CA2118178A1 - Method and appliance for generating gases for operating a gas turbine - Google Patents
Method and appliance for generating gases for operating a gas turbineInfo
- Publication number
- CA2118178A1 CA2118178A1 CA002118178A CA2118178A CA2118178A1 CA 2118178 A1 CA2118178 A1 CA 2118178A1 CA 002118178 A CA002118178 A CA 002118178A CA 2118178 A CA2118178 A CA 2118178A CA 2118178 A1 CA2118178 A1 CA 2118178A1
- Authority
- CA
- Canada
- Prior art keywords
- gas
- combustion
- appliance
- pressure vessel
- temperature
- 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.)
- Abandoned
Links
- 239000007789 gas Substances 0.000 title claims abstract description 92
- 238000000034 method Methods 0.000 title claims abstract description 34
- 238000002485 combustion reaction Methods 0.000 claims abstract description 25
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 claims abstract description 10
- 239000001301 oxygen Substances 0.000 claims abstract description 10
- 229910052760 oxygen Inorganic materials 0.000 claims abstract description 10
- 239000000428 dust Substances 0.000 claims abstract description 9
- 239000002918 waste heat Substances 0.000 claims abstract description 7
- 238000002844 melting Methods 0.000 claims abstract description 6
- 230000008018 melting Effects 0.000 claims abstract description 6
- 150000001339 alkali metal compounds Chemical class 0.000 claims abstract description 5
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 5
- 238000004140 cleaning Methods 0.000 claims description 12
- 239000000567 combustion gas Substances 0.000 claims description 9
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 8
- QGZKDVFQNNGYKY-UHFFFAOYSA-N Ammonia Chemical compound N QGZKDVFQNNGYKY-UHFFFAOYSA-N 0.000 claims description 6
- MYMOFIZGZYHOMD-UHFFFAOYSA-N Dioxygen Chemical compound O=O MYMOFIZGZYHOMD-UHFFFAOYSA-N 0.000 claims description 6
- 239000000654 additive Substances 0.000 claims description 5
- 238000009413 insulation Methods 0.000 claims description 5
- 239000003245 coal Substances 0.000 claims description 4
- 238000010438 heat treatment Methods 0.000 claims description 4
- 229910052757 nitrogen Inorganic materials 0.000 claims description 4
- 238000005507 spraying Methods 0.000 claims description 4
- 235000008733 Citrus aurantifolia Nutrition 0.000 claims description 3
- 235000011941 Tilia x europaea Nutrition 0.000 claims description 3
- 230000000996 additive effect Effects 0.000 claims description 3
- 229910021529 ammonia Inorganic materials 0.000 claims description 3
- 239000000919 ceramic Substances 0.000 claims description 3
- 239000004571 lime Substances 0.000 claims description 3
- 230000009970 fire resistant effect Effects 0.000 claims description 2
- JTJMJGYZQZDUJJ-UHFFFAOYSA-N phencyclidine Chemical class C1CCCCN1C1(C=2C=CC=CC=2)CCCCC1 JTJMJGYZQZDUJJ-UHFFFAOYSA-N 0.000 claims description 2
- 230000000875 corresponding effect Effects 0.000 claims 1
- 239000004744 fabric Substances 0.000 claims 1
- 239000002956 ash Substances 0.000 description 5
- 238000009434 installation Methods 0.000 description 4
- 230000008569 process Effects 0.000 description 4
- 238000010531 catalytic reduction reaction Methods 0.000 description 2
- 238000001816 cooling Methods 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- GRYSXUXXBDSYRT-WOUKDFQISA-N (2r,3r,4r,5r)-2-(hydroxymethyl)-4-methoxy-5-[6-(methylamino)purin-9-yl]oxolan-3-ol Chemical compound C1=NC=2C(NC)=NC=NC=2N1[C@@H]1O[C@H](CO)[C@@H](O)[C@H]1OC GRYSXUXXBDSYRT-WOUKDFQISA-N 0.000 description 1
- 230000008878 coupling Effects 0.000 description 1
- 238000010168 coupling process Methods 0.000 description 1
- 238000005859 coupling reaction Methods 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 239000003344 environmental pollutant Substances 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 239000010881 fly ash Substances 0.000 description 1
- 229910052602 gypsum Inorganic materials 0.000 description 1
- 239000010440 gypsum Substances 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 238000009421 internal insulation Methods 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 239000007800 oxidant agent Substances 0.000 description 1
