EP0243801B1 - Cycle combiné gaz et vapeur avec lit fluidisé - Google Patents

Cycle combiné gaz et vapeur avec lit fluidisé Download PDF

Info

Publication number
EP0243801B1
EP0243801B1 EP87105588A EP87105588A EP0243801B1 EP 0243801 B1 EP0243801 B1 EP 0243801B1 EP 87105588 A EP87105588 A EP 87105588A EP 87105588 A EP87105588 A EP 87105588A EP 0243801 B1 EP0243801 B1 EP 0243801B1
Authority
EP
European Patent Office
Prior art keywords
fluidized bed
combustion chamber
fuel
firing system
gas
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Expired
Application number
EP87105588A
Other languages
German (de)
English (en)
Other versions
EP0243801A1 (fr
Inventor
Wolfgang Dipl.-Ing. Schemenau
Jürgen Ing. grad. Bennert
Dietrich Dr. Ing. Ceelen
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
ASEA BROWN BOVERI AKTIENGESELLSCHAFT
Original Assignee
ASEA BROWN BOVERI AG
Asea Brown Boveri AG Germany
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by ASEA BROWN BOVERI AG, Asea Brown Boveri AG Germany filed Critical ASEA BROWN BOVERI AG
Priority to AT87105588T priority Critical patent/ATE48673T1/de
Publication of EP0243801A1 publication Critical patent/EP0243801A1/fr
Application granted granted Critical
Publication of EP0243801B1 publication Critical patent/EP0243801B1/fr
Expired legal-status Critical Current

Links

Images

Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
    • F01K23/00—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids
    • F01K23/02—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled
    • F01K23/06—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle
    • F01K23/061—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with combustion in a fluidised bed

