EP0062115A1 - Verfahren zur katalytischen Vergasung von Kohle in einer Wirbelschicht - Google Patents

Verfahren zur katalytischen Vergasung von Kohle in einer Wirbelschicht Download PDF

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Publication number
EP0062115A1
EP0062115A1 EP81301436A EP81301436A EP0062115A1 EP 0062115 A1 EP0062115 A1 EP 0062115A1 EP 81301436 A EP81301436 A EP 81301436A EP 81301436 A EP81301436 A EP 81301436A EP 0062115 A1 EP0062115 A1 EP 0062115A1
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EP
European Patent Office
Prior art keywords
oxygen
catalyst
coal
volume percent
process according
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EP81301436A
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English (en)
French (fr)
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EP0062115B1 (de
Inventor
Charles Alfred Euker, Jr.
Robert Dale Wesselhoft
John Jacob Dunkleman
Dolores Catherine Aquino
Toby Ronald Gouker
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ExxonMobil Technology and Engineering Co
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Exxon Research and Engineering Co
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Application filed by Exxon Research and Engineering Co filed Critical Exxon Research and Engineering Co
Priority to EP81301436A priority Critical patent/EP0062115B1/de
Priority to DE8181301436T priority patent/DE3171541D1/de
Priority to ZA00812817A priority patent/ZA812817B/xx
Priority to AU70523/81A priority patent/AU7052381A/en
Priority to BR8103006A priority patent/BR8103006A/pt
Publication of EP0062115A1 publication Critical patent/EP0062115A1/de
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    • 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
    • C10J3/46—Gasification of granular or pulverulent flues in suspension
    • C10J3/48—Apparatus; Plants
    • C10J3/482—Gasifiers with stationary fluidised bed
    • 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
    • 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
    • C10J3/46—Gasification of granular or pulverulent flues in suspension
    • C10J3/54—Gasification of granular or pulverulent fuels by the Winkler technique, i.e. by fluidisation
    • 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
    • C10J2300/0973—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
    • C10J2300/09—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
    • C10J2300/18—Details of the gasification process, e.g. loops, autothermal operation
    • C10J2300/1807—Recycle loops, e.g. gas, solids, heating medium, water