- 231100000719 pollutant Toxicity 0.000 description 1
- 238000004321 preservation Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 238000006722 reduction reaction Methods 0.000 description 1
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
- F01K23/10—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 exhaust fluid of one cycle heating the fluid in another cycle
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
- F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
- F02C3/00—Gas-turbine plants characterised by the use of combustion products as the working fluid
- F02C3/20—Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products
- F02C3/26—Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products the fuel or oxidant being solid or pulverulent, e.g. in slurry or suspension
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
- F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
- F02C3/00—Gas-turbine plants characterised by the use of combustion products as the working fluid
- F02C3/34—Gas-turbine plants characterised by the use of combustion products as the working fluid with recycling of part of the working fluid, i.e. semi-closed cycles with combustion products in the closed part of the cycle
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
- Y02E20/00—Combustion technologies with mitigation potential
- Y02E20/16—Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
- Y02E20/00—Combustion technologies with mitigation potential
- Y02E20/32—Direct CO2 mitigation
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
- Y02E20/00—Combustion technologies with mitigation potential
- Y02E20/34—Indirect CO2mitigation, i.e. by acting on non CO2directly related matters of the process, e.g. pre-heating or heat recovery
Landscapes
- Engineering & Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- Combustion & Propulsion (AREA)
- Mechanical Engineering (AREA)
- General Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (AREA)
- Sustainable Development (AREA)
- Engine Equipment That Uses Special Cycles (AREA)
- Treating Waste Gases (AREA)
- Control Of Eletrric Generators (AREA)
- Separation By Low-Temperature Treatments (AREA)
- Chimneys And Flues (AREA)
Abstract
Abstract In the method, the raw gas flowing out of the com-bustion chamber - when the temperature is above the melting temperature of the ash - is first cooled by recirculated exhaust gas and/or air and/or oxygen to under the ash melting point temperature but above the gas turbine inlet temperature, is subsequently further cooled to approximately 650-950 °C by giving up heat to the clean gas and by admixture of recirculated exhaust gas and/or air and/or oxygen, is cleaned at this tem-perature by known methods from dust, including alkali metal compounds, SO2 and NOx, is again heated as clean gas to the permissible gas turbine inlet temperature by taking up heat from the raw gas and then flows through a gas turbine and, subsequently, a waste heat steam generator, in which water for operating a steam turbine of one or more pressure stages is preheated, evaporated and superheated.
The method is distinguished by particularly high efficiencies for the electrical current generators.
The method is distinguished by particularly high efficiencies for the electrical current generators.
Description
^- ~118178 The invention relates to a method, and an appli-ance for carrying out the method, for generating ga~es for operating a gas turbine in a combined gas turbine and ~team turbine power station, in which fine-grained to pulverized coal ic almost completely burned at a pres~ure greater than 1 bar and a temperature greater than 1000 C with air, with air enriched with oxygen or with pure oxygen alone or mixed with recirculated exhaust gas in each case to form a combustion gas which consists essentially of C02 and steam and, when air is used, also of ni~rogen, and which i8 subsequently cleaned at least from dust including alkali metal compounds and possibly from S02 and N0x, which combustion gas flows in sequence through a gas turbine and a waste heat steam generator in whiah water for operating a steam turbine is preheated, evaporated and superheated at one or a plurality of pressure stages.