Definitions

  • the invention relates to a method for generating electrical energy according to the preamble of patent claim 1.
  • the invention also relates to a combined gas turbine steam power plant for carrying out the method according to the preamble of patent claim 2.
  • a plant of this type has become known from the prior art, in which steam is generated with the aid of a fluidized bed combustion and is fed to a steam turbine (US Pat. No. 4,387,560).
  • the steam is released and the power output is fed to an electrical generator to generate electricity.
  • ambient air is simultaneously sucked in and compressed by a compressor, it heats in a heat exchanger arranged in the fluidized bed furnace, is further heated in a downstream combustion chamber and then fed to a gas turbine which drives another electrical generator.
  • a fuel gas is used, which is generated from the solid fuels of the fluidized bed furnace.
  • the object of the invention is therefore to provide a method or a plant of the type mentioned, in which the fuel gas can be produced from the fuel of the fluidized bed furnace with little effort and therefore inexpensively.
  • the fuel gas required to operate the combustion chamber is thus generated in the fluidized bed. This simplifies the process and eliminates the need for special measures for gas generation and for transporting the fuel from the location of the gas generation into the combustion chamber of the fluidized bed furnace. It should also be emphasized that no special measures are required to supply the heat required for the gasification or degassing.
  • the fuel gas line of the additional furnace must be connected to the combustion chamber of the fluidized bed furnace.
  • the connection is preferably made above the fuel supply point in an area that adjoins the fuel supply upwards and has a vertical extension of 1/5 to 1/15 of the vertical thickness of the fluidized bed.
  • the fluidized bed itself has a thickness in the vertical direction which is approximately 30 to 60% of the clear height of the combustion chamber.
  • the fuel gas line in the gasification or degassing area through several openings, which preferably run in one plane and are approximately evenly distributed on the periphery of the combustion chamber, to the Combustion chamber is connected.
  • the fuel gas line is preferably connected to a ring line surrounding the combustion chamber, which in turn has connections to the openings. There are advantageously four to eight openings.
  • part of the fluidized bed combustion fuel is fed into the part of the circulation duct leading back to the combustion chamber and the combustion chamber for gas supply with the gasification or Degassing area connected.
  • the fuel gas generation is outside the actual combustion chamber, but remains a component of the fluidized bed combustion, whereby in particular the heating of the fuel for degassing or gasification can be carried out without any particular additional effort. The same applies to the transport of the degassed or gasified fuel into the combustion chamber.
  • the circulation channel seen in the direction of circulation, has a fuel gas collector downstream of the fuel feed point in the form of a hood-like extension of the circulation channel to which the combustion chamber is connected for supplying the fuel gas.
  • a particularly preferred development of the invention consists in that a stationary second fluidized bed with a fluidized bed with a defined surface is inserted into the circulation channel, into which part of the fluidized bed combustion fuel can be fed, and which contains a low-oxygen gas, preferably exhaust gas from the fluidized bed combustion, as the fluidizing medium and can be supplied for at least partial degassing of the fuel.
  • a second fluidized bed is therefore in the circulation channel added, which is operated as a fuel degasser. The heat required for the degassing is introduced into the second fluidized bed by the hot ash and / or slag particles circulating in the circulation channel, while the fluidized bed is generated by the supplied oxygen-poor gas.
  • a very expedient embodiment of the above-mentioned teaching, which optimizes the fuel gas generation, is that above the second fluidized bed there is a fuel gas collecting space connected to the combustion chamber, that the part of the circulation channel entering the second fluidized bed, viewed in the direction of circulation, ends in the fluidized bed, that the part of the circulation channel leading from the second fluidized bed is connected to at least one overflow weir which laterally delimits the fluidized bed and the height of which determines the vertical thickness of the fluidized bed.
  • the steam power plant of the combined gas turbine steam power plant is provided with a fluidized bed combustion, which is provided with the reference number 10 in its entirety.
  • the fluidized bed furnace has a vertical combustion chamber 12 in a housing 11, in the lower region of which the fluidized bed 14 is provided, which has a defined surface 16 within the combustion chamber 12, and is therefore a stationary fluidized bed.
  • the combustion chamber preferably has a circular cross section and is surrounded by a vertical combustion chamber wall.
  • solid, small-sized fuel preferably hard coal, lignite or oil shale with a grain size of 0.5 to 15 mm
  • a conveyor above a horizontal nozzle bottom 18 arranged in the lower end region at the fuel supply point 20 by means of a line 13 .
  • the distance between the nozzle base 18 and the fuel supply point 20 is approximately 1/20 to 1/5 of the vertical thickness of the fluidized bed 14, preferably 1/8 to 1/5.
  • the fuel is expediently mixed with additives such as small pieces of dolomite or limestone in order to bind sulfur components that are introduced into the combustion chamber with the fuel in the fluidized bed during the combustion process.
  • the nozzle base 18 arranged in the lower region of the combustion chamber 12 has a multiplicity of openings through which the combustion air or the fluidizing air is fed to the fluidized bed.
  • a deduction for ash portions is not shown in the drawings, which leads downward from the nozzle bottom 18 into the outside space.
  • an exhaust gas duct 19 is connected, which leads to a chimney (not shown) through an exhaust gas purification system 21, which contains dedusters, cleaners and, if necessary, a denitrification device for removing nitrogen oxides.
  • a heat exchanger 22 for. B. in the form of coils, provided in the combustion chamber 12, which is connected on the one hand by the pipe 24 to the pressure side of the outside air compressor 26 of the gas turbine system and on the other hand is connected by a pipe 28 to the inlet of the expansion turbine 30.
  • the combustion chamber 32 is inserted into the pipeline 28.
  • the air is heated directly, i.e. H. mixed with the hot flue gases, and then fed to the turbine 30.
  • the fuel gas for the gas burner 36 which is part of the combustion chamber, is removed from the combustion chamber 12 of the fluidized bed furnace through the fuel gas line 44.
  • at least one opening 45 is provided in the combustion chamber wall.
  • the opening 45 is expediently arranged in the region of the horizontal fuel supply plane.
  • the opening 45 is circular and has a diameter that is equal to 1/20 to 1/10 of the diameter of the combustion chamber.
  • the fuel supply level runs through the fuel supply point 20; the opening 45 is arranged in a region which has a vertical extent which is equal to 1/5 to 1/15 of the vertical thickness of the fluidized bed 14.
  • a ring line preferably runs around the vertical combustion chamber wall and communicates with a plurality of openings 45 distributed approximately uniformly on the combustion chamber wall. The openings are in a horizontal plane.
