US3927996A - Coal injection system - Google Patents

Coal injection system Download PDF

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US3927996A
US3927996A US444614A US44461474A US3927996A US 3927996 A US3927996 A US 3927996A US 444614 A US444614 A US 444614A US 44461474 A US44461474 A US 44461474A US 3927996 A US3927996 A US 3927996A
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coal
gas
fluidized bed
particles
nozzle
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Christian W Knudsen
Rosenberg Hermann E Von
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ExxonMobil Technology and Engineering Co
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Exxon Research and Engineering Co
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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
    • C10J3/463—Gasification of granular or pulverulent flues in suspension in stationary fluidised beds
    • 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
    • C10J3/72—Other features
    • C10J3/723—Controlling or regulating the gasification process
    • 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
    • C10J3/72—Other features
    • C10J3/78—High-pressure apparatus
    • 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
    • C10J3/72—Other features
    • C10J3/82—Gas withdrawal means
    • C10J3/84—Gas withdrawal means with means for removing dust or tar from the 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
    • 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
    • C10J2300/0913—Carbonaceous raw material
    • C10J2300/0946—Waste, e.g. MSW, tires, glass, tar sand, peat, paper, lignite, oil shale
    • 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
    • C10J2300/0956—Air or oxygen enriched air
    • 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
    • C10J2300/0959—Oxygen
    • 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
    • C10J2300/0976—Water as steam
    • 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
    • C10J2300/1603—Integration of gasification processes with another plant or parts within the plant with gas treatment
    • C10J2300/1606—Combustion processes
    • 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

  • ABSTRACT A caking coal or similar carbonaceous solid is introduced into a fluidized bed containing char particles at a temperature in excess of the coal resolidification point by entraining coal particles less than about 8 mesh on the Tyler Screen Scale in a gas stream preheated to a temperature in excess of about 300 F.
  • Coal gasification and similar processes carried out in high temperature fluidized beds normally require the entrainment of finely divided coal particles in a stream of gas and the injection of this stream into the fluidized bed through a suitable nozzle. Although such processes work satisfactorily with noncaking coals, they frequently pose problems where highly caking coals are used. Coals of this latter type are generally characterized by oxygen contents of 15 weight percent or less, hydrogen contents of 5 weight percent or more, and Free Swelling Index values in the upper part of the l to range. Experience has shown that such coals tend to devolatilize rapidly and begin to soften at temperatures in excess of about 600F.
  • the temperature at which softening starts depends upon the coal composition and is therefore higher in some coals than in others. Above this initial softening point, a coal particle begins to undergo deformation and tends to become rounded, rather than angular, in shape. The outer surface of the particle becomes plastic and small bubbles begin to appear in the coal. As the temperature is increased, deformation becomes more intense, the particle swells, the bubbles enlarge, and the walls surrounding the bubbles may rupture. At a still higher temperature, referred to as the resolidification point, the particle becomes a hard, porous mass and undergoes no further change in appearance. The resolidification point also depends upon the composition of the particular coal but generally occurs at a temperature of about 800F. or higher.
  • This invention provides an improved process for the introduction of caking coals and similar carbonaceous solids into high temperature fluidized beds which alleviates the difliculties outlined above and permits the use of highly caking coals and similar materials in fluidized bed gasification operations and similar processes without the severe problems that have characterized earlier efforts to use such materials.
  • caking coals and related materials can readily be injected into fluidized beds containing char particles at temperatures,
  • This process avoids the necessity for pretreatment of the coal to reduce its agglomerating tendency, permits the carrying out of gasification and similar reactions with apparatus less complex than that required in many of the earlier processes, is less expensive than processes suggested heretofore, and has other advantages over prior art processes. As a result of these advantages, the process of the invention has many potential applications.
  • FIG. 1 in the drawing is a schematic diagram of a coal gasification process in which the process of the invention is employed for the introduction of a highly caking coal into a high temperature fluidized bed gasifier;
  • FIG. 2 is an enlarged sectional view through a coal injection nozzle suitable for'purposes of the invention.
