Abstract:
A method for producing electric energy from solid and liquid fuels is provided. The fuels are first subjected to a gasification process at high pressure, and the scrubbed gasification gas is fed to a gas and steam turbine process. The combustion of the scrubbed gasification gas in the gas turbine chamber does not occur with air, but with a mixture made of the three components oxygen, carbon dioxide and water vapor. As a result, the waste gas of the gas turbine is made only of carbon dioxide and water vapor. After the condensation thereof, technically pure carbon dioxide remains, which can be dissipated by storage in the deep substrate of the atmosphere.

Description:
CROSS REFERENCE TO RELATED APPLICATIONS 
     This application is the US National Stage of International Application No. PCT/EP2008/055136, filed Apr. 28, 2008 and claims the benefit thereof. The International Application claims the benefits of German application No. 10 2007 022 168.3 DE filed May 11, 2007, both of the applications are incorporated by reference herein in their entirety. 
     FIELD OF INVENTION 
     The invention relates to a method and an arrangement for producing motor energy from solid or liquid fuels with removal of pure carbon dioxide. 
     The invention relates to a method and an arrangement for producing motor energy, particularly also generated electrical power, from solid and liquid fuels, i.e. energy carriers. Solid and liquid energy carriers are to be understood as meaning coals of different ranks and cokes of different origin, biomass mechanically and thermally conditioned for power generation, and residual and waste materials, but also water-coal or oil-coal/coke suspensions otherwise known as slurries. 
     BACKGROUND OF INVENTION 
     In the last decade, IGCC (Integrated Gasification Combined Cycle) technology has come into use for electrical power generation. It is characterized in that the fuel is not combusted directly, but first undergoes a gasification process using oxygen or air to produce a combustion gas rich in hydrogen and carbon monoxide. Said combustion gas can then be used in a combined cycle gas and steam turbine process. A number of such plants have been built worldwide, with in particular hard coals and petroleum cokes being used a fuels. The relevant background art is extensively described in the international technical literature. 
     Reference shall be made here to the following publications:
     Trevino, M: Integrated Gasification Combined Cycle Technology; IGCC, ELCOGAS, Club Español de la Energia, March 2003   Gomez, F. S. et al.: Puertollano IGCC Plant: Operating Experiences and Further Technology Development for Commercial Generation of Clean Energy from Coal Russia Power Conference 2004, 10-11, Mar. 2004, Moscow   Delaney, R.: Hatfield—The first United Kingdom IGCC Plant IChemE Conference “Gasification—A versatile solution” 10-12 May 2004 Brighton, UK   

     The advantage of IGCC technology is that, by combining a gas turbine, with its high inlet temperatures, with a downstream steam turbine which uses the gas turbine&#39;s waste heat steam, increased efficiencies can be achieved. In addition, there are developments to modify IGCC technology such that a concentrated CO 2  stream is obtained which creates the necessary conditions for separating off the CO 2  and removing it from the atmosphere e.g. by means of underground storage. The first demonstration power plants are in preparation. Descriptions of the technology can be found in:
     Denkhahn, W. et al.: Wege zum CO 2 —emissionsfreien fossilbefeuerten Kraftwerk (Towards a CO 2  emissions-free fossil-fired power plant) Energiewirtschaftliche Tagesfragen ½. 2004, pages 86-89   Higginbotham, P “Process Integration in Gasification et al.: System for Multiproduct Applications” in 6 th  European Gasification Conference, 10-12 May 2004, Brighton, UK.   