  • the fuel gas line 44 is then connected to the ring line.
  • the ring line is not shown in Figure 1.
  • a filter device 42 is inserted into the fuel gas line 44. The solids retained in the filter device are fed back to the fluidized bed furnace.
  • the fuel gas cleaned in the filter device 42 is compressed in a compressor 35 and fed into the gas burner 36 and burned in the combustion chamber 34 of the combustion chamber 32.
  • the outlet of the turbine 30 is connected through the combustion air line 46 to that space 25 of the fluidized bed combustion which is located below the nozzle base 18 and which has a vertical height which is equal to 1/4 to 1/5 of the vertical thickness of the fluidized bed 14. Die
  • the suction side of the compressor 26 is connected to the environment 50 by a suction line 48.
  • the shaft of the compressor 26 is coupled to the shaft of the turbine 30, and the shaft of a generator 52 is also coupled, which converts the excess energy into electrical current.
  • the steam power plant shown in a very simplified form in FIG. 1 has an evaporator 54 which is arranged in or possibly above the fluidized bed 14 and receives feed water from a feed water pump 58 through a pipeline 56.
  • the steam generated is fed to a high-pressure steam turbine 60, partially expanded there and fed to the reheater 40 through the pipeline 62. This is located in the upper end region of the combustion chamber 12 above the heat exchanger 22 and the fluidized bed 14.
  • the evaporator 54 and the reheater 40 are preferably designed as coils.
  • the reheated steam is fed through the pipeline 64 to the low-pressure steam turbine 66, expanded here and then liquefied in a condenser 68.
  • the condensate is fed to the feed water pump 58 so that the circuit is closed.
  • the two turbines 60 and 66 are coupled with their shafts and drive an electric generator 70.
  • ambient air is sucked in, compressed by the compressor 26 through the suction line 48, advantageously through a filter, and supplied to the heat exchanger 22 through the pipe 24.
  • this compressed air is heated by the flue gases of the fluidized bed furnace and fed through the pipeline 28 via the combustion chamber 32 to the turbine 30.
  • the heated air is expanded in the turbine and then fed through the combustion air line 46 as combustion air to the space 25 and thus to the fluidized bed 14.
  • the combustion air still has an overpressure of approximately 0.2 to 1 bar, the combustion air swirls the fuel and thus the formation of the fluidized bed 14 is achieved.
  • the compressed air in the heat exchanger 22 can only be heated to a correspondingly low temperature of approximately 500 to 750 ° C. which, however, is too low for economical operation of the turbine 30. This air is therefore further heated in the combustion chamber 32 after leaving the heat exchanger 22, to the extent necessary for optimal operation of the turbine 30 and as permitted for operation of the turbine with regard to its mechanical strength.
  • the air in the combustion chamber is heated to a temperature of approximately 900 to 1000 ° C.
  • the combustion chamber 32 is fired by at least one gas burner 36, which draws its fuel gas through the fuel gas line 44 from the fluidized bed furnace.
  • the fuel gas line 44 is connected in a zone of the fluidized bed 14 to the combustion chamber, in which gaseous fuel is produced by gasification or degassing of the solid fuel, such as lumpy coal. This zone is usually located directly above the level in which the solid fuel is supplied at the feed point 20.
  • gaseous fuel is produced by gasification or degassing of the solid fuel, such as lumpy coal.
  • This zone is usually located directly above the level in which the solid fuel is supplied at the feed point 20.
  • the compressed air flowing in from the heat exchanger 22 is further heated, mixed with the combustion exhaust gases, and supplied to the turbine 30.
  • this mixture containing oxygen is introduced into the space 25 as combustion air and swirl air through the combustion air line 46. From here, the air flows up through the openings in the nozzle base 18, swirls the fuel and thus causes the formation of the fluidized bed 14.
  • the fluidized bed 14 accordingly consists of the swirled fuel which burns completely in the fluidized bed.
  • the required solid fuel is introduced into the combustion chamber 12 together with the additives, such as dolomite or lime, through a line at the fuel supply point 20.
  • Burnt-out components of the fuel such as ash, are drawn off through a line (not shown).
  • the exhaust gases flow upwards in the combustion chamber, give off heat to the individual heat exchangers 54, 22, 40 and are guided through the exhaust gas duct 19 in the form of a pipe via the exhaust gas cleaning system 21 to a chimney (not shown).
  • the mechanical energy emitted by the turbine 30 serves to drive the compressor 26, the remaining energy is converted into electrical current in the electrical generator 52.
  • the feed water supplied is evaporated and superheated in the evaporator 54 in a known manner and the high pressure steam which is produced is fed to the high pressure turbine 60.
  • the steam in the reheater 40 is again overheated and fed through the pipeline 64 to the low-pressure steam turbine 66, expanded and liquefied in the condenser 68.
  • the energy obtained is released as electrical energy from generator 70 to a power grid.
  • FIG. 2 shows the area of the fluidized bed furnace 10 of FIG. 1 in one embodiment variant and as a detail. Recurring individual parts in FIG. 2 are provided with the corresponding reference numbers in FIG. 1, which are expanded by the amount 100.
  • the fluidized bed combustion system according to FIG. 2, which is provided with the reference number 110 in its entirety, has a likewise vertically running combustion chamber 112 with a preferably circular cross section, in which the evaporator 154 of the steam power plant, the heat exchanger 122 for heating the compressed air and the reheater 140 of the steam power plant are arranged one above the other.
  • a nozzle base 118 is also arranged here, the openings of which connect the combustion chamber to the space 125 arranged below it.
  • Combustion air line 146 opens into space 125 and supplies the expanded mixture of combustion chamber exhaust gas and air as combustion air to the fluidized bed from the expansion turbine.
  • the supply point 120 for supplying the fuel to the combustion chamber 112 can still be seen.
  • a discharge line for burned-out fuel is not shown for the sake of clarity. This would lead from the lower area of the combustion chamber 112 to the outside.
  • the upper end region of the combustion chamber 112 is connected to the lower end region by a circulation channel 72 running outside the combustion chamber 112.
  • the circulation channel preferably has a circular cross section.
  • the cross section is approximately 10 to 25% of the cross section of the combustion chamber 112.
  • the circulation channel has a section 74 which extends horizontally from the upper end of the combustion chamber 112 and opens into a cyclone separator 76.
  • the exhaust gas guide 119 is connected to the centric and upward leading pipe of the cyclone separator, which leads to the exhaust gas cleaning system, not shown in FIG. 2.
  • a vertically running section 78 of the circulation channel 72 is connected to the lower, tapering region of the conical cyclone separator 76, which section passes through an arc 80 into a section 82 leading to the combustion chamber 112.