Such installations have become known from the journal VGB Xraftwerkstechnik (70) 1990, No. 5, Pages 399-406, inter alia. The gases generated contain pollutant materials which would damage the gas turbine and a gas cleaning system is therefore absolutely necessary. Because it is scarcely possible to carry out effectivè cleaning of such hot, pollutant-laden gases with temperatures above the permissible entry : 21182178 temperature of modern gas turbine~, i.e. above 1200 C, the temperature of the gases must be reduced to a level of approximately 650-950 C co that the gas cleaning can be carried out by known and tested methods. Thi~
temperature level i8, in partiaular, also decisive for the dry additive method (desulphurization by spraying in lime dust) and the selective non-catalytic reduction - SNCR - method (reduction of the oxide~ of nitrogen by ammonia or a catalyzer). In order to achieve this tem~
perature level, heat is generally removed in a steam :: ~ .
power process or the sy3tem i~ operated with a very high level of excess air.
In the known method - removing heat in a steam : . . -:
process or operating with a high level of excess air -disadvantageous features are the 1088 of efficiency due to the heat transfer to the steam process at a rela-tively low temperature or due to the reduced gas tur-bine inlet temperature in the ca~e of a high level of excess air and the increased exhaust gas lo~ses. The coupling of gas turbine operation and waste heat boiler operation is also disadvantageous.
As a consequence of the discussion ahout the climate, of environmental protection and of the preser-vation of resources, the not unsubstantial increase in efficiency due to the method proposed and the appliance proposed have gained great importance, particularly in recent years.
The objec~ of the invention i8 to create a method of the type de~cribed at the beginning and the associated appliance in which the disadvant2ges described are avoided and a decisive improvement to the efficiency i8 aahieved in the generation of electrical current from coal. This object is achieved by means of the characterizing part of Patent Claim 1.
Advantageous embodiments of the invention may be taken from the su~-claims 2 to 9.
The following advantages relative to the known prior art are achieved by mean~ of the measures accord-ing to the invention:
1) Higher clean gas temperatures (1200-1400 C) can be achieved 80 that gas turbine~ can be operated with higher inlet temperatures and correspondingly higher efficiency.
Such installations have become known from the journal VGB Xraftwerkstechnik (70) 1990, No. 5, Pages 399-406, inter alia. The gases generated contain pollutant materials which would damage the gas turbine and a gas cleaning system is therefore absolutely necessary. Because it is scarcely possible to carry out effectivè cleaning of such hot, pollutant-laden gases with temperatures above the permissible entry : 21182178 temperature of modern gas turbine~, i.e. above 1200 C, the temperature of the gases must be reduced to a level of approximately 650-950 C co that the gas cleaning can be carried out by known and tested methods. Thi~
temperature level i8, in partiaular, also decisive for the dry additive method (desulphurization by spraying in lime dust) and the selective non-catalytic reduction - SNCR - method (reduction of the oxide~ of nitrogen by ammonia or a catalyzer). In order to achieve this tem~
perature level, heat is generally removed in a steam :: ~ .
power process or the sy3tem i~ operated with a very high level of excess air.
In the known method - removing heat in a steam : . . -:
process or operating with a high level of excess air -disadvantageous features are the 1088 of efficiency due to the heat transfer to the steam process at a rela-tively low temperature or due to the reduced gas tur-bine inlet temperature in the ca~e of a high level of excess air and the increased exhaust gas lo~ses. The coupling of gas turbine operation and waste heat boiler operation is also disadvantageous.
As a consequence of the discussion ahout the climate, of environmental protection and of the preser-vation of resources, the not unsubstantial increase in efficiency due to the method proposed and the appliance proposed have gained great importance, particularly in recent years.
The objec~ of the invention i8 to create a method of the type de~cribed at the beginning and the associated appliance in which the disadvant2ges described are avoided and a decisive improvement to the efficiency i8 aahieved in the generation of electrical current from coal. This object is achieved by means of the characterizing part of Patent Claim 1.
Advantageous embodiments of the invention may be taken from the su~-claims 2 to 9.
The following advantages relative to the known prior art are achieved by mean~ of the measures accord-ing to the invention:
1) Higher clean gas temperatures (1200-1400 C) can be achieved 80 that gas turbine~ can be operated with higher inlet temperatures and correspondingly higher efficiency.