  • FIG. 3 is an enlarged sectional view through an alternate type of nozzle which may be employed for purposes of the invention.
  • the process depicted in FIG. 1 of the drawing is a process for the production of a methane-containing gas from bituminous coal, subbituminous coal, lignite or similar carbonaceous solids which contain volatilizable hydrocarbon constituents and may tend to agglomerate at elevated temperatures.
  • the solid feed material employed in the process preferably a bituminous or lower rank coal, is introduced into the system through line from a preparation plant, not shown, in which the coal or other material may be crushed, dried and screened or from a storage facility which does not appear in the drawing.
  • the coal or other carbonaceous solid is introduced into the system in a finely divided state, normally less than about 8 mesh on the Tyler Screen Scale.
  • the carrier gas stream is introduced into the system at a pressure between about 100 and about 1,500 psig, depending upon the pressure at, which gasifier 15 is operated and the solid feed material employed, and at a temperature in excess of about 300F. but below the initial softening point of the coal or other carbonaceous feed material.
  • the use of carrier gas input temperatures in the range of from about 400 to about 550F. is generally preferable.
  • the coal particles introduced through line 13, preferably less than about mesh in size on the Tyler Screen Scale, are suspended in hot input carrier gas fed through line 14 in a ratio between about 0.2 and about 2.0 pounds of coal per pound of carrier gas.
  • the optimum ratio for a particular system will depend in part upon the coal particle size and density, the molecular weight of the gas employed, the temperature of the coal and input gas stream, and other factors. In general, ratios between about 0.5 and about 1.5 pounds of coal per pound of carrier gas are preferred.
  • the resultant stream of carrier gas and entrained coal particles is then fed through a fluid-cooled nozzle 16 into the gasifier.
  • the cooling fluid which will normally be low pressure steam but may also be water or other fluid, may be introduced into the nozzle through line 17 and 4 recovered by means of line 18. Suitable nozzles are shown in greater detail in FIGS. 2 and 3 of the drawing.
  • the nozzle structure shown in FIG. 2 includes an outer nozzle housing 19 which is welded in place to the outer shell 20 of the gasifier and extends downwardly at an acute angle to the longitudinal axis of the gasifier.
  • a removable nozzle assembly including an inner injection tube 22, an intermediate cylindrical baffle 23 and an outer coolant tube 24. These members are welded or otherwise connected near the upper end of the nozzle assembly to a cap or flange 25 which is held in place by means of bolts 26. Inlet and outlet tubes 27 and 28 extend through the cap to permit the introduction and withdrawal of coolant.
  • the injection and coolant tubes 22 and 24 are connected at their lower ends by member 29.
  • Baffle 23 stops short of the end connection. Coolant introduced into the assembly thus flows downwardly between the baffle and the injection tube and then flows upwardly through the annular space between the outer coolant tube and the intermediate bafi'le. This permits control of the temperature of the gas and entrained coal injected into the gasifier and avoids temperatures above the initial softening point of the coal due to heat transfer from the gasifier before the coal reaches the fluidized bed.
  • FIG. 3 in the drawing depicts an alternate type of nozzle which may be employed if desired.
  • This nozzle includes an outer nozzle housing 30 which is welded to the outer shell20 of the gasifier and e'xtends downwardly at an angle to the longitudinal axis of the gasifier.
  • An inner ejection tube 31 andan outer'coolant tube 32 which extend downwardly through the housing and the ceramic lining 21 of the gasifier, are welded or otherwise connected to flange 33 which contains coolant inlet tube 34 and is held in place by bolts 35.
  • the injection and coolant tubes are interconnected at their lower ends by a perforated member 36 containing orifices through which the coolant fluid may pass into the gasifier.
  • Carrier gas and entrained particles and cookant may thus be injected concurrently into the gasifier through this nozzle assembly.
  • the injected coolant fluid aids in maintaining the coal particles below the initial softening point and is advantageous in that it moderates the rate at which the particles are heated up within the fluidized bed. It will be understood that the process of the invention is not restricted to use of the particular nozzles shown in the drawing and that other nozzle assemblies which will permit control of the particle temperature can also be used.