  • This section 82 runs here with a slope from the bend 80 to the combustion chamber 112 and opens into the combustion chamber 112 in the vicinity of the nozzle base 118, preferably directly above the nozzle base.
  • the bend has an angle of approximately 110 to 130 °.
  • the air flows through the nozzle base 118 into the combustion chamber 112 and swirls the small-sized fuel supplied at the supply point 120, a fluidized bed is formed which fills the entire combustion chamber 112 and which causes the fuel to burn completely.
  • the fluidized bed formed in the combustion chamber 112 and consisting of fuel particles circulates, starting from the upper end region of the combustion chamber 112, downward through the circulation channel 72 into the region directly above the nozzle base 118, and is therefore a circulating fluidized bed.
  • the exhaust gases are separated from the solid components in the cyclone separator 76 and drawn off through the exhaust gas guide 119.
  • a feed point 84 for fluidized bed fuel is provided in the section 82 of the circulation channel, viewed in the direction of circulation (arrow 86) after the bend 80.
  • the feed point 84 is arranged on the top of the section 82.
  • an upwardly extending, hood-like extension 87 of the section 82 is arranged in its immediate vicinity, at the highest point of which the fuel gas line 144 leading to the combustion chamber 32 of the gas turbine system is connected to the removal point 145 in the form of an opening.
  • the fuel gas line 144 contains a filter device 142 and a compressor 135.
  • the combustion chamber is not shown.
  • the extension 87 has a height and a maximum width, which is approximately 2 to 3 times the diameter of the circulation channel 72.
  • the extension 87 tapers towards the top to a tip to which the fuel gas line 144 is connected.
  • the distance between the feed point 84 and the extension 87 is approximately 0.5 to 1.5 times the diameter of the circulation channel 72.
  • the non-degassed fluidized bed combustion fuel in particular small-sized coal
  • supplied at the feed point 84 is entrained and heated by the cob and ash particles of the circulating fluidized bed circulating in the direction of arrow 86 in the circulation channel.
  • This fuel is gasified or degassed, the resulting fuel gas collects in the hood-like extension 87 and is drawn off through the fuel gas line 144 and fed to the combustion chamber of the gas turbine system.
  • the degassed residues of the supplied fuel are then introduced together with the pobs and ash particles into the combustion chamber 112, where they burn together with the fuel supplied at the fuel supply point 120.
  • the circulation of the fluidized bed through the combustion chamber 112 and the circulation channel 72 is brought about by the mixture of combustion chamber exhaust gas and air containing oxygen supplied by means of the combustion air line 146, which enters the combustion chamber 112 from the room 125 through the nozzle floor 118. This mixture also causes combustion in the combustion chamber.
  • FIG. 3 shows the area of the sections 78, 82 and the bend 80 of the circulation channel according to FIG. 2 as an embodiment variant and as a detail in a larger representation. Individual parts of FIG. 2 also contained in FIG. 3 have reference numerals in FIG. 3, which are enlarged by an amount of 100 compared to FIG.
  • a stationary second fluidized bed 102 is inserted in the area of the arc 180 of the circulation channel 172, which works similarly to the fluidized bed 14 according to FIG. 1.
  • the second fluidized bed 102 is preferably in a vertical space 90 circular cross section, in the lower region of which a nozzle bottom 92 provided with a plurality of openings is arranged horizontally.
  • a space 94 is provided under the nozzle base 92, into which a pipeline 96 opens, and which is connected to the exhaust gas duct of the system, which has the reference number 19 in FIG. 1, with the interposition of a blower or a compressor.
  • the connection is preferably made after the intended exhaust gas cleaning system. This is not shown in Figure 3.
  • the vertically extending straight section 186 of the circulation channel 172 is introduced, preferably centrally, to such an extent that the mouth of the section 186 lies in the stationary second fluidized bed 102 and is at a distance from the nozzle bottom 92 which is approximately 1/2 to 1 / 4 of the vertical thickness of the fluidized bed 102.
  • This stationary second fluidized bed is located directly above the nozzle base 92 and has a defined surface 100.
  • the section 182 of the circulation duct which leads back to the combustion chamber of the steam generator with a gradient is connected to a vertical side wall of the chamber 90. That vertical region of the side wall, which is located between the connection point 106 of the section 182 and the nozzle base 92, forms an overflow weir 104.
  • the height of the overflow weir 104 determines the vertical thickness of the stationary second fluidized bed 102 or the thickness of this fluidized bed can be selected by a corresponding height of the overflow weir.
  • the upper end region of the space 90 forms a fuel gas collection space 108.
  • the upper end region of the space 90 tapers conically towards the section 186 centrally introduced into the space 90 and merges into a space 114 which surrounds the section 186 in an annular manner and which forms the actual fuel gas collection space 108 .
  • the fuel gas line 244 leading to the combustion chamber of the gas turbine system at the extraction point 245 is connected to this fuel gas collecting space in the form of at least one opening.
  • a filter device 242 together with compressor 235 is advantageously connected into the Brering gas line 244.
  • the feed point 116 for fuel to the space 90 through which fluidized bed fuel can be supplied to the second fluidized bed 102.
  • the circulation duct 172 is flowed through by circulating ash and coke components of the fluidized bed furnace. These enter the space 90 through the section 186 and, starting from the nozzle bottom 92, fill the space 90 up to the connection point 106, flow over the overflow weir 104 and are then inclined through the section 182 to the combustion chamber of the fluidized bed firing of the steam generator ( see FIG. 1).
  • the height of the vertically extending upper weir 104 determines the thickness of the layer which forms on the nozzle bottom 92 and which forms the fluidized bed 102.
  • the section 186 of the circulation channel dips into the fluidized bed 102 and opens there.
  • fluidized bed firing fuel intended for fuel gas generation is introduced into the second fluidized bed 102.
  • low-oxygen gas with an oxygen content of at most 5 vol%, preferably exhaust gas, which is taken from the exhaust gas duct 19 of the fluidized bed furnace of the steam generator, is fed through the pipeline 96, so that the fuel introduced cannot burn, but is only degassed . Since the second fluidized bed 102 is switched into the circulation channel 172 of the fluidized bed firing of the steam generator, the heat required for the degassing of the fuel is introduced into the second fluidized bed 102 by the circulating hot ash and coke particles.
  • the resulting fuel gas flows upward into the fuel gas plenum 108 and is drawn off there through the fuel gas line 244 and fed as fuel gas to the combustion chamber of the gas turbine system via the filter device 242 and the compressor 235.
  • the degassed fuel flows together with the ash and coke particles of the circulation channel 172 through the section 182 of the fluidized-bed firing used to generate steam.
  • the remaining fuel required for the operation of the system is then fed directly into the fluidized bed firing of the steamer producer introduced.