     IGCC technology with CO 2  capture is characterized by the following process stages: 
     gasification of the fuel, e.g. in an entrained bed gasifier at temperatures of between 1250 and 1700° C. 
     cooling of the gasification gas and saturation with water vapor at 190-220° C. 
     raw gas conversion by carrying out the reaction
 
CO+H 2 O           CO 2 +H 2  

     removal of carbon dioxide and sulfur compounds from the converted raw gas using prior art methods 
     conversion of the resulting technical hydrogen into electricity in a combined cycle (gas and steam turbine) process 
     compressing the abstracted carbon dioxide and taking it away for storage underground 
     Said prior art is characterized by the following disadvantages:
         The efficiency of IGCC technology with CO 2  capture is up to 10% less than that without CO 2  capture. In addition to the energy required for CO 2  compression, which is an inherent feature of all the technology models, this disadvantage results from the stages of CO conversion and CO 2  separation from the converted raw gas.       

     CO conversion is strongly exothermic, which means that some of the chemical energy contained in the raw gas is converted into heat and can only be used for steam generation.
         CO 2  capture cannot be performed selectively but only collectively with the sulfur compounds. These components therefore have to be separated out in a secondary stage. The energy required for regenerating the solvent used for absorption is very high, resulting in considerable steam consumption.       

     SUMMARY OF INVENTION 
     The object of the invention is to specify an improved technology for producing motor energy from fossil fuels with removal of technical grade carbon dioxide. 
     The object is achieved by a method having the features set forth in the claims and an arrangement having the features set forth in the claims. 
     According to the invention, the IGCC technology selected comprises the following stages: 
     gasification of the fuel e.g. in an entrained bed gasifier or a fluidized bed gasifier 
     cooling of the combustion gas to temperatures &lt;200° C. with utilization of the heat content 
     performing catalytic raw gas hydrolysis at temperatures &lt;200° C. to eliminate HCN and COS according to the reactions
 
HCN+H 2 O           NH 3 +CO
 
COS+H 2 O         H 2 S+CO 2  

     carrying out selective scrubbing to remove the H 2 S according to prior art methods, e.g. by means of an oxidation method to convert the H 2 S into elemental sulfur or by means of a selective H 2 S absorption method in conjunction with a Claus unit 
     feeding the desulfurized gasification gas to the combustion chamber of a gas turbine and combusting it with a mixture of oxygen, CO 2  and water vapor with a composition of preferably 
     O 2 =21 vol % 
     CO 2 =29 vol % 
     H 2 O=50 vol % 
     as synthetic combustion air 
     recovering heat from the gas turbine&#39;s exhaust gas by extracting high-pressure steam and using the resulting steam in a steam turbine 
     cooling the gas turbine&#39;s exhaust gas consisting of carbon dioxide and water vapor and condensing out the water vapor 
     compressing the remaining carbon dioxide and feeding back part of the CO 2  to produce the synthetic combustion air 
     delivering the rest of the CO 2  for storage or material use or venting it to the atmosphere 
     Some of the electrical power generated in the gas and steam turbine is used for internal consumption, the rest is delivered as net energy. 
     The fuel can be supplied pneumatically to the gasification reactor, either dry as a conveying gas—pulverized fuel suspension or also wet as a water or oil—pulverized fuel suspension. 
     With the invention, the disadvantageous stages of CO conversion and CO 2  absorption are superfluous, resulting in a corresponding reduction in equipment and operating costs. The exhaust gas only consists of carbon dioxide and water vapor, thereby enabling technical grade carbon dioxide to be separated out and removed in a simple manner, which basically constitutes a CO 2 -free power plant. 
     Advantageous further developments of the subject matter of the application are detailed in the sub-claims. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       The invention will now be explained to the extent necessary for its understanding based on exemplary embodiments and with reference to the 5 accompanying drawings in which: 
         FIG. 1 : shows an IGCC technology with reheating of the desulfurized gasification gas 
         FIG. 2 : shows an IGCC technology with heating and water vapor saturation of the CO 2  supplied to the gas turbine 
         FIG. 3 : shows an IGCC technology with a waste heat boiler downstream of the gasifier 
         FIG. 4 : shows an IGCC technology with a low temperature gasifier with deduster and waste heat boiler 
         FIG. 5 : shows an IGCC technology with partial quenching and downstream waste heat boiler each solution featuring the removal of technical grade carbon dioxide. 
     