  • FIG. 1 shows only one nozzle, large diameter gasifiers will normally be provided with a plurality of nozzles.
  • the gasifier 15 which is employed in the system shown in the drawing comprises a refractory-lined vessel containing a fluidized bed of char particles introduced into the lower part of the vessel through inlet line 40.
  • the inlet line extends upwardly through the bottom of the vessel to a point above grid or similar distribution device 41.
  • Steam for maintaining char particles in a fluidized state and reacting with the char to produce a synthesis gas containing substantial quantitites of hydrogen and carbon monoxide is introduced into the gasifier below the grid through manifold 42 and injection nozzles 43.
  • the installation shown utilizes four nozzles spaced at intervals about the periphery of the gasifier but a greater or lesser number may be employed if desired.
  • the steam introduced through the nozzles will normally be fed into the system at a rate within the range between about 0.5 and about 2 pounds per pound of coal feed and at a pressure between about 100 and about 1,500 psig, depending upon the gasifier operating pressure and the solid feed material used.
  • the upflowing stream and suspended char particles form a fluidized bed which extends upwardly in the gasifier to a level above the point at which the coal particles are introduced by means of nozzle 16.
  • the upper surface of this bed is indicated in the drawing by reference numeral 44.
  • the steam introduced through the manifold and steam injection nozzles reacts with carbon in the hot char particles to form synthesis gas in accordance with the reaction: H O +C H CO.
  • the hydrogen concentration in the gaseous phase of the fluidized bed is substantially zero.
  • the temperature in the steam gasification zone will generally range between about l,450 and about l,950F.
  • the gas velocities in the fluidized bed will normally range between about 0.2 and about 4.0 feet per second, preferably between about 0.5 and about 2.0 feet per second.
  • the upper part of the fluidized bed in reactor vessel '15 serves as a hydrogasification zone where the feed coal is devolatilized and a portion of the volatile matter thus liberated reacts with hydrogen generated in the steam gasification zone below to produce methane as one of the significant constituents of the product gas.
  • the point at which the coal feed stream is introduced into the gasifier through nozzle 16 and hence the location of the steam gasification and hydrogasification zones depends primarily upon the properties of the particular coal or carbonaceous solid which is employed as the feed material for the process. It is generally preferred to select the nozzle location so that the methane yield from the gasifier will be maximized and the tar yield minimized.
  • the amount of methane produced increases as the coal feed injection point is moved toward the top of the vessel.
  • the tar formed from the input coal which has a tendency to foul downstream processing equipment, normally increases in amount as the coal injection point is moved upwardly and decreases as the coal injection point is moved toward the bottom of the reaction vessel, other operating conditions being the same.
  • the coal feed stream should therefore generally be introduced into the gasifier at a point where the hydrogen concentration in the gas phase is in excess of about 20% by volume, preferably between and about 50% by volume.
  • the upper surface 44 of the fluidized bed should normally be located at a level sufiiciently above the nozzle 16 to provide at least about 4 seconds of residence time for the gas phase in contact with the fluidized solids in the hydrogasification zone.
  • a residence time for the gas in contact with the solid phase above the coal injection point of between 10 and about 20 seconds is normally preferred. It will be understood, of course, that the optimum hydrogen concentration at the coal injection point and the gas residence time above that point will vary with different types and grades of feed coal and will also change with variations in the gasifier temperature, pressure, steam rate, and other process variables. Higher rank coals normally require somewhat more severe reaction conditions and longer residence times to obtain high methane yields than do coals of lower rank. Similarly, high reaction temperatures and steam rates generally tend to increase the hydrogen concentration in the gas phase and thus reduce the solids residence time needed to secure acceptable methane yields from a particular feed coal.
  • the temperature in gasifier 15 is normally maintained within the range between about 1,450 and about l,950F. This is above both the initial softening point and the resolidification point of the coal fed into the gasifier through nozzle 16.
  • the entrained coal particles emerging from the nozzle into the fluidized bed therefore tend to heat up rapidly and quickly reach the initial softening point.