Definitions

  • This invention relates to the gasification of coal and similar carbonaceous solids and is particularly concerned with a method for maintaining a relatively high gasifier bed density in a fluidized bed catalytic gasification process.
  • agglomerates are a problem frequently encountered in the gasification of caking coals. This is caused by plastic properties which develop when such coals are subjected to temperatures above their softening point. Upon reaching this point, generally between about 370°C and about 480°C, the coal particles begin to swell and deform due to the formation of bubbles during devolatilization. As the temperature increases, deformation becomes more severe, the coal becomes plastic and sticky, and may eventually become fragile. The sticky particles tend to agglomerate and form coherent solid masses which reduce gas permeability, and tend to block the reactor and the reactor feed lines.
  • the present invention provides an improved fluidized bed catalytic coal gasification process which results in the maintenance of a relatively high fluidized bed density in the gasification reactor.
  • relatively high fluidized bed densities normally densities above about 160 kg/m 3
  • the carbonaceous feed solids are contacted with an aqueous solution containing water-soluble gasification catalyst constituents and the resultant catalyst impregnated solids are oxidized by contact with an oxygen-containing gas at a temperature below about 250°C.
  • the catalyst constituents will comprise alkali metal constituents, preferably potassium constituents including potassium carbonate and potassium hydroxide. It has been surprisingly found that optimum fluidized bed densities are dependent upon the temperature at which the oxidation is carried out and on the concentration of oxygen in the oxygen-containing gas. Normally, the oxygen concentration will range between about 2.0 volume percent and about 21 volume percent, preferably between about 4.0 volume percent and about 15 volume percent; and the temperature will range between about 50°C and about 250°C, preferably between about 125°C and about 225°C. ' If a bituminous coal, such as Illinois No.
  • the invention is based in part upon the surprising discovery that bituminous coals impregnated with alkali metal catalyst constituents yield relatively low fluidized bed densities during gasification at elevated pressure as opposed to the relatively high densities that had been found in the past when gasification was carried out at relatively low pressures.
  • Laboratory studies designed to predict bed density by measuring the swelling tendencies of coal under pressure indicate that coal impregnated with alkali metal catalyst constituents swell when subjected to rapidly increasing temperatures at the high pressures that . are found in typical high pressure gasification reactors. These laboratory studies also show that the swelling tendencies are drastically reduced when the catalyst impregnated coal is oxidized'by contacting it with an oxygen-containing gas.
  • the studies further indicate . that careful control of the oxygen concentration and the temperature during oxidation is necessary in order to obtain optimum bed densities when gasifying the catalyzed coal at high pressures in a pilot plant fluidized bed gasifier.
  • the process of the invention provides an efficient method for the fluidized bed catalytic gasification of bituminous coals and similar carbonaceous solids that tend to agglomerate and swell at elevated temperatures and high pressures which results in relatively high densities in the fluidized bed.
  • more coal and product gas can be produced for a given size gasifier thus resulting in substantial savings especially when compared to the case where a larger gasifier or multiple gasifiers would be required in order to compensate for low bed densities.
  • the process depicted in Figure 1 is one for the production of a substitute natural gas by the fluidized bed catalytic gasification of bituminous coal, subbituminous coal, lignite, liquefaction bottoms, oil shale or similar carbonaceous solids which contain volatilizable hydrocarbon constituents and may tend to swell and agglomerate at elevated temperatures.
  • the invention is not restricted to this particular gasification process and instead may be employed in any fluidized bed gasification operation in which a catalyst is used to promote the reaction of oxygen, steam, hydrogen, carbon dioxide, or a similar gasification agent with solid carbonaceous feed material in a fluidized bed gasification reactor operated at elevated pressures.
  • the solid carbonaceous feed material that has been crushed to a particle size of about 8 mesh or smaller on the U.S. Sieve Series Scale is passed, into line 10 from a feed preparation plant or storage facility that is not shown in the drawing.
  • the solids introduced into line 10 are fed into a hopper or similar vessel 12 from which they are passed through line 14 into catalyst impregnation zone 16.
  • This zone contains a screw conveyor or similar device, not shown in the drawing, which transports the solids from one end of the zone to the other while they are being sprayed with a catalyst-containing solution supplied through line 20 and-introduced into the zone through a series of spray nozzles or similar devices 18.
  • the aqueous solution of water-soluble catalyst is recycled to line 20 through line 62 from the catalyst recovery portion of the process which is described in more detail hereinafter.
  • sufficient catalyst-containing solution is passed into the impregnation zone to thoroughly wet the coal.
  • the residence time of the coal in the catalyst impregnation zone is sufficient to allow the catalyst constituents in the solution to deposit onto and impregnate the coal or similar carbonaceous feed solids.