    
    
     In the figures, the same designations are used to identify identical elements. 
     DETAILED DESCRIPTION OF INVENTION 
     Example 1 
     The example will be described with reference to  FIG. 1 . 
     An IGCC plant is designed for a gross energy consumption of 1200 MW. For this purpose 170 Mg/h of hard coal with a calorific value of 25218 kJ/kg is ground to a fine powder and fed pneumatically according to the dense-phase conveying principle to the gasification reactor  1  as pulverized fuel  13  and reacted with oxygen  14  from the oxygen unit  11  at 40 bar. Fed-back carbon dioxide is used as the conveying gas for pneumatically conveying the pulverized fuel. The pulverized fuel  13  is reacted at an equilibrium temperature of 1,450° C. in an entrained bed gasifier  1  to produce raw synthesis gas. At this temperature, the ash content of the pulverized fuel  13  is liquefied to slag and flows together with the hot raw gas into the quencher  2  where cooling to 200° C. by injection of excess water takes place, the raw gas being saturated with water vapor. The liquid slag is likewise cooled and, in so doing, is granulated. It is discharged from the quencher  2  as solid slag  20  via lock hoppers. The raw gas possesses the following analysis (dry): 
     
       
         
               
               
               
             
           
               
                   
                   
               
             
             
               
                   
                 H 2   
                 22.16 vol % 
               
               
                   
                 CO 
                 72.79 vol % 
               
               
                   
                 CO 2   
                  4.19 vol % 
               
               
                   
                 CH 4   
                  0.01 vol % 
               
               
                   
                 N 2   
                  0.56 vol % 
               
               
                   
                 NH 3   
                 0.001 vol % 
               
               
                   
                 HCN 
                 0.001 vol % 
               
               
                   
                 H 2 S 
                 0.233 vol % 
               
               
                   
                 COS 
                 0.032 vol % 
               
               
                   
                 HCl 
                 0.020 vol % 
               
               
                   
                   
               
             
          
         
       
     
     The dry raw gas amounts to 282,500 m 3  (STP)/h at a calorific value of 11,650 kJ/m 3  (STP). For gasification, 83.700 m 3  (STP)/h of oxygen are required. After further water scrubbing, the water-vapor-saturated raw gas  15  is fed to a raw gas hydrolyzer  29  at approximately 200° C. in order to catalytically convert carbonyl sulfide and hydrogen cyanide into hydrogen sulfide and ammonia by means of the reactions:
 
COS+H 2 O           CO 2 +H 2 S
 
HCN+H 2 O         CO+NH 3  

     which are removed from the raw gas  15  in the downstream cleaning processes. After flowing through the heat exchanger  3  and the cooler  4  from which fine-dust-laden waste water  19  is withdrawn, the raw gas undergoes selective desulfurization  5  at temperatures of between 40 and 60° C. Prior art direct oxidation methods such as Sulferox and Locat can be used to oxidize the hydrogen sulfide directly to elemental sulfur. However, desulfurization can also be performed using selective absorption methods combined with a Claus unit. The cleaned gas is thus available for the gas turbine. To use low-temperature heat, the cleaned gas can first be heated against the uncleaned raw gas to e.g. 150 to 180° C. in the heat exchanger  3 . To achieve a maximally pure CO 2  stream, the cleaned gas is not burned with air in the combustion chamber of the gas turbine  6 , but with a mixture of oxygen, carbon dioxide and water vapor, the mixture of said components being designed to have similar properties to air during combustion of the cleaned gas  15 , in order to avoid modifications to the gas turbine&#39;s combustion chamber. 
     This is achieved using a composition of: 
     
       
         
               
               
               
             
           
               
                   
                   
               
             
             
               
                   
                 CO 2   
                 21 vol % 
               
               
                   