  • the nozzle In order to avoid excessive agglomeration in the vicinity of the nozzle, the
  • carrier gas in-which the particles are entrained is injected into the fluidized bed at a superficial gas velocity sufficient to move the particles a significant distance into the bed before they soften, become sticky and begin to swell.
  • the turbulence within the fluidized bed and the presence of a carrier gas injected with the particles tend to keep the particles separate from one another and thus reduce the amount of agglomeration which occurs.
  • Some agglomeration due to contact between the hot sticky particles undergoing devolatilization and contact with hot char particles suspended in the bed will take place, however, and will tend to increase the average size of the particles within the fluidized bed. Swelling of the injected particles as they are heated from the initial softening point to the resolidification point also tends to increase the average particle size.
  • the amount of swelling which takes place depends upon the composition of the particular coal being gasified and the particle size.
  • the small surface-to-volume ratios of relatively large particles may lead to excessive swelling and the production of large brittle fragments which quickly degrade to fines in the turbulent fluidized bed and hence an average feed particle size of about 20 mesh or smaller is normally preferred.
  • the velocity of the carrier gas stream containing the entrained feed coal particles is regulated to produce controlled attrition of the feed particles.
  • varying the input carrier gas velocity produces significant changes in the amount of attrition which takes place within the bed and that this can be used to regulate the bed particle size.
  • Gases from the fluidized bed move upwardly from the upper surface 44 of the bed, carrying entrained solids with them. These gases are withdrawn from gasifier 15 through line 50 and passed to cyclone separator or similar device 51 where the larger particles are separated from the gas stream.
  • the solids content of this overhead gas can be monitored by withdrawing gas samples through line 52 and determining their solids contents, by means of optical monitoring equipment based on the transmisssion of light through the flowing gas stream, by the periodic insertion of filters into the gas stream, by means of radioactive monitoring equipment including a source and detector mounted on the gas line, or by other methods familiar to those skilled in the art. Equipment which may be employed for such monitoring is available commercially and may be used if desired.
  • the amount of solids entrained in the gas stream will depend upon the particular operating conditions employed, the composition of the feed coal, the coal particle size and other factors. Assuming that the coal feed rate and other conditions are held constant, an increase in the carrier gas velocity through nozzle 16 will normally produce an increase in particle attrition within the bed. If excess agglomeration is occuring, such an increase will tend to reduce the average particle size .without producing excessive fines. An overly high carrier gas velocity, on the other hand, may tend to produce a marked increase in the fines content of the overhead gas. By monitoring the solids content of the gas stream and adjusting the carrier gas velocity as necessary, an optimum gas velocity for a particular coal and a particular set of operating conditions can thus be determined.
  • the gas stream taken overhead from separation unit 51 through line 53 will normally contain entrained fines too small to be taken out by separation unit 51.
  • This gas stream may therefore be passed to a second centrifugal separator or similar unit 54 for the removal of additional fine particles.
  • the raw product gas is withdrawn overhead from this second separation unit through line 55 and may be'passed to conventional downstream facilities for cooling, the removal of water and any additional entrained solids, treatment to take out carbon dioxide and sulfur compounds, and the like. If desired, the treated gas can then be passed through a catalytic shift conversion unit to adjust the hydrogento-carbon monoxide ratio and then introduced into a methanation unit to increase the amount of methane and raise the B.t.u. content of the gas. All of these downstream gas treating and processing steps may be carried out in a conventional manner and will be familiar to those skilleld in the art.
  • the heat required to sustain the overall endothermic reaction taking place in gasifier 15 and maintain the operating temperature of from about l,450 to about 1,950F. is provided by withdrawing a portion of the char solids from the fluidized bed in the gasifier through line 60 and passing these solids, together with solid particles recovered from separation units 51 and 53 through diplegs 61 and 62, through connector 63, and into vertical riser 64 at the lower end of transfer line burner 65. Steam may be introduced into the system through line 66, and through line 67 if desired, to promote smooth flow of the dense phase solids stream and avoid clogging problems.
