300/0973—Water
    • 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
    • C10J2300/1662—Conversion of synthesis gas to chemicals to methane
    • 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
    • Y02P20/141—Feedstock
    • Y02P20/145—Feedstock the feedstock being materials of biological origin

Definitions

  • the present invention relates to the production of synthetic natural gas from a carbonaceous material, preferably a biomass material, such as wood.
  • the carbonaceous material is steam reformed to produce a syngas, which is then passed through several clean-up steps then to a methanation zone to produce synthetic natural gas.
  • biomass energy is regarded as one of the most promising natural energy from the viewpoint of its abundance, renewability and storability.
  • Cellulosic materials, such as wood have great potential for providing large amounts of energy.
  • Direct combustion of woody biomass suffers from a limited amount of resource and low efficiency, and, further, only electric power can effectively be supplied from the direct combustion of woody biomass.
  • Synthetic natural gas A large portion of synthetic natural gas is often referred to as “green gas” because it is a renewable gas typically obtained from biomass and having natural gas specifications. Thus, it can be transported through existing natural gas infrastructure, substituting for natural gas in all existing applications. Also, the use of biomass as the feedstock will not generally result in a net CO 2 emission as long as the source material can be replanted to replace those used as fuel. It may even be possible to reduce atmospheric CO 2 by sequestering the CO 2 that is released during the conversion of biomass (negative CO 2 emission).
  • Exposing the base fuel during the pyrolysis to air, water vapor or other components has a direct impact on the products of pyrolysis, as does the temperature of the process and the duration thereof.
  • a fluidized bed which is, at least initially exposed to air and can be additionally exposed to oxygen, or other input gases, some portion of the fuel for gasification is consumed, as by oxidation (burning) affecting the output of the process by producing ash or other undesirable residue.
  • the carbonaceous material is selected from the group consisting of wood and dried distillers grains.
  • FIG. 1 hereof is a generalized flow scheme of a preferred embodiment of the present invention wherein a carbonaceous material, such as wood chips, are steam reformed to produce a syngas, which is then passed through various clean-up steps to a methanation unit to produce synthetic natural gas.
  • a carbonaceous material such as wood chips
  • the present invention is directed to the production of synthetic natural gas (predominantly methane) from carbonaceous materials, preferably biomass materials.
  • Synthetic natural gas also sometimes called “green gas” is a renewable gas from biomass with natural gas specifications. Therefore, it can be transported through the existing gas infrastructure, substituting for natural gas in all existing applications.
  • Another advantage of green gas is that is carbon neutral. That is, using biomass as an energy supply will typically not result in a net CO 2 emission since its source can be replanted and uses CO 2 from the atmosphere during its growth period.
  • biomass feedstocks suitable for being converted in accordance with the present invention include trees such as red cedar, southern pine, hardwoods such as oak, cedar, maple and ash, as well as bagasse, rice hulls, rice straw, kennaf, old railroad ties, dried distiller grains, corn stalks and cobs and straw.
  • biomass feedstocks suitable for being converted in accordance with the present invention include trees such as red cedar, southern pine, hardwoods such as oak, cedar, maple and ash, as well as bagasse, rice hulls, rice straw, kennaf, old railroad ties, dried distiller grains, corn stalks and cobs and straw.
  • Cellulosic materials are the more preferred biomass feedstocks, with wood and dried distillers grains being the most preferred.
  • Biomass is typically comprised of three major components: cellulose, hemicellulose and lignin.
  • Cellulose is a straight and relatively stiff molecule with a polymerization degree of approximately 10,000 glucose units (C 6 sugar).
  • Hemicellulose are polymers built of C 5 and C 6 sugars with a polymerization degree of about 200 glucose units. Both cellulose and hemicellulose can be vaporized with negligible char formation at temperatures above about 500° C.
  • lignin is a three dimensional branched polymer composed of phenolic units. Due to the aromatic content of lignin, it degrades slowly on heating and contributes to a major fraction of undesirable char formation.
  • biomass In addition to the major cell wall composition of cellulose, hemicellulose and lignin, biomass often contains varying amounts of species called “extractives”. These extractives, which are soluble in polar or non-polar solvents, are comprised of terpenes, fatty acids, aromatic compounds and volatile oil.
  • the carbonaceous feedstock used in the practice of the present invention will be found in a form wherein the particles too large for conducting through the tubes of the reformer.
  • it will usually be necessary to grind the carbonaceous material to an effective size.
