CA2618030C - A method for operating a gas turbine and a gas turbine for implementing the method - Google Patents
A method for operating a gas turbine and a gas turbine for implementing the method Download PDFInfo
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- CA2618030C CA2618030C CA2618030A CA2618030A CA2618030C CA 2618030 C CA2618030 C CA 2618030C CA 2618030 A CA2618030 A CA 2618030A CA 2618030 A CA2618030 A CA 2618030A CA 2618030 C CA2618030 C CA 2618030C
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- Prior art keywords
- combustor
- turbine
- syngas
- gas turbine
- hot gases
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- 238000000034 method Methods 0.000 title claims abstract description 21
- 239000007789 gas Substances 0.000 claims abstract description 102
- 239000003245 coal Substances 0.000 claims abstract description 48
- 238000003303 reheating Methods 0.000 claims abstract description 20
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims abstract description 11
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 claims abstract description 9
- 239000001301 oxygen Substances 0.000 claims abstract description 9
- 229910052760 oxygen Inorganic materials 0.000 claims abstract description 9
- 229910052757 nitrogen Inorganic materials 0.000 claims abstract description 5
- 239000000446 fuel Substances 0.000 claims description 19
- 238000002309 gasification Methods 0.000 claims description 18
- 238000000926 separation method Methods 0.000 claims description 12
- 238000001816 cooling Methods 0.000 claims description 10
- 238000001914 filtration Methods 0.000 claims description 10
- 238000004891 communication Methods 0.000 claims description 8
- 239000012530 fluid Substances 0.000 claims description 8
- 230000006835 compression Effects 0.000 claims description 5
- 238000007906 compression Methods 0.000 claims description 5
- 238000002485 combustion reaction Methods 0.000 description 11
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 description 10
- 239000003546 flue gas Substances 0.000 description 10
- 238000011084 recovery Methods 0.000 description 5
- RLQJEEJISHYWON-UHFFFAOYSA-N flonicamid Chemical compound FC(F)(F)C1=CC=NC=C1C(=O)NCC#N RLQJEEJISHYWON-UHFFFAOYSA-N 0.000 description 2
- 230000003247 decreasing effect Effects 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
Classifications
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- 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
- F02C3/28—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 using a separate gas producer for gasifying the fuel before combustion
-
- 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
- F02C6/00—Plural gas-turbine plants; Combinations of gas-turbine plants with other apparatus; Adaptations of gas-turbine plants for special use
- F02C6/003—Gas-turbine plants with heaters between turbine stages
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
- F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
- F25J3/04—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream for air
- F25J3/04521—Coupling of the air fractionation unit to an air gas-consuming unit, so-called integrated processes
- F25J3/04527—Integration with an oxygen consuming unit, e.g. glass facility, waste incineration or oxygen based processes in general
- F25J3/04539—Integration with an oxygen consuming unit, e.g. glass facility, waste incineration or oxygen based processes in general for the H2/CO synthesis by partial oxidation or oxygen consuming reforming processes of fuels
- F25J3/04545—Integration with an oxygen consuming unit, e.g. glass facility, waste incineration or oxygen based processes in general for the H2/CO synthesis by partial oxidation or oxygen consuming reforming processes of fuels for the gasification of solid or heavy liquid fuels, e.g. integrated gasification combined cycle [IGCC]
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
- F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
- F25J3/04—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream for air
- F25J3/04521—Coupling of the air fractionation unit to an air gas-consuming unit, so-called integrated processes
- F25J3/04563—Integration with a nitrogen consuming unit, e.g. for purging, inerting, cooling or heating
- F25J3/04575—Integration with a nitrogen consuming unit, e.g. for purging, inerting, cooling or heating for a gas expansion plant, e.g. dilution of the combustion gas in a gas turbine
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
- F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
- F25J3/04—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream for air
- F25J3/04521—Coupling of the air fractionation unit to an air gas-consuming unit, so-called integrated processes
- F25J3/04593—The air gas consuming unit is also fed by an air stream
- F25J3/046—Completely integrated air feed compression, i.e. common MAC
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J2200/00—Processes or apparatus using separation by rectification
- F25J2200/20—Processes or apparatus using separation by rectification in an elevated pressure multiple column system wherein the lowest pressure column is at a pressure well above the minimum pressure needed to overcome pressure drop to reject the products to atmosphere
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J2230/00—Processes or apparatus involving steps for increasing the pressure of gaseous process streams
- F25J2230/40—Processes or apparatus involving steps for increasing the pressure of gaseous process streams the fluid being air
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J2240/00—Processes or apparatus involving steps for expanding of process streams
- F25J2240/80—Hot exhaust gas turbine combustion engine
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- 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
- Y02E20/16—Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]
- Y02E20/18—Integrated gasification combined cycle [IGCC], e.g. combined with carbon capture and storage [CCS]
Landscapes
- Engineering & Computer Science (AREA)
- Mechanical Engineering (AREA)
- General Engineering & Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- Combustion & Propulsion (AREA)
- Physics & Mathematics (AREA)
- Thermal Sciences (AREA)
- Engine Equipment That Uses Special Cycles (AREA)
- Separation By Low-Temperature Treatments (AREA)
Abstract
The invention relates to a method for operating a gas turbine (11) in a combined cycle power plant (40), in which method, air is drawn in through the gas turbine (11), compressed, and the compressed air is led to a combustor (18, 19) [text does not give specific combuster references though the list does]to burn a syngas that is recovered from coal, whereby a portion of the compressed air is separated into oxygen and nitrogen. An improved degree of efficiency is achieved by virtue of the fact that a gas turbine (11) with reheating is used, which comprises two combustors (18, 19) and two turbines (16, 17), whereby in the first combustor (18) syngas is burned with the compressed air and the resultant hot gases are expanded in the first turbine (16). In the second combustor, syngas is burned with the gases coming from the first turbine (16) and the resultant hot gases are expanded in the second turbine (17) and the generation of the syngas is undertaken in such a manner that the syngas that is generated can be led directly to the first combustor (18).