Landscapes

  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Engine Equipment That Uses Special Cycles (AREA)
  • Fluidized-Bed Combustion And Resonant Combustion (AREA)

Claims (6)

1. Procédé pour générer de l'énergie électrique en utilisant une installation de production d'énergie combinée à vapeur et à turbine à gaz présentant une seule installation de chauffage à lit fluidisé, de l'air comprimé étant chauffé dans une chambre de combustion (32) alimentée en gaz combustible, détendu dans une turbine à gaz (30) et amené ensuite à l'installation de chauffage à lit fluidisé en tant qu'air de combustion et de turbulence, et le gaz combustible étant produit par dégazage ou par gazéification du combustible de l'installation de chauffage à lit fluidisé, caractérisé par le fait que le gaz combustible est produit à l'intérieur de l'installation de chauffage à lit fluidisé utilisée pour la production de vapeur.
2. Installation de production d'énergie combinée à vapeur et à turbine à gaz pour la mise en oeuvre du procédé selon la revendication 1, comprenant une installation de chauffage à lit fluidisé (10; 110) et une chambre de combustion (32) pouvant être alimentée en gaz combustible qui est obtenu par dégazage ou par gazéification de combustible de l'installation de chauffage à lit fluidisé, caractérisée par le fait que, dans le cas d'une installation de chauffage à lit fluidisé (10) avec un lit fluidisé (14) stationnaire dans le foyer (12), la chambre de combustion est raccordée, pour l'alimentation en gaz combustible, à la zone de gazéification ou de dégazage formée dans la zone de l'emplacement d'amenée (20) du combustible dans le foyer (12) de l'installation d'énergie à vapeur, et que, dans le cas d'une installation de chauffage à lit fluidisé (110) avec un lit fluidisé en circulation, une partie du combustible de l'installation de chauffage à lit fluidisé peut être alimentée dans la portion (82; 182) du canal de circulation (72 ; 172) revenant au foyer (112), et que la chambre de combustion est raccordée, pour l'alimentation en gaz, à la zone de gazéification ou de dégazage formée dans la zone de l'emplacement d'amenée (84 ; 116).
3. Installation selon la revendication 2, comprenant une installation de chauffage à lit fluidisé (10) dont le lit fluidisé est stationnaire, caractérisée par le fait que dans la zone de gazéification ou de dégazage, la conduite (44) de gaz combustible de la chambre de combustion (32) est raccordée au foyer (12) par plusieurs ouvertures (45) qui se trouvent de préférence à peu près dans un même plan et sont réparties à peu près régulièrement sur la périphérie du foyer (12) (figure 1).
4. Installation selon la revendication 2, comprenant une installation de chauffage à lit fluidisé (110) avec un lit fluidisé en circulation, caractérisée par le fait que, vu dans le sens de circulation, le canal de circulation (72) présente en aval de l'emplacement d'alimentation (84) un collecteur de gaz combustible, sous forme d'un élargissement (87) en forme de hotte du canal de circulation (72), auquel est raccordée la chambre de combustion (32) en vue de l'aliméntation en combustible (figure 2).
5. Installation selon la revendication 2, comprenant une installation de chauffage à lit fluidisé avec un lit fluidisé en circulation, caractérisée par le fait que dans le canal de circulation (172) est intégré un espace (90) avec un deuxième lit fluidisé (102), stationnaire, dans lequel peut être alimentée, à l'emplacement d'amenée (116) de combustible, une partie du combustible solide nécessaire au fonctionnement de l'installation, et auquel peut être amené par une tuyauterie (96) un gaz à faible teneur en oxygène, de préférence le gaz brûlé de l'installation de chauffage à lit fluidisé, en tant qu'agent de turbulence et pour le dégazage au moins partiel du combustible (figure 3).
6. Installation selon la revendication 5, caractérisée par le fait que, au-dessus du lit fluidisé (102), est prévu un espace collecteur (114) de gaz combustible raccordé à la chambre de combustion (32), que, vu dans le sens de circulation (127), la portion (186) du canal de circulation entrant dans le deuxième lit fluidisé (102) débouche à l'intérieur du deuxième lif fluidisé, et que la portion (182) du canal de circulation quittant l'espace (90) est raccordée à au moins un déversoir de trop-plein (104) qui délimite latéralement le deuxième lit fluidisé (102) et dont la hauteur détermine l'épaisseur du deuxième lit fluidisé (102) dans le sens vertical (figure 3).
EP87105588A 1986-04-19 1987-04-15 Cycle combiné gaz et vapeur avec lit fluidisé Expired EP0243801B1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AT87105588T ATE48673T1 (de) 1986-04-19 1987-04-15 Kombinations-gas-dampfturbinenanlage mit wirbelschichtfeuerung.