  • the carbonaceous material is ground, or otherwise reduced in size, to a suitable size of about 1/32 inch to about 1 inch, preferably about 1/16 inch to about 1 ⁇ 2 inch, and more preferably from about 1 ⁇ 8 inch to 1 ⁇ 4 inch. Grinding techniques are well know and varied, thus any suitable grinding technique and equipment can be used for the particular carbonaceous material being converted.
  • reforming requires that a feedstock have less than about 15% moisture content, but there is an optimization between moisture content and conversion process efficiency.
  • the actual moisture content will vary somewhat depending on the commercial process equipment used. Since some of the biomass received for processing can have a moisture content from about 40 to 60% it will have to be dried before pyrolysis. Any conventional drying technique can be used as long as the moisture content is lowered to less than about 15% when mixed with the superheated steam. For example, passive drying during summer storage can reduce the moisture content to about 30% or less. Active silo drying can reduce the moisture content down to about 12%. Drying can be accomplished either by very simple means, such as near ambient, solar drying or by waste heat flows or by specifically designed dryers operated on location. Also, commercial dryers are available in many forms and most common are rotary kilns and shallow fluidized bed dryers.
  • the carbonaceous material feedstock is conducted via line 10 and superheated steam is conducted via line 12 to mixing zone Mix wherein the two are sufficiently mixed before being conducted via line 14 into steam reformer R.
  • the superheated steam which will be at a temperature from about 850° F. to about 950° F. acts as both a source of hydrogen as well as a transport medium.
  • the dew point will typically be at about 230° C.
  • the amount of superheated steam to feedstock will be an effective amount. By effective amount we mean at least that amount needed to provide sufficient transport of the feedstock.
  • That ratio of superheated to steam of feedstock, on a volume to volume basis will typically from about 0.2 to 2.5, preferably from about 0.3 to 1.0.
  • the temperature conditions for the pyrolysis reaction will be described later in detail.
  • the steam is preferably introduced so that the feedstock is diluted to the point where it can easily be transported through the reactor tubes. Fluidization will typically result and can realize fluid pyrolysis by virtue of good contact among steam, polymers and heat decomposition products of carbonaceous material liberated in the gas phase.
  • the mixture of steam and feedstock is fed to steam reformer R via line 14 into a flow divider FD where it is distributed into the plurality of coiled reactor tubes of effective internal diameter and length within a metal cylindrical vessel of suitable size.
  • Typical internal diameters for the pyrolysis reactor tubes will be from about 2 to about 4 inches, preferably from about 2.5 to about 3.5 inches, and more preferably about 3 inches.
  • the source of heat for the reformer can be any suitable source it is preferred that the source of heat be one or more burners B located at bottom of the reforming process unit.
  • Fuel for burner B can be any suitable fuel. It is preferred that at least some of the fuel be obtained from the present process, such as fuel or syngas produced in the reformer.
  • reformer R be one in which the carbonaceous feed will be distributed to a plurality of vertically oriented tubes. At least a portion of the carbonaceous feed is converted to syngas in reformer R, which syngas is also composed primarily of hydrogen, carbon dioxide, carbon monoxide and methane.
  • the inlet temperature of the feedstock and superheated steam entering reformer R will preferably be about 230° C.
  • the exit temperature of the product syngas leaving reformer R via line 16 will typically be from about 850° C. and 1200° C., preferably between about 900° C. and about 1,000° C. At a temperature of about 1100° C.
  • Pressure in the reformer is not critical, but it will typically be at about 3 to 35 psig. Also, it is preferred that the residence time in the reformer be from about 0.4 to about 1.5 seconds.
  • syngas product stream For any given feedstock, one can vary the proportions of hydrogen, carbon dioxide, carbon monoxide and methane that comprise the resulting syngas product stream as a function of the contact time of the carbonaceous feedstock in the reformer, the exit temperature, the amount of steam introduced, and to a lesser extent, pressure. Certain proportions of syngas components are better than others for producing synthetic natural gas, thus conditions should be such as to maximize the production of carbon monoxide and methane at the expense of hydrogen.
  • a flue gas stream comprised primarily of CO 2 and N 2 is exhausted from the reformer via line 15 and the product syngas stream from reformer R is conducted via line 16 to heat recovery zone HR 1 where it is preferred that water be the heat exchange medium and that the water be used as preheated steam to reformer R via lines 18 where it is further heated to produce at least a portion of the superheated steam used for the reformer via line 17 .
  • Heat Recovery zone HR 1 can be any suitable heat exchange device, such as the shell-and-tube type wherein water is used to remove heat from product stream 16 .
  • the product syngas is passed via line 18 through separation zone S which contains a gas filtering means and preferably a cyclone (not shown) and optionally a bag house (not shown) to remove at least a portion, preferably substantially all, of the remaining ash and other solid fines from the syngas.