Description
SPECIFICATION
A METHOD FOR OPERATING A GAS TURBINE AND A GAS TURBINE FOR
IMPLEMENTING THE METHOD
TECHNICAL FIELD
. The present invention relates to the field of power plant technology. It pertains to a method for operating a (stationary) gas turbine, as well as a gas turbine for . 10 implementing the method.
PRIOR ART
A gas turbine with reheating (reheat gas turbine) is known (see, for example, the United States patent application US-A-5,577,378 or "State of the art gas turbines ¨
a brief update," ABB Review 02/1997, Fig. 15, turbine type GT26), which combines flexible operation with very low flue gas emission levels.
The machinery architecture of gas turbine type GT26 is unique and lends itself exceptionally well to the realization of a concept that is the subject matter of the present invention, because:
- Even in the case of the compressor, there is a significant diversion of = compressor air at intermediate compressor pressures, - The concept of sequential combustion renders increased stability of combustion possible, with decreased levels of excess oxygen, and - A secondary air system is present, which renders it possible to divert air from the compressor, to cool [it] down, and to use the cooled air to cool the combustor and the turbine. =
The principle of the known gas turbine with reheating is shown in Fig. 1. The gas turbine 11, which is a portion of the combined cycle power plant 10, comprises two compressors, one connected behind the other, on a shaft 15 that is shared in
A METHOD FOR OPERATING A GAS TURBINE AND A GAS TURBINE FOR
IMPLEMENTING THE METHOD
TECHNICAL FIELD
. The present invention relates to the field of power plant technology. It pertains to a method for operating a (stationary) gas turbine, as well as a gas turbine for . 10 implementing the method.
PRIOR ART
A gas turbine with reheating (reheat gas turbine) is known (see, for example, the United States patent application US-A-5,577,378 or "State of the art gas turbines ¨
a brief update," ABB Review 02/1997, Fig. 15, turbine type GT26), which combines flexible operation with very low flue gas emission levels.
The machinery architecture of gas turbine type GT26 is unique and lends itself exceptionally well to the realization of a concept that is the subject matter of the present invention, because:
- Even in the case of the compressor, there is a significant diversion of = compressor air at intermediate compressor pressures, - The concept of sequential combustion renders increased stability of combustion possible, with decreased levels of excess oxygen, and - A secondary air system is present, which renders it possible to divert air from the compressor, to cool [it] down, and to use the cooled air to cool the combustor and the turbine. =
The principle of the known gas turbine with reheating is shown in Fig. 1. The gas turbine 11, which is a portion of the combined cycle power plant 10, comprises two compressors, one connected behind the other, on a shaft 15 that is shared in
2 common, namely a low pressure compressor 13 and a high pressure compressor 14, as well as two combustors, namely a high pressure combustor 18 and a reheat combustor19, and pertinent turbines, namely a high pressure turbine 16 and a low pressure turbine 17. Shaft 15 drives a generator 12.