                 CO 2   
                 29 vol % 
               
               
                   
                 H 2 O 
                 50 vol % 
               
               
                   
                   
               
             
          
         
       
     
     as synthetic combustion air. However, certain other concentration ranges are also possible, said components possibly varying between 
     
       
         
               
               
               
             
           
               
                   
                   
               
             
             
               
                   
                 CO 2   
                 18-30 vol % 
               
               
                   
                 CO 2   
                 10-50 vol % 
               
               
                   
                 H 2 O 
                 30-70 vol % 
               
               
                   
                   
               
             
          
         
       
     
     Taking the first mentioned values as the basis, we obtain the following consumptions for combustion of the cleaned gas  15  based on said gas analysis and a gas flow rate of 282,500 m 3  (STP)/h for ideal combustion for an oxygen-fuel ratio of 1: 
     
       
         
           
             
               
                 
                   
                     
                       O 
                       2 
                     
                     ⁢ 
                     
                       : 
                     
                     ⁢ 
                     
                         
                     
                     ⁢ 
                     134 
                     ⁢ 
                     
                       , 
                     
                     ⁢ 
                     000 
                     ⁢ 
                     
                         
                     
                     ⁢ 
                     
                       
                         m 
                         3 
                       
                       ⁡ 
                       
                         ( 
                         
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                           ⁢ 
                           
                               
                           
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                         ) 
                       
                     
                     ⁢ 
                     
                       / 
                     
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                     h 
                   
                 
               
               
                 
                   
                     
                       CO 
                       2 
                     
                     ⁢ 
                     
                       : 
                     
                     ⁢ 
                     
                         
                     
                     ⁢ 
                     185 
                     ⁢ 
                     
                       , 
                     
                     ⁢ 
                     000 
                     ⁢ 
                     
                         
                     
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                     ⁢ 
                     
                       / 
                     
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                       H 
                       2 
                     
                     ⁢ 
                     O 
                     ⁢ 
                     
                       : 
                     
                     ⁢ 
                     
                         
                     
                     ⁢ 
                     319 
                     ⁢ 
                     
                       , 
                     
                     ⁢ 
                     000 
                     ⁢ 
                     
                         
                     
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                         m 
                         3 
                       
                       ⁡ 
                       
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                           P 
                         
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                     ⁢ 
                     
                       / 
                     
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               Σ 
               ⁢ 
               
                   
               
               ⁢ 
               638 
               ⁢ 
               
                 , 
               
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               ⁢ 
               
                   
               
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     Combustion of the cleaned gas  15  at an oxygen ratio of 1 results in an exhaust gas flow rate of 738,000 m 3  (STP)/h. The combustion temperature is 2,032° C. However, the exit temperature from the gas turbine&#39;s combustion chamber should not exceed 1,250° C. To achieve this, the calorific value of the gas  15  must be reduced by introducing water vapor and carbon dioxide, 
     405,000 m 3  (STP)/h water vapor and 
     233,000 m 3  (STP)/h carbon dioxide 
     being added here. 
     A 1,250° C. exhaust gas therefore leaves the combustion chamber of the gas turbine  6  at flow rate of 
     
       
         
           
             
               
                 
                   
                     
                       water 
                       ⁢ 
                       
                           
                       
                       ⁢ 
                       vapor 
                       ⁢ 
                       
                           
                       
                       ⁢ 
                       786 
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                       h 
                     
                     ⁢ 
                     
                       = 
                       ⋀ 
                     
                     ⁢ 
                     
                       55.7 
                       ⁢ 
                       
                           
                       
                       ⁢ 
                       vol 
                       ⁢ 
                       
                           
                       
                       ⁢ 
                       % 
                     
                   
                 
               
               
                 
                   
                     
                       carbon 
                       ⁢ 
                       
                           
                       
                       ⁢ 
                       dioxide 
                       ⁢ 
                       
                           
                       