2) The heat losses relative to the prior art are smaller due to the raw gas/clean gas heat exchange and the efficiency of the overall installation is improved by this means.
3) The gas turbine can be operated with its own chim-ney independently of the waste heat boiler.
. 5 4) The internal insulation of the pressure ves3elsand the connecting conduits, which are necessary in any case, is simultaneously used as a heat exchanger and the temperature of the pressure ves-sels and the connecting conduit walls is reduced --J ~118178 ~ ~
for the same in~ulation thickne~s. Under certain circumstances, it is possible to dispense with the separate heat exchanger (15 in Figure 2).
.
The invention is explained in more detail using the description and Figures 1 and 2.
Figure 1 show3 a combined gas turbine and steam turbine power station which includes the installation complex 31-37, namely the compressor for exhaust gas 31, the compressor for air or for air enriched with oxygen or for pure oxygen 32, the combu~tion chamber 33, the heat exchanger 34, the gas cleaning system 35, the gas turb,ine ~with electrical generator) 36 and the wa~te heat steam generator (including steam turbine and electrical generator) 37.
Figure 2 shows the installation parts 33, 34 and 35, fine-grained to pulverized coal under pressure, for example 16 bar, together with air or with air enriched with oxygen ox with pure oxygen alone or with recircu-lated exhaust gas in each case being supplied via theconnecting piece 11 to the combustion chamber 27 and 'being burned in the latter. The combustion then takes place either at a temperature at which the ash remains solid or at a temperature at which the ash can be witih-drawn in the molten state. The combustion temperaturecan be adjusted by the selection of the air excess and/or oxygen excess and~or exhaust gas recirculation.
The combustion chamber 27 is of cyclone type 90 that a major proportion of the ash can be precipitated and : --- 211817~
extracted via the connecting piece 14. If the combus-tion temperature in the combustion chamber is above the ash melting point, the combustion gas at the outlet connecting piece of the combustion chamber 12 is cooled to a temperature below the a h melting point by admix-ture of recirculated exhaust gas or a gas similar to that used for combustion (via the connecting piece 25) in order to avoid slagging of the subsequent conduit and of the heat exchanger. In both cases (solid or molten ash in the combu~tion chamber), the combustion gases (~ raw gases) then flow through the connecting conduits 2, which are configured as a heat exchanger~
and - if necessary - via the raw gas inlet connecting piece 16 through the heat exchanger 15, which i8 arranged for cooling the raw gases and heating the clean gases in the heating surface space 22 of the heat exchanger pressure vessel 3.
The raw gases leave the heat exchanger pressure vessel via the raw gas outlet 17 and flow via the con-necting conduit 4, which i8 provided with insulation 7only, and via the raw gas inlet 18 into the gas clean-ing pressure vessel 5, recirculated exhaust gas or a gas similar to that used for combustion being mixed via the connecting piece 30 with the raw gases, which have already been cooled by giving up heat to the clean gas, that they are cooled to a temperature between approximately 650 to 950 C. At this temperature, the raw ga~es can have dust (including alkali metal com-pounds) removed by known methods, such as cyclones, ~. ~118178 :~ ~
ceramic filter tubes 24 etc. and are, furthermore, desulphurized by likewise known method~, for example the dry additive method, i.e. by spraying in lime dust, and are freed from oxides of nitrogen by, for example, the selective non-catalytic reduction - SNCR - method, i.e. by spraying in ammonia. These gas cleaning meth-ods 35 are arranged in a vessel 5 from which fly ash and other residue~ such as gypsum can be withdrawn via the outlet 20. The supply of the additives take~ place via the connecting piece 28. The cleaned combustion gases (~ clean gases) then flow via the clean gas out-let 19, the connecting conduit 6 - which is only pro-vided with insulation 7 - and the connecting piece 23 back to the heat exchanger pressure vessel 3. The clean gas then flows through the heat exchanger 15 and/or the ducts 10, 9 and 8, which are configured as heat exchangers, of the heat exchanger pressure vessel 3, of the connecting conduit 2 and of the combustion chamber pressure vessel 1, taking up heat from the uncleaned combustion gaseE (= raw gases) in the process and leaving the combustion chamber pressure vessel via the connecting piece 13 at the permissible gas turbine inlet temperature. The clean gas then flows sequen-tially through the gas turbine 36 in Figure 1 and the waste heat steam generator 37 in Figure 1. In this waste heat steam generator 37, water for operating a steam turbine is preheated, evaporated and superheated at one or a plurality of pre~sure stages (a possible cycle with three pre~sure stages is represented in ~118178 Figure 1). Water can also be tapped off for heating purposes.