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
DE19863613300 DE3613300A1 (de) 1986-04-19 1986-04-19 Verfahren zum erzeugen von elektrischer energie mit einer eine wirbelschichtfeuerung aufweisenden kombinierten gasturbinen-dampfkraftanlage sowie anlage zur durchfuehrung des verfahrens
DE3613300 1986-04-19

Publications (2)

Publication Number Publication Date
EP0243801A1 EP0243801A1 (fr) 1987-11-04
EP0243801B1 true EP0243801B1 (fr) 1989-12-13

Family

ID=6299089

Family Applications (1)

Application Number Title Priority Date Filing Date
EP87105588A Expired EP0243801B1 (fr) 1986-04-19 1987-04-15 Cycle combiné gaz et vapeur avec lit fluidisé

Country Status (5)

Country Link
US (2) US4845942A (fr)
EP (1) EP0243801B1 (fr)
JP (1) JPS62255535A (fr)
AT (1) ATE48673T1 (fr)
DE (2) DE3613300A1 (fr)

Families Citing this family (30)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4827723A (en) * 1988-02-18 1989-05-09 A. Ahlstrom Corporation Integrated gas turbine power generation system and process
DE3907217A1 (de) * 1989-03-07 1990-09-13 Steinmueller Gmbh L & C Verfahren zum betreiben eines kombinierten gasturbinen-/dampfturbinen-prozesses
US4911107A (en) * 1989-06-09 1990-03-27 The Babcock & Wilcox Company Standby cooling system for a fluidized bed boiler
US5190451A (en) * 1991-03-18 1993-03-02 Combustion Power Company, Inc. Emission control fluid bed reactor
US5236354A (en) * 1991-03-18 1993-08-17 Combustion Power Company, Inc. Power plant with efficient emission control for obtaining high turbine inlet temperature
US5255507A (en) * 1992-05-04 1993-10-26 Ahlstrom Pyropower Corporation Combined cycle power plant incorporating atmospheric circulating fluidized bed boiler and gasifier
US5239946A (en) * 1992-06-08 1993-08-31 Foster Wheeler Energy Corporation Fluidized bed reactor system and method having a heat exchanger
DE4236512C2 (de) * 1992-10-26 2001-05-10 Ver Energiewerke Ag Verfahren zum Betrieb eines Kombikraftwerkes, wobei Rauchgas eines Kessels mit einer unterstöchiometrisch in vergaserähnlichem Betrieb gefahrenen Wirbelschichtfeuerung gereinigt, mit der Zuführung von Reinluft nachverbrannt und einer Gasturbine zugeführt wird
DE4224958A1 (de) * 1992-07-24 1994-01-27 Ver Energiewerke Ag Verfahren und Anordnung zum Betrieb eines Kombikraftwerkes
DE4227146A1 (de) * 1992-08-18 1994-02-24 Saarbergwerke Ag Verfahren zur Erzeugung von Energie in einer kombinierten Gas-Dampfkraftanlage
CA2102637A1 (fr) * 1992-11-13 1994-05-14 David H. Dietz Reacteur a lit fluidise en mouvement associe a un systeme de generation cyclique de courant
US5285629A (en) * 1992-11-25 1994-02-15 Pyropower Corporation Circulating fluidized bed power plant with turbine fueled with sulfur containing fuel and using CFB to control emissions
DE4307167C2 (de) * 1993-03-06 2002-06-27 Llb Lurgi Lentjes Energietechn Verfahren zur Herstellung eines Brenngases zur Verfeuerung in einer Brennkammer
JP2733188B2 (ja) * 1993-06-18 1998-03-30 川崎重工業株式会社 加圧型ガス化炉による石炭直接燃焼ガスタービン複合発電システム
DE4409057C2 (de) * 1994-03-11 2001-05-17 Ver Energiewerke Ag Verfahren zum Betrieb einer druckaufgeladenen zirkulierenden mit Braunkohle betriebenen Wirbelschichtfeuerung für ein Kombikraftwerk
US5396849A (en) * 1994-03-30 1995-03-14 Electric Power Research Institute, Inc. Combustion method producing low levels of pollutants and apparatus for same
US5469698A (en) * 1994-08-25 1995-11-28 Foster Wheeler Usa Corporation Pressurized circulating fluidized bed reactor combined cycle power generation system
US5666801A (en) * 1995-09-01 1997-09-16 Rohrer; John W. Combined cycle power plant with integrated CFB devolatilizer and CFB boiler
US6560956B1 (en) * 1998-03-19 2003-05-13 Ormat Industries Ltd. Multi-fuel, combined cycle power plant
EP1240414B1 (fr) * 1999-12-21 2008-10-08 Siemens Aktiengesellschaft Procede d'exploitation d'une installation de turbine a vapeur et installation de turbine a vapeur fonctionnant selon ledit procede
US6430914B1 (en) * 2000-06-29 2002-08-13 Foster Wheeler Energy Corporation Combined cycle power generation plant and method of operating such a plant
US7267698B1 (en) 2002-09-23 2007-09-11 Pierce Jr Joseph Frank Method for producing hydrogen
US6886340B1 (en) * 2002-09-23 2005-05-03 Joseph Frank Pierce, Jr. Method for converting waste into electricity
US6843058B1 (en) * 2002-09-23 2005-01-18 Joseph Frank Pierce, Jr. Method for making gypsum and zinc sulfide
KR101590447B1 (ko) * 2006-11-17 2016-02-18 서머힐 바이오매스 시스템즈, 아이엔씨. 분말 연료, 이의 분산물, 및 이와 관련된 연소장치
US9039407B2 (en) 2006-11-17 2015-05-26 James K. McKnight Powdered fuel conversion systems and methods
US20080148739A1 (en) * 2006-12-22 2008-06-26 Paul Marius A Fluidized bed heavy fuel combustor
US20090223612A1 (en) * 2007-11-16 2009-09-10 Mcknight James K Powdered fuels and powdered fuel dispersions
FR2994249B1 (fr) * 2012-08-06 2018-09-07 Degremont Procede et installation de production d'electricite a partir de dechets fermentescibles, en particuler de boues de station d'epuration
CN108397250B (zh) * 2018-03-14 2019-02-26 浙江城建煤气热电设计院有限公司 一种低温余热发电装置