  • the filtered solids are collected via line 20 for disposal.
  • the filtered syngas stream is then passed via line 22 to water wash zone WW wherein it is conducted upward and countercurrent to down-flowing water via line 23 .
  • the water wash zone preferably comprises a column packed with conventional packing material, such as copper tubing, pall rings, metal mesh or other such materials.
  • the syngas passes upward countercurrent to down-flowing water which serves to further cool the syngas stream to about ambient temperature, and to remove any remaining ash that may not have been removed in second separation zone S.
  • the water washed syngas stream is then passed via line 24 to oil wash zone OW where it is passed countercurrent to a downflowing organic liquid stream to remove any organics present, such as benzene, toluene, xylene, or heavier hydrocarbon components via line 25 that may have been produced in the reformer.
  • the downflowing organic stream will be any organic stream in which the organic material being removed is substantially soluble. It is preferred that the down-flowing organic stream be a hydrocarbon stream, more preferably a petroleum fraction.
  • the preferred petroleum fractions are those boiling in naphtha to distillate boiling range, more preferably a C 16 to C 20 hydrocarbon stream, most preferably a C 18 hydrocarbon stream.
  • the resulting syngas stream is conducted via line 26 to acid gas scrubbing zone AGS wherein acidic gases, preferably CO 2 are removed.
  • acid gas treating technology can be used in the practice of the present invention.
  • any suitable acid gas scrubbing agent can be used, preferably a basic solution can be used in the acid gas scrubbing zone AGS that will adsorb the desired level of acid gases from the vapor stream. It will be understood that it may be desirable to leave a certain amount of CO 2 in the scrubbed stream depending on the intended use of resulting methane product stream from the methanation unit. For example, if the methane product stream is to be introduced into a natural gas pipeline, no more than about 4 vol. % of CO 2 should be remain.
  • One suitable acid gas scrubbing technology is the use of an amine scrubber.
  • Non-limiting examples of such basic solutions are the amines, preferably diethanol amine, mono-ethanol amine, and the like. More preferred is diethanol amine.
  • Another preferred acid gas scrubbing technology is the so-called “Rectisol Wash” which uses an organic solvent, typically methanol, at subzero temperatures.
  • the scrubbed stream can also be passed through one or more guard beds (not shown) to remove catalyst poisoning impurities such as sulfur, halides etc.
  • the treated stream is passed via line 28 from acid gas scrubbing zone AGS to methanation zone M.
  • Methanation of syngas involves a reaction between carbon oxides, i.e. carbon monoxide and carbon dioxide, and hydrogen in the syngas to produce methane and water, as follows:
  • Methanation reactions (1) and (2) take place at around 300° C. to about 900° C. in methanation zone M which is preferably comprised of two or more, more preferably three, reactors each containing a suitable methanation catalyst.
  • the methanation reaction is strongly exothermic.
  • the temperature increase in a typical methanator gas composition is about 74° C. for each 1% of carbon monoxide converted and 60° C. for each 1% carbon dioxide converted.
  • the temperature in the methanation reactor during methanation of syngas has to be controlled to prevent overheating of the reactor catalyst.
  • high temperatures are undesirable from an equilibrium standpoint and reduce the amount of conversion of syngas to methane since methane formation is favored at lower temperatures. Formation of soot on the catalyst is also a concern and may require the addition of water to the syngas feedstock.
  • methanation zone M preferably comprises a series of three adiabatic methanation reactors R 1 , R 2 and R 3 .
  • Each of these reactors is configured to react carbon oxide and hydrogen contained in the syngas in the presence of a suitable catalyst to produce methane and water, in accordance with the reactions (1) and (2) set forth hereinabove.
  • Each of the methanation reactors includes a catalyst capable of promoting methanation reactions between carbon oxides and hydrogen in the syngas feedstock.
  • Any conventional methanation catalyst is suitable for use in the practice of the present invention, although nickel catalysts are most commonly used and the more preferred for this invention.
  • Such catalysts are, especially those containing greater than 50% nickel, are generally stable against thermal and chemical sintering during methanation of undiluted syngas streams.
  • other stable catalysts that are active and selective towards methane may be used in the methanation reactors.
  • heat recover zones HR 2 and HR 3 are used to remove heat from the stream as it passed from reactor R 1 to reactor R 2 and reactor R 2 to reactor R 3 respectively.
  • Any suitable exchange device can be used, preferably a shell-and-tube type wherein water can be used to remove heat from the product stream. The water can then be recycled to line 30 where it can be further heated to produce superheated steam.