                       ⁢ 
                       624 
                       ⁢ 
                       
                         , 
                       
                       ⁢ 
                       000 
                       ⁢ 
                       
                           
                       
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                         ⁡ 
                         
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                       ⋀ 
                     
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                       44.2 
                       ⁢ 
                       
                           
                       
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                       vol 
                       ⁢ 
                       
                           
                       
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                       % 
                     
                   
                 
               
             
             
               Σ 
               ⁢ 
               
                   
               
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               1 
               ⁢ 
               
                 , 
               
               ⁢ 
               410 
               ⁢ 
               
                 , 
               
               ⁢ 
               000 
               ⁢ 
               
                   
               
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                   3 
                 
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     The nitrogen content is &lt;0.1 vol %. 
     The gas turbine exhaust gas  16  with the above analysis leaves the gas turbine  6  at approximately 600° C. and is used in the steam generator  7  whose waste heat steam  25  drives the steam turbine  8  which produces the electricity  23 . This together with the electrical energy  22  from the gas turbine block constitutes the gross electrical output. The steam condensate  26  is returned to the steam generator  7 . Back-pressure steam from the steam turbine  8  can be fed both to the gas  15  and to produce the synthetic combustion air. After leaving the steam generator  7 , the combustion exhaust gas  16  is fed to the cooler  9 , with most of the water vapor being condensed out. 
     After condensate removal  17 , all the carbon introduced with the pulverized fuel  13  is available in technical form as carbon dioxide together with the portion  30  circulated via the CO 2  compressor  10 . The portion resulting from the pulverized fuel can be removed from the process and stored or used for other purposes. At certain times during repairs or if CO 2  removal is not possible, the cleaned gas can be combusted with air in the gas turbine&#39;s combustion chamber. 
     Example 2 
     Example 2 is largely identical to Example 1. The difference is the use of the sensible heat of the raw gas  15 . Whereas in Example 1 the desulfurized gas, after selective desulfurization  5 , is heated against the approximately 200° C. undesulfurized raw gas in the heat exchanger  3 , in Example 2 a heat exchanger/saturator  33  is provided in which the compressed carbon dioxide  30  fed to the gas turbine  6  via the compressor  10  is heated up and completely or partially saturated with water vapor by the introduction and evaporation of condensate. In this way, the water vapor to be supplied to the “synthetic air” is reduced by the amount produced in the heat exchanger/saturator  33 . 
     Example 3 
     In Example 3, as shown in  FIG. 3 , the pulverized fuel is not supplied in a pneumatically dry manner to the gasifier  1  but as a pulverized fuel-water suspension, a so-called slurry consisting of 50 wt % pulverized fuel (calculated as dry) and 50 wt % water. It is likewise reacted with oxygen in the gasifier  1  at temperatures of 1,450° C. and an operating pressure of 50 bar (5 MPa). The slurry can be pre-heated to temperatures of approx. 230° C. The raw gas exiting the gasification reactor  1  has the following composition: 
     
       
         
               
               
               
               
             
           
               
                   
                   
               
             
             
               
                   
                 H 2   
                 16.62 
                 vol % 
               
               
                   
                 CO 
                 25.07 
                 vol % 
               
               
                   
                 CO 2   
                 16.53 
                 vol % 
               
               
                   
                 CH 4   
                 0 
               
               
                   
                 N 2   
                 0.42 
                 vol % 
               
               
                   
                 NH 3   
                 0.001 
                 vol % 
               
               
                   
                 HCN 
                 0 
               
               
                   
                 H 2 S 
                 0.26 
                 vol % 
               
               
                   
                 COS 
                 0.016 
                 vol % 
               
               
                   
                 H 2 O 
                 41.05 
                 vol % 
               
               
                   
                   
               
             
          
         
       