After the exhaust heat boiler, part of the exhaust gases can be recirculated by means of a compressor 31 driven by the ga~ turbine, see Figure 1, to the pos-itions-ll, 26 and 30 listed above. The rest can - if this is necessary or has not already occurred - be cleaned in known manner to permissible emi~sion figures and leaves the power station via a chimney. If pure oxygen i8 used as the oxidizing agent, a gas mixture which consists almost exclusively of C02 and steam occurs - as already mentioned - as the exhaust gas.
With appropriate further cooling, stéam condenses first and finally the C02 with the residual gas traces also becomes fluid or freezes. This produces a power station which i8 free of exhaust gas, if the nitrogen separated from the air during the production of the oxygen is ignored. In addition, the compressor for air or for air enriched with oxygen or for pure oxygen 32 -see Figure 1 - is also driven by the gas turbine 36.
The combustion chamber pressure vessel 1, the con-necting conduit 2 and the heat exchanger pres~ure ves-sel 3 are constructed in such a way that the pre3sure-carrying wall is located on the outside. Insulation !7~
ducts 8, 9 and 10 in which clean gas flows and a jacket 21, which is heat conducting, substantially impermeable to gas and fire-resistant, follow in sequence towards the inside. It is only within this jacket that raw gas flows.
. 5 4) The internal insulation of the pressure ves3elsand the connecting conduits, which are necessary in any case, is simultaneously used as a heat exchanger and the temperature of the pressure ves-sels and the connecting conduit walls is reduced --J ~118178 ~ ~
for the same in~ulation thickne~s. Under certain circumstances, it is possible to dispense with the separate heat exchanger (15 in Figure 2).
.
The invention is explained in more detail using the description and Figures 1 and 2.
Figure 1 show3 a combined gas turbine and steam turbine power station which includes the installation complex 31-37, namely the compressor for exhaust gas 31, the compressor for air or for air enriched with oxygen or for pure oxygen 32, the combu~tion chamber 33, the heat exchanger 34, the gas cleaning system 35, the gas turb,ine ~with electrical generator) 36 and the wa~te heat steam generator (including steam turbine and electrical generator) 37.
Figure 2 shows the installation parts 33, 34 and 35, fine-grained to pulverized coal under pressure, for example 16 bar, together with air or with air enriched with oxygen ox with pure oxygen alone or with recircu-lated exhaust gas in each case being supplied via theconnecting piece 11 to the combustion chamber 27 and 'being burned in the latter. The combustion then takes place either at a temperature at which the ash remains solid or at a temperature at which the ash can be witih-drawn in the molten state. The combustion temperaturecan be adjusted by the selection of the air excess and/or oxygen excess and~or exhaust gas recirculation.
The combustion chamber 27 is of cyclone type 90 that a major proportion of the ash can be precipitated and : --- 211817~
extracted via the connecting piece 14. If the combus-tion temperature in the combustion chamber is above the ash melting point, the combustion gas at the outlet connecting piece of the combustion chamber 12 is cooled to a temperature below the a h melting point by admix-ture of recirculated exhaust gas or a gas similar to that used for combustion (via the connecting piece 25) in order to avoid slagging of the subsequent conduit and of the heat exchanger. In both cases (solid or molten ash in the combu~tion chamber), the combustion gases (~ raw gases) then flow through the connecting conduits 2, which are configured as a heat exchanger~
and - if necessary - via the raw gas inlet connecting piece 16 through the heat exchanger 15, which i8 arranged for cooling the raw gases and heating the clean gases in the heating surface space 22 of the heat exchanger pressure vessel 3.