  • a fines return gas normally recycled flue gas containing suspended solids recovered from the overhead flue gas stream as described hereafter, may be injected into the lower end of connector 63 through line 68 and used to aid in lifting the solid particles withdrawn from the gasifier up wardly through line 64 into the burner.
  • An oxygen-containing gas preferably a mixture of air and sufficient recycle flue gas to give a molecular oxygen content less than about 10% by volume, is introduced into the lower end of the burner through line 69 and peripherally spaced nozzles 70 in a quantity sufficient to establish dilute phase flow of the solids and initiate combustion of the char particles.
  • Oxygen-containing gas having a higher molecular oxygen content than that introduced at the lower end of the burner is supplied to the burner through line 71 and peripherally spaced nozzles 72. It is generally preferred to introduce this additional oxygen-containing gas at two or more vertically-spaced levels along the burner in order to achieve better control of the combustion process and again avoid localized overheating and the problems that may accompany it.
  • air or other oxygen-containing gas is introduced at two additional levels by means of line 73 and peripherally spaced nozzles 74 and 75.
  • the levels at which the oxygen-containing gas is introduced into the burner are generally spaced sufiiciently far apart so that substantially all of the oxygen introduced at one level is consumed before the gas and entrained solids reach the next level. This generally provides better control of the temperatures within the burner, results in more efficient combustion, and reduced the carbon monoxide content of the gas stream.
  • the total amount of oxygen introduced in this manner should be sufficient to raise the temperature of the solids passing upwardly through the burner by about 50 to about 300 F. and thus provide sufficient heat upon return of the solids to the gasifier to maintain the gasification reactions.
  • the gases and entrained solids leaving the upper end of burner 65 are passed into a cyclone separator or similar separation unit 77 where the larger solids are removed from the gas stream and returned through dipleg 78 and connector 79 to the gasifier bottom intake line 40.
  • Steam may be introduced into the solids return system through lines 80 and 81, and through line 82, if desired, to promote proper flow of the solids stream and avoid clogging difficulties.
  • the hot solid char particles thus returned to the gasifier provide the heat required to sustain the steam gasification reaction taking place in steam gasification zone 45 and that necessary for the hydrogasification reactions taking place in hydrogasification zone 46. As indicated earlier, these hot char particles will normally be at a temperature well in excess of the coal resolidification point.
  • the flue gas is taken overhead from separator 84 through line 86.
  • the flue gas may be passed to still another cyclone separator for the elimination of very fine entrained solids consisting primarily of ash or may be scrubbed for the removal of such solids.
  • the flue gas stream can then be treated as necessary to comply with applicable pollution regulations and then discharged into the atomsphere.
  • a portion of the flue gas stream may be recycled for use as a fines return gas and as a diluent gas in the burner.
  • Conventional procedures can be used for treatment of the flue gas to remove pollutants before its discharge.
  • the process of the invention provides an improved method for the introduction of coal and similar materials into high temperature fluidized beds and that this method has advantages over methods employed in the past.
  • the method has been described primarily in terms of coal gasification, it will be understood that it is not restricted to gasification operations and may instead be used in other fluidized bed operations in which agglomeration and related difficulties are apt to be encountered.
  • use of the method of the invention permits the injection of highly caking coals without severe deposit formation, excessive fines production and other difficulties which have generally precluded the use of such coals heretofore.
  • the feed solids will normally be injected into the fluidized bed at locations different from that at which the solids are injected into a fluidized bed used for gasification purposes.
  • Materials other than coal which contain volatilizable hydrocarbon constituents have an initial softening point and a somewhat higher resolidification point, and often behave in much the same manner as caking coals in high temperature fluidized beds, lignite for example, can also be employed.
  • said carrier gas comprises a methane-containing gas produced by coal gasification.
  • a process as defined by claim 1 wherein said fluidized bed is a bed of char particles fluidized by steam.

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  • Engineering & Computer Science (AREA)
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  • Devices And Processes Conducted In The Presence Of Fluids And Solid Particles (AREA)
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Cited By (39)

* Cited by examiner, † Cited by third party
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