     
     For an input of 170 Mg/h pulverized fuel, corresponding to 340 Mg/h slurry, 491,000 m 3  (STP)/h raw gas is produced wet. To use the sensible heat of this large amount of gas, a waste heat boiler  27  for generating medium-pressure steam is provided downstream of the gasifier  1 . The slag  20  is flushed out of the waste heat boiler  27 . The raw gas leaves the waste heat boiler  27  water-vapor-saturated at approx. 200° C. and is fed to the COS and HCN hydrolyzer  29 . To eliminate entrained dust, the raw gas can undergo water scrubbing (not shown) downstream of the waste heat boiler  27 . The hydrolysis stage  29  is followed by further waste heat use 28 before the raw gas is fed to the selective desulfurizer  5 . The process continues as described in the above examples. 
     Example 4 
     In contrast to the high-temperature gasification in Examples 1 to 3, it is also possible to use low-temperature gasification such as a fluidized bed method, as shown in  FIG. 4 , in which the gasification temperatures are below 1000° C. For the same amount of coal of 170 Mg/h, a raw gas flow rate of 311,000 m 3  (STP)/h with the following composition is achieved: 
     
       
         
               
               
               
               
             
           
               
                   
                   
               
             
             
               
                   
                 H 2   
                 23.46 
                 vol % 
               
               
                   
                 CO 
                 66.47 
                 vol % 
               
               
                   
                 CO 2   
                 4.00 
                 vol % 
               
               
                   
                 CH 4   
                 2.45 
               
               
                   
                 N 2   
                 0.51 
                 vol % 
               
               
                   
                 NH 3   
                 0.004 
                 vol % 
               
               
                   
                 HCN 
                 0.003 
               
               
                   
                 H 2 S 
                 0.226 
                 vol % 
               
               
                   
                 COS 
                 0.027 
                 vol % 
               
               
                   
                 H 2 O 
                 2.83 
                 vol % 
               
               
                   
                   
               
             
          
         
       
     
     The ash  30 , which is partially agglomerated to slag, is discharged from the gasifier. After dry, mechanical dedusting  24  with dust discharge  31 , the raw gas passes through a waste heat boiler  34  and cooler  4  before being fed to the hydrolysis stage  29  and then to the selective desulfurizer  5 . The technology is then the same as in the above examples. To limit the gasification temperature, carbon dioxide or water vapor, particularly back-pressure steam  21 , is admixed with the oxygen  14 . 
     Example 5 
       FIG. 5  shows by way of example a technological variant in which the gasifier  1  is initially followed by partial quenching  35 . The raw gas leaving the gasification reactor  1  at a temperature of 1,450° C. is cooled down to temperatures of between 800 and 900° C. in the partial quencher  35  by injecting a limited amount of water, the raw gas not being saturated with water vapor. An advantage of this exemplary solution is that, at said temperatures, the liquid slag leaving the gasification reactor  1  together with the 1,450° C. raw gas is cooled down and solidified to the extent that it no longer adheres to the cooling surfaces of the downstream waste heat boiler  34 . In the bottom of the partial quencher  35  is a water bath which receives the now solid slag  30 . It is flushed out at regular intervals. After the waste heat boiler  34 , the raw gas  15  is fed to the known hydrolyzer  29  either directly or after further cooling  4  to approx. 200° C. and then to the selective desulfurizer  5 . The technology is otherwise the same as in the foregoing examples. 
     The invention comprises a method for generating electrical energy from solid and liquid energy carriers such as coals of different ranks and cokes of different origins, for gasifying mechanically and thermally conditioned biomasses, residual and waste materials, but also water- or oil-coal/coke suspensions by combining the gasification of said energy carriers at temperatures of between 800 and 1700° C. and pressures of up to 80 bar using nitrogen-free gasification media such as oxygen to which carbon dioxide and/or water vapor is added to produce a combustion gas with combined cycle technology, wherein the combustion gas is burnt in the combustion chambers of a gas turbine, combustion of the combustion gas being carried out using a mixture of oxygen, carbon dioxide and/or water vapor. 
     In particular embodiment of the invention, the mixture of oxygen, carbon dioxide and water vapor used for combustion of the combustion gas in the gas turbine&#39;s combustion chamber has the following composition 
                                                 O 2     18-30 vol %           CO 2     10-50 vol %           H 2 O   30-70 vol %,                        
preferably
 