The raw gases leave the heat exchanger pressure vessel via the raw gas outlet 17 and flow via the con-necting conduit 4, which i8 provided with insulation 7only, and via the raw gas inlet 18 into the gas clean-ing pressure vessel 5, recirculated exhaust gas or a gas similar to that used for combustion being mixed via the connecting piece 30 with the raw gases, which have already been cooled by giving up heat to the clean gas, that they are cooled to a temperature between approximately 650 to 950 C. At this temperature, the raw ga~es can have dust (including alkali metal com-pounds) removed by known methods, such as cyclones, ~. ~118178 :~ ~
ceramic filter tubes 24 etc. and are, furthermore, desulphurized by likewise known method~, for example the dry additive method, i.e. by spraying in lime dust, and are freed from oxides of nitrogen by, for example, the selective non-catalytic reduction - SNCR - method, i.e. by spraying in ammonia. These gas cleaning meth-ods 35 are arranged in a vessel 5 from which fly ash and other residue~ such as gypsum can be withdrawn via the outlet 20. The supply of the additives take~ place via the connecting piece 28. The cleaned combustion gases (~ clean gases) then flow via the clean gas out-let 19, the connecting conduit 6 - which is only pro-vided with insulation 7 - and the connecting piece 23 back to the heat exchanger pressure vessel 3. The clean gas then flows through the heat exchanger 15 and/or the ducts 10, 9 and 8, which are configured as heat exchangers, of the heat exchanger pressure vessel 3, of the connecting conduit 2 and of the combustion chamber pressure vessel 1, taking up heat from the uncleaned combustion gaseE (= raw gases) in the process and leaving the combustion chamber pressure vessel via the connecting piece 13 at the permissible gas turbine inlet temperature. The clean gas then flows sequen-tially through the gas turbine 36 in Figure 1 and the waste heat steam generator 37 in Figure 1. In this waste heat steam generator 37, water for operating a steam turbine is preheated, evaporated and superheated at one or a plurality of pre~sure stages (a possible cycle with three pre~sure stages is represented in ~118178 Figure 1). Water can also be tapped off for heating purposes.
After the exhaust heat boiler, part of the exhaust gases can be recirculated by means of a compressor 31 driven by the ga~ turbine, see Figure 1, to the pos-itions-ll, 26 and 30 listed above. The rest can - if this is necessary or has not already occurred - be cleaned in known manner to permissible emi~sion figures and leaves the power station via a chimney. If pure oxygen i8 used as the oxidizing agent, a gas mixture which consists almost exclusively of C02 and steam occurs - as already mentioned - as the exhaust gas.
With appropriate further cooling, stéam condenses first and finally the C02 with the residual gas traces also becomes fluid or freezes. This produces a power station which i8 free of exhaust gas, if the nitrogen separated from the air during the production of the oxygen is ignored. In addition, the compressor for air or for air enriched with oxygen or for pure oxygen 32 -see Figure 1 - is also driven by the gas turbine 36.
The combustion chamber pressure vessel 1, the con-necting conduit 2 and the heat exchanger pres~ure ves-sel 3 are constructed in such a way that the pre3sure-carrying wall is located on the outside. Insulation !7~
ducts 8, 9 and 10 in which clean gas flows and a jacket 21, which is heat conducting, substantially impermeable to gas and fire-resistant, follow in sequence towards the inside. It is only within this jacket that raw gas flows.