  • the inlet and outlet temperatures of the streams entering and exiting methanation reactors R 1 -R 3 can be controlled by varying the percentage of syngas being delivered to each of the reactors as well as how much heat is exchanged by heat exchangers HR 2 and HR 3 .
  • the inlet temperature of reactors R 1 and R 2 will be from about 400° F. to about 450° F. with an outlet temperature of about 500° F. to about 800° F.
  • the third reactor, which will operate at a lower temperature than that of reactors R 1 and R 2 will have an inlet temperature of about 400° F. and an outlet temperature of about 500° F.
  • the step of recovering at least a part of generated heat and/or at least a part of waste heat in the regeneration zone and effectively utilizing the recovered heat is further provided.
  • the recovered heat can be effectively utilized, for example, for drying and heating of the biomass feedstock and the generation of steam as the gasifying agent.
  • the product stream from the methanation unit will be comprised predominantly of methane. That is, it will contain at least about 75 vol. %, preferably at least about 85 vol. %, and more preferably at least about 95 vol. % methane.
  • the product methane can be introduced into a natural gas pipeline and utilized at any downstream facility.
  • One such facility if preferably a plant that converts the methane to syngas then to other products, such as alcohols, transportation fuels, or lubricant base stocks.
  • any suitable process can be used that convert methane or natural gas to syngas.
  • Preferred methods include steam reforming and partial oxidation. More preferred is steam reforming. Steam reforming of methane is a highly endothermic process and involves following reactions:
  • the steam reformer will preferably be one similar to reformer R hereof, which is a coiled tubular reactor.
  • Preferred steam reforming catalysts are nickel containing catalysts, particularly nickel (with or without other elements) supported on alumina or other refractory materials, in the above catalytic processes for conversion of methane (or natural gas) to syngas is also well known in the prior art. Kirk and Othmer, Encyclopedia of Chemical Technology, 3rd Ed., 1990, vol. 12, p. 951; Ullmann's Encyclopedia of Industrial Chemistry, 5th Ed., 1989, vol. A12, pp. 186 and 202; U.S. Pat. No. 2,942,958 (1960); U.S. Pat. No. 4,877,550 (1989); U.S. Pat. No.
  • the catalytic steam reforming of methane, or natural gas, to syngas is a well established technology practiced for commercial production of hydrogen, carbon monoxide and syngas (i.e., a mixture of hydrogen and carbon monoxide).
  • hydrocarbon feed is converted to a mixture of H 2 , CO and CO 2 by reacting hydrocarbons with steam over a supported nickel catalyst such as NiO supported on alumina at elevated temperature (850° C. to 1000° C.) and pressure (10-40 atm) and at steam to carbon mole ratio of 2-5 and gas hourly space velocity of about 5000-8000 per hour.

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US11/880,750 2006-07-24 2007-07-24 Conversion of carbonaceous materials to synthetic natural gas by reforming and methanation Abandoned US20080016756A1 (en)

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Cited By (7)

* Cited by examiner, † Cited by third party
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US20080154144A1 (en) * 2006-08-08 2008-06-26 Kamil Unver Systems and methods for cardiac contractility analysis
US20090221725A1 (en) * 2008-02-28 2009-09-03 Enerkem, Inc. Production of ethanol from methanol
US20090293786A1 (en) * 2008-05-27 2009-12-03 Olver John W Biomass Combustion Chamber and Refractory Components
WO2012058903A1 (fr) * 2010-11-05 2012-05-10 四川亚连科技有限责任公司 Procédé de préparation de gaz naturel de synthèse à l'aide de gaz produit à partir de paille
US20150052812A1 (en) * 2013-08-20 2015-02-26 Philip James Scalzo Oxygen-Deficient Thermally Produced Processed Biogas from Beneficiated Organic-Carbon-Containing Feedstock
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PL2261308T3 (pl) 2009-05-07 2013-11-29 Haldor Topsoe As Sposób wytwarzania gazu ziemnego
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US20160317054A1 (en) * 2008-05-27 2016-11-03 Kyma Medical Technologies Ltd. Microwave monitoring of heart function
WO2012058903A1 (fr) * 2010-11-05 2012-05-10 四川亚连科技有限责任公司 Procédé de préparation de gaz naturel de synthèse à l'aide de gaz produit à partir de paille
US9012523B2 (en) 2011-12-22 2015-04-21 Kellogg Brown & Root Llc Methanation of a syngas
US20150052812A1 (en) * 2013-08-20 2015-02-26 Philip James Scalzo Oxygen-Deficient Thermally Produced Processed Biogas from Beneficiated Organic-Carbon-Containing Feedstock

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