Family Cites Families (24)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB1165537A (en) * 1966-01-11 1969-10-01 Coal Industry Patents Ltd Improvements in Gas Turbine Systems
GB1200727A (en) * 1966-11-15 1970-07-29 Struthers Scientific Int Corp Gas turbine plant comprising a combustible gas producer
FR1585425A (fr) * 1968-07-15 1970-01-23
US3986348A (en) * 1973-04-25 1976-10-19 Switzer Jr George W Coal-fueled combined cycle power generating system
US3978657A (en) * 1974-02-06 1976-09-07 Combustion Turbine Power, Inc. Turbine system
GB2014662A (en) * 1978-02-16 1979-08-30 English Electric Co Ltd Gas Turbine Plant Providing Shaft Power and Heat
CH632560A5 (en) * 1978-10-06 1982-10-15 Bbc Brown Boveri & Cie Gas turbine plant
US4253300A (en) * 1979-08-03 1981-03-03 General Electric Company Supplementary fired combined cycle power plants
DE3002615A1 (de) * 1979-12-05 1981-06-11 BBC AG Brown, Boveri & Cie., Baden, Aargau Verfahren und einrichtung fuer den teillastbetrieb von kombinierten kraftanlagen
GB2076062B (en) * 1980-05-16 1984-04-26 English Electric Co Ltd Turbine power plant
IE51626B1 (en) * 1980-08-18 1987-01-21 Fluidised Combustion Contract A fluidised bed furnace and power generating plant including such a furnace
US4387560A (en) * 1980-12-29 1983-06-14 United Technologies Corporation Utilization of coal in a combined cycle powerplant
US4369624A (en) * 1981-01-02 1983-01-25 Westinghouse Electric Corp. High temperature gas turbine systems
ZA821381B (en) * 1981-04-01 1983-03-30 Westinghouse Electric Corp Efficient combined cycle system employing a high temperature combustion turbine and a fluidized coal bed with economic exclusion of sulfur from system waste gases
DE3124832A1 (de) * 1981-06-24 1983-01-13 Kraftwerk Union AG, 4330 Mülheim Heissgassystem
US4419965A (en) * 1981-11-16 1983-12-13 Foster Wheeler Energy Corporation Fluidized reinjection of carryover in a fluidized bed combustor
US4548138A (en) * 1981-12-17 1985-10-22 York-Shipley, Inc. Fast fluidized bed reactor and method of operating the reactor
DE3204672A1 (de) * 1982-02-11 1983-08-18 Deutsche Babcock Anlagen Ag, 4200 Oberhausen Kombinierter gas-/dampfturbinenprozess
US4476674A (en) * 1982-06-10 1984-10-16 Westinghouse Electric Corp. Power generating plant employing a reheat pressurized fluidized bed combustor system
DE3338107A1 (de) * 1982-11-30 1984-05-30 BBC Aktiengesellschaft Brown, Boveri & Cie., Baden, Aargau Kohlegefeuertes kraftwerk mit wirbelschichtfeuerung
US4453495A (en) * 1983-03-23 1984-06-12 Electrodyne Research Corporation Integrated control for a steam generator circulating fluidized bed firing system
DE3320227A1 (de) * 1983-06-03 1984-12-06 Kraftwerk Union AG, 4330 Mülheim Kraftwerk mit einer integrierten kohlevergasungsanlage
FR2563118B1 (fr) * 1984-04-20 1987-04-30 Creusot Loire Procede et installation de traitement de matiere en lit fluidise circulant
DE3428041A1 (de) * 1984-07-30 1986-01-30 BBC Aktiengesellschaft Brown, Boveri & Cie., Baden, Aargau Luftspeichergasturbinenkraftwerk mit wirbelbettfeuerung

Also Published As

Publication number Publication date
EP0243801A1 (fr) 1987-11-04
ATE48673T1 (de) 1989-12-15
DE3613300A1 (de) 1987-10-22
DE3761156D1 (de) 1990-01-18
JPS62255535A (ja) 1987-11-07
US4845942A (en) 1989-07-11
US4901521A (en) 1990-02-20