Claims (9)
1. A method for generating gases for operating a gas turbine in a combined gas turbine and steam turbine power station, in which fine-grained to pulverized coal is almost completely burned at a pressure greater than 1 bar and a temperature greater than 1000 °C with air, with air enriched with oxygen or with pure oxygen alone or mixed with recirculated exhaust gas in each case to form a combustion gas which consists essentially of CO2 and steam and, when air is used, also of nitrogen, and which is subsequently cleaned at least from dust including alkali metal compounds and possibly from SO2 and NOX, which combustion gas flows in sequence through a gas turbine and a waste heat steam generator in which water for operating a steam turbine is preheated, evaporated and superheated at one or a plurality of pressure stages, wherein combustion gas = raw gas flowing from the combustion chamber is cooled to approximately 650-950 °C, by rejecting heat to the clean gas and by subsequent admixture via the connecting piece of recirculated exhaust gas or a gas similar to that used for combustion, and is cleaned at this temperature, using known methods such as cyclones or ceramic filters, at least from dust including alkali metal compounds and possibly from SO2 and/or NOx by likewise known methods, for example the supply of lime dust (dry additive method) and ammonia (SNCR method), and is heated again to the permissible gas turbine inlet temperature as clean gas by acceptance of heat from raw gas.
2. The method for generating gases as claimed in claim 1, wherein the combustion in the combustion chamber is carried out above the gas turbine inlet tem-perature and below the ash melting point by correspond-ing air and/or oxygen surplus and/or exhaust gas recir-culation so that the ash can be withdrawn in dust form via the ash outlet connecting piece.
3. The method for generating gases as claimed in claim 1, wherein combustion in the combustion chamber takes place at such temperatures that the ash is with-drawn in a molten state via the ash outlet connecting piece and the combustion gas at the outlet from the combustion chamber is cooled to a temperature below the ash melting point but above the permissible gas outlet temperature by admixture via the connecting piece of recirculated exhaust gas or a gas similar to that used for combustion.
4. An appliance for carrying out the method as claimed in claim 1, wherein the combustion chamber is configured as a cyclone combustion chamber, the inside of the walls of the combustion chamber pressure vessel, of the connecting conduit and of the heat exchanger pressure vessel are respectively provided with a ther-mal insulation and a jacket, the jacket being con-figured as a heat exchanger which has sequentially con-nected ducts, and the last duct is connected, if appro-priate, via a heat exchanger by the outlet connecting piece of the cleaning pressure vessel and, if appropri-ate, a heat exchanger is arranged in the heating surface space of the heat exchanger pressure vessel, the inside of the enclosing walls of the connecting piece conduits and of the gas cleaning pressure vessel being provided with thermal insulation.
5. The appliance for carrying out the method, as claimed in claim 4, wherein the gas cleaning pressure vessel is provided with a filter which is configured as a fabric filter.
6. The appliance for carrying out the method, as claimed in claims 4 and 5, wherein the gas cleaning pressure vessel is provided with a filter which is con-figured as a ceramic filter.
7. The appliance for carrying out the method, as claimed in claims 4 to 6, wherein the sequentially con-nected ducts are each formed by a plurality of ducts arranged in parallel.
8. The appliance for carrying out the method, as claimed in claims 4 to 7, wherein the jacket is fire-resistant, substantially impermeable to gas and ther-mally conducting.