The way in which the unit works is the following: air is drawn in via an air inlet 20 by the low pressure compressor 13 and initially compressed to an intermediate level of pressure (ca. 20 bar). The high pressure compressor 14 then compresses the air further to a level of high pressure (ca. 32 bar). Cooling air is diverted, both at the intermediate level of pressure and at the level of high pressure, and cooled in pertinent OTC coolers (OTC = Once Through Cooler) 23 and 24 and conducted to the combustors 18 and 19 and turbines 16, 17 for cooling purposes via cooling lines 25 and 26. The remaining air from the high pressure compressor 14 is led to the high pressure combustor 18 and heated there by the combustion of a fuel brought in via the fuel feedline 21. The resultant flue gas is then expanded to an intermediate pressure level in the downstream high pressure turbine 16, as it performs work. After the expansion, the flue gas is heated again in the reheat combustor 19 by the combustion of a fuel led in via the fuel inlet 22, before it is expanded in the downstream low pressure turbine 17, performing additional work in the process.
The cooling air, which flows through the cooling lines 25, 26, is sprayed in at suitable points of the combustors 18, 19 and turbines 16, 17 to limit the material temperatures to a reasonable degree. The flue gas coming from the low pressure turbine 17 is sent through a heat recovery steam generator (HRSG) 27 to generate steam, which flows within a water-steam circuit through a steam turbine 29, performing additional work there. After flowing through the heat recovery steam generator 27, the flue gas is finally given off to the outside through a flue gas line 28. The OTC coolers 23, 24 are a portion of the water-steam circuit;
superheated steam is generated at their outlets.
The way in which the unit works is the following: air is drawn in via an air inlet 20 by the low pressure compressor 13 and initially compressed to an intermediate level of pressure (ca. 20 bar). The high pressure compressor 14 then compresses the air further to a level of high pressure (ca. 32 bar). Cooling air is diverted, both at the intermediate level of pressure and at the level of high pressure, and cooled in pertinent OTC coolers (OTC = Once Through Cooler) 23 and 24 and conducted to the combustors 18 and 19 and turbines 16, 17 for cooling purposes via cooling lines 25 and 26. The remaining air from the high pressure compressor 14 is led to the high pressure combustor 18 and heated there by the combustion of a fuel brought in via the fuel feedline 21. The resultant flue gas is then expanded to an intermediate pressure level in the downstream high pressure turbine 16, as it performs work. After the expansion, the flue gas is heated again in the reheat combustor 19 by the combustion of a fuel led in via the fuel inlet 22, before it is expanded in the downstream low pressure turbine 17, performing additional work in the process.
The cooling air, which flows through the cooling lines 25, 26, is sprayed in at suitable points of the combustors 18, 19 and turbines 16, 17 to limit the material temperatures to a reasonable degree. The flue gas coming from the low pressure turbine 17 is sent through a heat recovery steam generator (HRSG) 27 to generate steam, which flows within a water-steam circuit through a steam turbine 29, performing additional work there. After flowing through the heat recovery steam generator 27, the flue gas is finally given off to the outside through a flue gas line 28. The OTC coolers 23, 24 are a portion of the water-steam circuit;
superheated steam is generated at their outlets.
3 Great operational flexibility is achieved as a result of both combustions in combustors 18 and 19, which are independent of one another and follow one another sequentially; the combustor temperatures can be adjusted in such a manner that the maximal degree of efficiency is achieved within the existing limits. The low flue gas levels of the sequential combustion system are assured by the inherently low emission levels that can be achieved in conjunction with the reheating (under certain conditions, the second combustion even leads to a consumption of N0x).
On the other hand, combined cycle power plants with single-stage combustion in the gas turbines are known (see, for example, the U.S. patent application US-A-4,785,622 or US-B2-6,513,317), in which a coal gasifier is integrated, in order to provide the fuel that is necessary for the gas turbine in the form of syngas, which is recovered from coal. Such combined cycle power plants are characterized as IGCC plants (IGCC = Integrated Gasification Combined Cycle).
SUMMARY OF THE INVENTION
Some embodiments of the present disclosure proceed from the knowledge that as a result of the use of gas turbines with reheating in an IGCC unit, the advantages of this type of gas turbine can be made usable for the unit in a particular manner.
According to an aspect of the present invention, there is provided a method for operating a gas turbine, the method comprising: drawing in air through and compressing air in the gas turbine; conducting compressed air to a combustor;
combusting a syngas that is recovered from coal with said compressed air in said combustor, to produce hot gases; expanding the hot gases from said combustor in a downstream turbine as said hot gases perform work; separating a portion of said compressed air into oxygen and nitrogen; generating syngas in a coal gasifier using the oxygen from said separating; conducting a portion of said compressed air to and cooling portions of the gas turbine that are exposed to hot air with said compressed 3a air; wherein said gas turbine comprises a reheating gas turbine which comprises two combustors and two turbines; wherein combusting a syngas comprises combusting syngas in the first combustor with the compressed air at pressures within the range of 40-65 bar; wherein expanding the hot gases from said combustor comprises expanding in the first turbine; combusting syngas in the second combustor using gases coming from the first turbine, to generate hot gases; expanding the hot gases from said second combustor in the second turbine; and wherein generating syngas comprises generating syngas suitable to be led directly to the first combustor.