     
       
         
               
               
               
             
           
               
                   
                   
               
             
             
               
                   
                 O 2   
                 21 vol % 
               
               
                   
                 CO2 
                 29 vol % 
               
               
                   
                 H 2 O 
                 50 vol %. 
               
               
                   
                   
               
             
          
         
       
     
     In further embodiment of the invention, gasification is followed by quenching of the hot gasification gas to temperatures of between 160 and 220° C. by injection of water. 
     In further embodiment of the invention, quenching of the gasification gas to temperatures of between 160 and 220° C. is followed by COS and HCN hydrolysis, the gasification gas possibly undergoing dry or wet dedusting between quenching and hydrolysis. 
     In further embodiment of the invention, COS and HCN hydrolysis is followed by selective desulfurization. 
     In further embodiment of the invention, selective desulfurization is performed by a physically or chemically acting absorbing agent which has a high solubility for hydrogen sulfide and low solubility for carbon dioxide. 
     In further embodiment of the invention, desulfurization is performed in a first stage in a solvent constituting a reduction-oxidation system in which components of the solvent are reduced and the sulfur ions S 2 — of the dissolved hydrogen sulfide are oxidized to elemental sulfur S and the reduced components of the solvent are oxidized again in a further stage by oxygen or air. 
     In further embodiment of the invention, the hydrogen sulfide absorbed by the selective solvent is stripped out and then converted into elemental sulfur by partial combustion. 
     In further embodiment of the invention, the hydrogen sulfide is separated from the gasification gas by an adsorption process. 
     In further embodiment of the invention, the desulfurized gasification gas as cleaned gas is heated to 180° C. by the raw gas in a heat exchanger. 
     In further embodiment of the invention, the desulfurized raw gas is saturated with water vapor by evaporation of water during said heating. 
     In further embodiment of the invention, the cleaned gas is fed to the combustion chamber of a gas turbine. 
     In further embodiment of the invention, the cleaned gas is combusted in the gas turbine&#39;s combustion chamber with a mixture of oxygen, carbon dioxide and water vapor. 
     In further embodiment of the invention, the combustion exhaust gas of the gas turbine is fed to a steam generator. 
     In further embodiment of the invention, after the steam generator the combustion exhaust gas is cooled and the water vapor content is condensed and separated. 
     In further embodiment of the invention, the technical grade carbon dioxide remaining after water separation is divided up. 
     In further embodiment of the invention, part of the carbon dioxide is compressed and fed to the gas turbine&#39;s combustion chamber and the other part is removed from the process for recycling or taking to final storage. 
     In further embodiment of the invention, the part of the carbon dioxide to be fed to the gas turbine is heated against the raw gas in a heat exchanger to temperatures of up to 180° C. 
     In further embodiment of the invention, the heated carbon dioxide is simultaneously saturated with water vapor. 
     In further embodiment of the invention, the gasifier is followed by a waste heat boiler for producing high-pressure steam. 
     In further embodiment of the invention, the raw gas is fed to a COS and HCN hydrolyzer downstream of the waste heat boiler. 
     In further embodiment of the invention, gasification is followed by dry dedusting of the hot gasification gas and a waste heat boiler for high-pressure steam generation. 
     In further embodiment of the invention, gasification is followed by partial quenching of the raw gas to temperatures of between 700 and 1000° C. before the partially quenched raw gas is fed to a waste heat boiler. 
     In further embodiment of the invention, if CO 2  capture is not provided, the cleaned gas is combusted with air in the gas turbine&#39;s combustion chamber.