9. The appliance for carrying out the method, as claimed in claims 4 to 8, wherein the connecting con-duit to the gas cleaning pressure vessel or to the gas cleaning pressure vessels is provided with an appliance for spraying in additives.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| DE4335136A DE4335136C2 (en) | 1992-10-22 | 1993-10-15 | Method and device for carrying out the method for generating gases for operating a gas turbine in a combined gas and steam power plant |
| DEP4335136.0 | 1993-10-15 |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2118178A1 true CA2118178A1 (en) | 1995-04-16 |
Family
ID=6500190
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002118178A Abandoned CA2118178A1 (en) | 1993-10-15 | 1994-10-14 | Method and appliance for generating gases for operating a gas turbine |
Country Status (9)
| Country | Link |
|---|---|
| EP (1) | EP0648919B1 (en) |
| JP (1) | JP3008251B2 (en) |
| AT (1) | ATE175004T1 (en) |
| CA (1) | CA2118178A1 (en) |
| CZ (1) | CZ283962B6 (en) |
| HR (1) | HRP940634B1 (en) |
| HU (1) | HU217014B (en) |
| PL (1) | PL176719B1 (en) |
| SK (1) | SK124494A3 (en) |
Families Citing this family (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| EP1413554A1 (en) * | 2002-10-23 | 2004-04-28 | Siemens Aktiengesellschaft | Gas and steam power plant for desalination of water |
| US8545681B2 (en) * | 2009-12-23 | 2013-10-01 | General Electric Company | Waste heat driven desalination process |
| DE102011110213A1 (en) * | 2011-08-16 | 2013-02-21 | Thyssenkrupp Uhde Gmbh | Method and device for recirculating exhaust gas from a gas turbine with subsequent waste heat boiler |
| US9492780B2 (en) | 2014-01-16 | 2016-11-15 | Bha Altair, Llc | Gas turbine inlet gas phase contaminant removal |
| US10502136B2 (en) | 2014-10-06 | 2019-12-10 | Bha Altair, Llc | Filtration system for use in a gas turbine engine assembly and method of assembling thereof |
Family Cites Families (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| DE1240338B (en) * | 1961-07-12 | 1967-05-11 | Ladislav Michalicka | Gas turbine plant with a pressure combustion chamber for solid fuel |
| DE2733029A1 (en) * | 1976-11-04 | 1979-02-08 | Steag Ag | PLANT FOR GENERATING ENERGY FROM SOLIDS, FOSSILS AND IN PARTICULAR BALLAST-RICH FUELS, IN PARTICULAR HARD COAL |
| DE3506102A1 (en) * | 1985-02-19 | 1986-08-21 | Mitsubishi Jukogyo K.K., Tokio/Tokyo | Coal-fired power station |
| DE3731082C1 (en) * | 1987-09-16 | 1989-04-13 | Steag Ag | Method and plant for obtaining energy from solid, high-ballast fuels |
-
1994
- 1994-09-27 EP EP94115162A patent/EP0648919B1/en not_active Expired - Lifetime
- 1994-09-27 AT AT94115162T patent/ATE175004T1/en not_active IP Right Cessation
- 1994-09-30 HR HRP4335136.0A patent/HRP940634B1/en not_active IP Right Cessation
- 1994-10-05 CZ CZ942442A patent/CZ283962B6/en not_active IP Right Cessation
- 1994-10-07 JP JP6279652A patent/JP3008251B2/en not_active Expired - Lifetime
- 1994-10-11 SK SK1244-94A patent/SK124494A3/en unknown
- 1994-10-13 PL PL94305429A patent/PL176719B1/en unknown
- 1994-10-14 CA CA002118178A patent/CA2118178A1/en not_active Abandoned
- 1994-10-14 HU HU9402972A patent/HU217014B/en not_active IP Right Cessation
Also Published As
| Publication number | Publication date |
|---|---|
| HRP940634B1 (en) | 1999-12-31 |
| JPH07166887A (en) | 1995-06-27 |
| EP0648919A2 (en) | 1995-04-19 |
| EP0648919A3 (en) | 1995-08-02 |
| EP0648919B1 (en) | 1998-12-23 |
| PL176719B1 (en) | 1999-07-30 |
| CZ244294A3 (en) | 1995-06-14 |
| HU9402972D0 (en) | 1995-02-28 |
| PL305429A1 (en) | 1995-04-18 |
| CZ283962B6 (en) | 1998-07-15 |
| HUT72198A (en) | 1996-03-28 |
| SK124494A3 (en) | 1996-01-10 |
| HU217014B (en) | 1999-11-29 |
| ATE175004T1 (en) | 1999-01-15 |
| HRP940634A2 (en) | 1996-08-31 |
| JP3008251B2 (en) | 2000-02-14 |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| FZDE | Discontinued |