  • the solids leaving __ the catalyst impregnation zone will contain between about 5.0 and about 30 weight percent catalyst constituents, preferably between about 10 and about 20 weight percent.
  • the catalyst impregnation zone may be a ribbon mixer or any other device in which intimate contact between the feed solids and catalyst containing solution can be achieved.
  • the catalyst impregnated solids produced in zone 16 would be dried and passed into the gasifier. It has now surprisingly been found that when catalyst impregnated solids are gasified in a fluidized bed gasifier operated at a relatively high pressure, normally above about .35 MPa and preferably above about .7 MPa, the density of the fluidized bed is very low. This, in turn, results in the need for a larger gasifier in order to produce the desired quantities of product gas.
  • the density of the fluidized bed in the gasifier can be substantially increased thereby obviating the need for a larger gasifier by contacting the solids after they have been impregnated with the catalyst constituents with an-oxygen-containing gas at a temperature below about 250°C but preferably above ambient temperature.
  • the catalyst impregnated solids are withdrawn from zone 16 and passed through line 22 into oxidizer or similar vessel 24, which contains a fluidized bed of carbonaceous solids extending upward within the vessel above an internal grid or similar distribution device not shown in the drawing.
  • the carbonaceous solids are maintained in a fluidized state within the oxidizer by means of an oxygen-containing gas introduced into the oxidizer through bottom inlet line 26.
  • the oxygen in the gas injected into the bottom of the oxidizer reacts with complex hydrocarbon molecules in the particles that comprise the fluidized bed to form carbon dioxide, carbon monoxide and molecules containing oxygen functional groups including carboxylic acid groups and ether linkages.
  • the heat generated by these reactions serves to drive off the water in the wet solids entering the oxidizer thereby drying the particles before or during the oxidation process.
  • the oxidizer will be operated at atmospheric pressure and at a temperature between about 50°C and about 250°C, preferably between about 125°C and about 225°C.
  • the oxygen-containing gas injected into bottom inlet line 26 will normally have an oxygen concentration between about 2.0 volume percent and about 21 volume percent, preferably between about 4.0 volume percent and about 15 volume percent.
  • the oxygen-containing gas will be a mixture of air and recycle flue gas in which the oxygen concentration is controlled by the amount of recycle flue gas utilized.
  • the average residence time of the catalyst impregnated carbonaceous solids in the oxidizer will range between about 0.25 hours and about 20 hours, preferably between about 2 hours and about 8 hours.
  • the gas leaving the fluidized bed in oxidizer 24 passes through the upper section of the oxidizer, which serves as a disengagement zone where particles too heavy to be entrained by the gas leaving the vessel are returned to the bed.
  • this disengagement zone may contain one or more cyclone separators or the like for the removal of relatively large particles from the gas.
  • the gas withdrawn from the upper part of the oxidizer through line 28 will normally contain a mixture of carbon monoxide, carbon dioxide, water vapor, nitrogen, sulfur dioxide formed from the sulfur contained in the solids fed to the oxidizer and entrained fines.
  • This hot flue gas is introduced into a cyclone separator or similar device, not shown in the drawing, where the fine particulates are removed.
  • the raw, hot flue gas from which the fines have been removed is withdrawn from the separator and can be passed to a waste heat boiler or other device where its heat can be utilized to generate steam or for some other purpose.
  • a portion of the cooled flue gas is normally mixed with air to produce the oxygen-containing gas which is fed to the oxidizer through bottom inlet line 26.
  • the oxidized, catalyst impregnated carbonaceous solids produced in oxidizer 24 are withdrawn through line 30 and passed to closed hopper or similar vessel 32 from which they are discharged through a star wheel feeder or equivalent device 36 in line 34 at an elevated pressure sufficient to permit their entrainment into a stream of high pressure steam, recycle product gas, inert gas or other carrier gas introduced into line 38 via line 40.
  • the carrier gas and entrained solids are passed through line 38 into manifold 41 and fed from the manifold through lines 42 and nozzles, not shown in the drawing, into gasifier 44.
  • the feed system may employ parallel lock hoppers, pressurized hoppers, aerated standpipes operated in series, or other apparatus to raise the input feed solid stream to the required pressure level.
  • Gasifier 44 comprises a refractory lined vessel containing a fluidized bed of carbonaceous solids extending upward within the vessel above an internal grid or similar distribution device not shown in the drawing.
  • the bed is maintained in the fluidized state by means of steam introduced through line 46, manifold 48 and peripherally spaced injection lines and nozzles 50, and by means of recycle hydrogen and carbon monoxide introduced through bottom inlet line 52.
  • the particular injection system shown in the drawing is not critical, hence other methods for injecting the steam and hydrogen and carbon monoxide may be employed. In some instances, for example, it may be preferred to introduce both the steam and recycle gases through multiple nozzles to obtain a more uniform distribution of the injected fluid and reduce the possibility of channeling and related problems.