Similar Documents

Publication Publication Date Title
EP0243801A1 (fr) Cycle combiné gaz et vapeur avec lit fluidisé
DE60120957T2 (de) Verfahren und system zur zersetzung wasserhaltiger brennstoffe oder anderer kohlenstoffhaltiger materialien
DE2743830C2 (de) Verfahren zum Betreiben einer kombinierten Gas-Dampfkraftanlage und Gas-Dampfkraftanlage zur Durchführung des Verfahrens
DE69205161T2 (de) Pulsierende atmosphärische wirbelschichtverbrennungsanlage und verfahren.
DE69535026T2 (de) Vorrichtung zur Wirbelbettvergasung und Schmelzverbrennung
DE69735410T2 (de) Fluidbett-Vergasungs- und Verbrennungsofen und Verfahren
EP0413199B1 (fr) Procédé d'abaissement de la teneur en dioxyde de carbone des gaz résiduaires d'une centrale électrique à turbines à gaz ou à vapeur et centrale électrique l'utilisant
DE2539546B2 (de) Verfahren zur Verbrennung kohlenstoffhaltiger Materialien
DD270561A5 (de) Gasturbinenkraftanlage entzuendbar durch wasseranlagernden brennstoff und verfahren zur ausnutzung des heizwertes von besagtem brennstoff
DE69415550T2 (de) Zirkulierender druckwirbelkessel für überkritischen dampf
EP0086261A1 (fr) Combination d'un cycle d'une turbine à gaz et d'une turbine à vapeur
DE3642619A1 (de) Kombiniertes gas/dampfturbinenkraftwerk mit wirbelschichtkohlevergasung
EP0272410A2 (fr) Générateur de vapeur avec combustion en lit fluidisé
DD295696A5 (de) Kombinierter Gas/Dampfturbinen-Prozeß
DE3503603A1 (de) Feuerungsanlage
DE3617364A1 (de) Kombiniertes gas- und dampfturbinenkraftwerk mit aufgeladener wirbelschichtfeuerung und kohlevergasung
DE3324411C2 (fr)
EP0069243B1 (fr) Système de gaz chaud
DE3506102A1 (de) Kohlebefeuerte energieanlage
EP0278357B1 (fr) Dispositif pour la production des gaz de combustion pour actionner une turbine à gaz
DE3817713A1 (de) Kombiniertes gas- und dampfturbinenkraftwerk mit aufgeladener wirbelschichtfeuerung
DE3608248C1 (en) Method of generating hot gas and hot-gas generator for implementing the method
EP0924457B1 (fr) Installation pour la combustion de combustible fossile et biomasse ou déchets
DE19622299C2 (de) Verfahren zum Betrieb einer druckaufgeladenen zirkulierenden Wirbelschichtfeuerung zur Erzeugung eines arbeitsfähigen Gases für die Gasturbine eines Kombikraftwerkes
EP0394281A1 (fr) Chaufferie a lit fluidise exploitable sous presion.

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

AK Designated contracting states

Kind code of ref document: A1

Designated state(s): AT BE DE FR GB IT NL SE

17P Request for examination filed

Effective date: 19871230

17Q First examination report despatched

Effective date: 19881202

RAP1 Party data changed (applicant data changed or rights of an application transferred)

Owner name: ASEA BROWN BOVERI AKTIENGESELLSCHAFT

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): AT BE DE FR GB IT NL SE

REF Corresponds to:

Ref document number: 48673

Country of ref document: AT

Date of ref document: 19891215

Kind code of ref document: T

ITF It: translation for a ep patent filed
ET Fr: translation filed
REF Corresponds to:

Ref document number: 3761156

Country of ref document: DE

Date of ref document: 19900118

GBT Gb: translation of ep patent filed (gb section 77(6)(a)/1977)
PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

26N No opposition filed
ITTA It: last paid annual fee
PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: FR

Payment date: 19940210

Year of fee payment: 8

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: GB

Payment date: 19940214

Year of fee payment: 8

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: SE

Payment date: 19940215

Year of fee payment: 8

Ref country code: AT

Payment date: 19940215

Year of fee payment: 8

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: BE

Payment date: 19940302

Year of fee payment: 8

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: DE

Payment date: 19940408

Year of fee payment: 8

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: NL

Payment date: 19940430

Year of fee payment: 8

EAL Se: european patent in force in sweden

Ref document number: 87105588.5

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: GB

Effective date: 19950415

Ref country code: AT

Effective date: 19950415

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: SE

Effective date: 19950416

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: BE

Effective date: 19950430

BERE Be: lapsed

Owner name: ASEA BROWN BOVERI A.G.

Effective date: 19950430

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: NL

Effective date: 19951101

GBPC Gb: european patent ceased through non-payment of renewal fee

Effective date: 19950415

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: FR

Effective date: 19951229

NLV4 Nl: lapsed or anulled due to non-payment of the annual fee

Effective date: 19951101

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: DE

Effective date: 19960103

EUG Se: european patent has lapsed

Ref document number: 87105588.5

REG Reference to a national code

Ref country code: FR

Ref legal event code: ST

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IT

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES;WARNING: LAPSES OF ITALIAN PATENTS WITH EFFECTIVE DATE BEFORE 2007 MAY HAVE OCCURRED AT ANY TIME BEFORE 2007. THE CORRECT EFFECTIVE DATE MAY BE DIFFERENT FROM THE ONE RECORDED.

Effective date: 20050415