  • the injected steam reacts with carbon in the feed material in the fluidized bed in gasifier 44 at a temperature within the range between about 425°C and about 870°C, preferably between about 600°C and about .760°C, and at a pressure normally above .7 MPa.
  • the pressure will normally range between about 1.4 MPa and about 4.9 MPa and will preferably be between about 2.8 MPa and about 4.2 MPa.
  • the catalyst constituents utilized to impregnate the carbonaceous feed material in impregnation zone 16 comprise alkali metal constituents, these constituents will interact at the gasification temperature with carbon in the carbonaceous solids to form a carbon-alkali metal catalyst, which will under proper conditions equilibrate the gas phase reactions occuring during gasification.
  • the process of the invention is not limited to this type of a gasification system and can be used with any type of gasification reactor in which a fluidized bed is maintained at elevated pressures.
  • the process of the invention may employ a catalytic gasifier in which oxygen is injected into the gasifier to burn a portion of the carbonaceous material in the fluidized bed to generate the heat required to maintain the reactor in heat balance.
  • the gas leaving the fluidized bed in gasifier 44 passes through the upper section of the gasifier, which serves as a disengagement zone where particles too heavy to be entrained by the gas leaving the vessel are returned to the bed.
  • this disengagement zone may include one or more cyclone separators or the like for removing relatively large particles from the gas.
  • the gas withdrawn from the upper part of the gasifier through line 54 will normally contain methane, carbon dioxide, hydrogen, carbon monoxide, unreacted steam, hydrogen sulfide, ammonia, and other contaminants formed from the sulfur and nitrogen contained in the feed material, and entrained fines. This gas is introduced into a cyclone separator or similar device, not shown in the drawing, for removal of fine particulates.
  • the resulting raw product gas may then be passed through suitable heat exchange equipment for the recovery of heat and then processed for the removal of acid gases. Once this has been accomplished, the remaining gas, consisting primarily of methane, hydrogen, and carbon monoxide, may be cryogenically separated into a product methane stream and a recycle stream of hydrogen and carbon monoxide which is returned to the gasifier through line 52.
  • Conventional gas processing equipment can be used. Since a detailed description of this downstream gas processing portion of the process is not necessary for an understanding of the invention, it has been omitted.
  • the density of the fluidized bed is controlled by the operating conditions in oxidizer 24.
  • the catalyst impregnated carbonaceous solids fed to oxidizer 24 are preferably contacted with a gas containing between about 4 volume percent and about 15 volume percent oxygen at a temperature between about 125°C and about 225°C for a time from about 2 hours to about 8 hours.
  • the actual temperature maintained in the oxidizer will depend at least in part upon the density of the fluidized bed desired in gasifier 44 and the oxygen concentration in the gas injected into the oxidizer through bottom inlet line 26.
  • the temperature in the oxidizer will normally be between about 175°C and about 225°C.
  • the temperature in the oxidizer will normally be between about 125°C and about 175°C.
  • a residence time in the oxidizer above about 2 hours is normally sufficient to obtain the desired fluidized bed densities in gasifier 44.
  • char particles containing carbonaceous material, ash and catalyst residues are continuously withdrawn through line 56 from the bottom of the fluidized bed in gasifier 44 in order to control the ash content of the system and to permit the recovery and recycle of catalyst constituents.
  • the withdrawn solids are passed to catalyst recovery unit 58, which will normally comprise a multistage, countercurrent leaching system in which the char particles are countercurrently contacted with fresh water or some other aqueous solution introduced through line 60.
  • the first stage of the catalyst recovery unit may utilize calcium hydroxide digestion to convert water-insoluble catalyst constituents into water-soluble constituents. Such a digestion process is described in detail in U.S. Patent No. 4,219,338.
  • aqueous solution of water-soluble catalyst constituents is withdrawn from the recovery unit through line 62 and may be recycled through lines 20 and 18 to impregnation zone 16.
  • the water-soluble catalyst constituents in the aqueous solution will comprise alkali metal constituents such as alkali metal carbonate, bicarbonate, hydroxide and similar alkali metal salts active in promoting the steam gasification of coal and similar carbonaceous -solids.
  • the water-soluble catalyst will comprise potassium constituents. Particles from which substantially all the soluble catalyst constituents have been extracted are withdrawn from the catalyst recovery unit through line 64 and may be disposed of as landfill or used for other purposes.
  • carbonaceous solids impregnated with catalyst constituents are passed into oxidizer 24 where they are dried and oxidized. It will be understood that the process of the invention is not limited to the situation where the drying and oxidizing steps occur in the same vessel and is equally applicable to the situation where the wet impregnated solids from zone 16 are passed into a separate drying zone prior to introduction into oxidizer 24.
  • the nature and objects of the invention are further illustrated by the results of laboratory and pilot plant tests.
  • the first series of tests illustrates that the laboratory swelling index for a bituminous coal impregnated with potassium hydroxide rises and then falls as pressure increases.
  • the second series of tests illustrates that the laboratory swelling index can be maintained at a relatively constant value below 1.0 by oxidizing the potassium hydroxide impregnated coal prior to subjecting it to the swelling test.
  • the third series of tests illustrates that the density of the fluidized bed in a pilot plant gasifier similar to the one depicted in Figure 1 increases as the laboratory swelling index of the feed coal decreases.
  • the fourth series of tests illustrates that the minimum laboratory swelling index and therefore maximum fluidized bed density is dependent upon the temperature of the oxidation and the concentration of oxygen in the oxidizing gas.
  • the ratio of the height of coal in the tube after heating to the height before heating was then calculated and is referred to as the laboratory swelling index.
  • the results of this series of tests is set forth in Figure 2.
  • the swelling index increases rapidly as the pressure increases up to about 4 MPa and then begins to decrease. This observed trend appears to be independent of the gaseous atmosphere in which the impregnated coal is heated.
  • swelling indices above 1.05 are indicative of relatively low gasifier fluidized bed densities.
  • the second series of tests was conducted in the same general manner as discussed in relation to the first series of tests except the potassium hydroxide impregnated coal was mildly oxidized before samples were placed into the quartz tube and subjected to high temperatures at various predetermined pressures in a hydrogen atomosphere.
  • the oxidation was conducted by placing about-200 grams of potassium hydroxide impregnated Illinois No. 6 coal in a bench scale fluidized bed oxidation unit operated at atmospheric pressure and at a temperature of about 200°C.
  • the oxidizing gas, a mixture of nitrogen and air contained about 6 volume percent oxygen and was passed upward through the impregnated coal particles for 6 hours at a superficial velocity of about .03 meters per second.
  • the results of this series of tests are also set forth in Figure 2.
  • the third series of tests was carried out in a pilot plant somewhat similar to the one depicted in Figure 1.
  • Illinois No. 6 coal was sprayed with an aqueous solution of potassium hydroxide, and the wet coal was passed through a series of screw dryers in which the impregnated coal was dried by indirect contact with steam.
  • the dry coal was then passed into a fluidized bed oxidation vessel in which it was contacted with a mixture of nitrogen and oxygen.
  • the vessel was steam jacketed in order to control the temperature during oxidation.
  • the oxidized, potassium hydroxide impregnated coal was then passed into a fluidized bed gasifier in which it was contacted with a mixture of steam, hydrogen, and carbon monoxide at a temperature of about 700°C and at a pressure of about 1.86 MPa.
  • the swelling indices of the various samples of oxidized, potassium hydroxide impregnated coal as determined by the laboratory technique appear to correlate well with the fluidized bed densities as measured in the pilot plant gasifier. As the swelling index increases, the fluidized bed density decreases. Although all the points plotted in the figure are for samples of potassium hydroxide impregnated coal that had been subjected to oxidation, the low fluidized bed densities observed in some of the runs are thought to be due to the fact that the pilot plant oxidation was ineffective for one reason or the other. Possible explanations for achieving ineffective oxidation include temperatures in the oxidation vessel that were either too high or too low and residence times that were too short or too long.
  • the fourth series of tests illustrates that the conditions under which the catalyst impregnated coal is oxidized are critical in obtaining optimum swelling indices and therefore maximum gasifier fluidized bed densities.
  • Illinois No. 6 coal was mixed with an aqueous solution of potassium hydroxide or potassium carbonate and the resultant slurry was placed in a vacuum oven and dried in a nitrogen atmosphere.
  • Samples of the dried and catalyst impregnated coal were then oxidized in an atmospheric bench scale fluidized bed oxidation unit by fluidizing each sample with a mixture of nitrogen and oxygen at various temperatures and residence times. The oxygen concentration of the fluidizing gas was also varied.
  • the swelling index of each sample of oxidized, catalyst impregnated coal was then measured in the same manner as discussed in relation to the third series of tests. The results of this series of tests are set forth in Figure 4.
  • the laboratory swelling index decreases with rising temperature to a minimum and then increases as the temperature continues to rise.
  • the temperature at which the minimum swelling index occurs appears to be dependent on the concentration of oxygen in the fluidizing gas.
  • low swelling indices indicate high gasifier fluidized bed densities.
  • the critical temperature range for an oxygen concentration of 5.25 volume percent is between about 175°C and about 225°C and for an oxygen concentration of 10.5 volume percent is between about 125°C and about 175°C.
  • the invention provides a process which results in high fluidized bed densities when coal or similar carbonaceous materials impregnated with catalyst constituents are gasified at elevated pressures. As a result, the number and size of the gasifiers required to carry out the gasification are reduced thereby lowering the overall cost of the process.

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  • Chemical & Material Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Combustion & Propulsion (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Organic Chemistry (AREA)
  • Industrial Gases (AREA)
  • Devices And Processes Conducted In The Presence Of Fluids And Solid Particles (AREA)
EP81301436A 1981-04-02 1981-04-02 Verfahren zur katalytischen Vergasung von Kohle in einer Wirbelschicht Expired EP0062115B1 (de)

Priority Applications (5)

Application Number Priority Date Filing Date Title
EP81301436A EP0062115B1 (de) 1981-04-02 1981-04-02 Verfahren zur katalytischen Vergasung von Kohle in einer Wirbelschicht
DE8181301436T DE3171541D1 (en) 1981-04-02 1981-04-02 A fluidised bed catalytic coal gasification process
ZA00812817A ZA812817B (en) 1981-04-02 1981-04-28 Fluidized bed catalytic coal gasification process
AU70523/81A AU7052381A (en) 1981-04-02 1981-05-13 Fluidized bed catalytic gasification of coal
BR8103006A BR8103006A (pt) 1981-04-02 1981-05-14 Processo para gaseificacao catalitica em leito fluidizado de solidos carbonaceos

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Application Number Priority Date Filing Date Title
EP81301436A EP0062115B1 (de) 1981-04-02 1981-04-02 Verfahren zur katalytischen Vergasung von Kohle in einer Wirbelschicht

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EP0062115A1 true EP0062115A1 (de) 1982-10-13
EP0062115B1 EP0062115B1 (de) 1985-07-31

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AU (1) AU7052381A (de)
BR (1) BR8103006A (de)
DE (1) DE3171541D1 (de)
ZA (1) ZA812817B (de)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0134344A1 (de) * 1983-08-24 1985-03-20 Exxon Research And Engineering Company Wirbelbettvergasung ausgeschiedener Kohle

Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2654664A (en) * 1948-04-05 1953-10-06 Consolidation Coal Co Gasification of carbonaceous solids
US3615299A (en) * 1969-06-04 1971-10-26 Chevron Res Hydrogen production by reaction of carbon with steam or steam and oxygen
US3884649A (en) * 1973-10-29 1975-05-20 Inst Gas Technology Coal pretreater and ash agglomerating coal gasifier
US3970434A (en) * 1974-10-07 1976-07-20 The United States Of America As Represented By The United States Energy Research And Development Administration Process for reducing sulfur in coal char
GB1462723A (en) * 1974-05-21 1977-01-26 Westvaco Corp Process for rendering coal non-agglomerative
US4057402A (en) * 1976-06-28 1977-11-08 Institute Of Gas Technology Coal pretreatment and gasification process
DE2757918A1 (de) * 1977-12-24 1979-06-28 Davy Powergas Gmbh Verfahren zur konrinuierlichen einspeisung von wasserhaltigen, fossilen brennstoffen in eine unter druck arbeitende vergasungs- und/oder verbrennungszone
US4251227A (en) * 1978-08-02 1981-02-17 Othmer Donald F Method for producing SNG or SYN-gas from wet solid waste and low grade fuels

Patent Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2654664A (en) * 1948-04-05 1953-10-06 Consolidation Coal Co Gasification of carbonaceous solids
US3615299A (en) * 1969-06-04 1971-10-26 Chevron Res Hydrogen production by reaction of carbon with steam or steam and oxygen
US3884649A (en) * 1973-10-29 1975-05-20 Inst Gas Technology Coal pretreater and ash agglomerating coal gasifier
GB1462723A (en) * 1974-05-21 1977-01-26 Westvaco Corp Process for rendering coal non-agglomerative
US3970434A (en) * 1974-10-07 1976-07-20 The United States Of America As Represented By The United States Energy Research And Development Administration Process for reducing sulfur in coal char
US4057402A (en) * 1976-06-28 1977-11-08 Institute Of Gas Technology Coal pretreatment and gasification process
DE2757918A1 (de) * 1977-12-24 1979-06-28 Davy Powergas Gmbh Verfahren zur konrinuierlichen einspeisung von wasserhaltigen, fossilen brennstoffen in eine unter druck arbeitende vergasungs- und/oder verbrennungszone
US4251227A (en) * 1978-08-02 1981-02-17 Othmer Donald F Method for producing SNG or SYN-gas from wet solid waste and low grade fuels

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0134344A1 (de) * 1983-08-24 1985-03-20 Exxon Research And Engineering Company Wirbelbettvergasung ausgeschiedener Kohle

Also Published As

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DE3171541D1 (en) 1985-09-05
BR8103006A (pt) 1983-08-23
AU7052381A (en) 1982-10-07
EP0062115B1 (de) 1985-07-31
ZA812817B (en) 1982-05-26

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