According to another aspect of the present invention, there is provided a reheating gas turbine comprising: compressors for the compression of air that has been drawn in; a first turbine and a second turbine; a first combustor and a second combustor, said first combustor in fluid communication with at least one of said compressors and with said first turbine, said second combustor in fluid communication with said first turbine and said second turbine; wherein the first combustor is configured and arranged to combust a fuel with compressed air from said at least one of said compressors at pressures within a range of 40-65 bar, to generate hot gases;
wherein said first turbine is configured and arranged to expand hot gases from said first combustor; wherein the second combustor is configured and arranged to combust a fuel with gases from the first turbine, to generate hot gases;
wherein the second turbine is configured and arranged to expand hot gases from said second combustor; a coal gasification syngas generation unit comprising an air separation unit, which receives compressed air from the compressors and having an outlet connected with the combustors configured and arranged to supply the combustors with syngas as fuel; and wherein the coal gasification syngas generation unit outlet is directly fluidly connected to the first combustor.
According to another aspect of the present invention, there is provided a reheating gas turbine comprising: compressors for the compression of air that has been drawn in; a first turbine and second turbine; a first combustor and a second combustor, said 3b first combustor in fluid communication with at least one of said compressors and with said first turbine, said second combustor in fluid communication with said first turbine and said second turbine; wherein the first combustor is configured and arranged to combust a fuel with compressed air from said at least one of said compressors at pressures within a range of 40-65 bar, to generate hot gases; wherein said first turbine is configured and arranged to expand hot gases from said first combustor;
wherein the second combustor is configured and arranged to combust a fuel with gases from the first turbine, to generate hot gases; wherein the second turbine is configured and arranged to expand hot gases from said second combustor; a coal gasification syngas generation unit having an outlet connected with the combustors configured and arranged to supply the combustors with syngas as fuel; wherein the coal gasification syngas generation unit outlet is directly fluidly connected to the first combuster, and wherein the coal gasification syngas generation unit comprises a CO2 separator which functions at pressures >40 bar.
Some embodiments of the present disclosure are directed to a method for operating a gas turbine that works together with a coal gasifier, which is characterized by an improved degree of efficiency, and which can, in addition, be realized to particularly good effect using available components, and to create a gas turbine for implementing the method.
In one aspect, a gas turbine with reheating, which comprises two combustors and two turbines, is used in a gas turbine unit that works with syngas from a coal gasifier, in which, in the first combustor, syngas is burned using the compressed =
On the other hand, combined cycle power plants with single-stage combustion in the gas turbines are known (see, for example, the U.S. patent application US-A-4,785,622 or US-B2-6,513,317), in which a coal gasifier is integrated, in order to provide the fuel that is necessary for the gas turbine in the form of syngas, which is recovered from coal. Such combined cycle power plants are characterized as IGCC plants (IGCC = Integrated Gasification Combined Cycle).
SUMMARY OF THE INVENTION
Some embodiments of the present disclosure proceed from the knowledge that as a result of the use of gas turbines with reheating in an IGCC unit, the advantages of this type of gas turbine can be made usable for the unit in a particular manner.
According to an aspect of the present invention, there is provided a method for operating a gas turbine, the method comprising: drawing in air through and compressing air in the gas turbine; conducting compressed air to a combustor;
combusting a syngas that is recovered from coal with said compressed air in said combustor, to produce hot gases; expanding the hot gases from said combustor in a downstream turbine as said hot gases perform work; separating a portion of said compressed air into oxygen and nitrogen; generating syngas in a coal gasifier using the oxygen from said separating; conducting a portion of said compressed air to and cooling portions of the gas turbine that are exposed to hot air with said compressed 3a air; wherein said gas turbine comprises a reheating gas turbine which comprises two combustors and two turbines; wherein combusting a syngas comprises combusting syngas in the first combustor with the compressed air at pressures within the range of 40-65 bar; wherein expanding the hot gases from said combustor comprises expanding in the first turbine; combusting syngas in the second combustor using gases coming from the first turbine, to generate hot gases; expanding the hot gases from said second combustor in the second turbine; and wherein generating syngas comprises generating syngas suitable to be led directly to the first combustor.
According to another aspect of the present invention, there is provided a reheating gas turbine comprising: compressors for the compression of air that has been drawn in; a first turbine and a second turbine; a first combustor and a second combustor, said first combustor in fluid communication with at least one of said compressors and with said first turbine, said second combustor in fluid communication with said first turbine and said second turbine; wherein the first combustor is configured and arranged to combust a fuel with compressed air from said at least one of said compressors at pressures within a range of 40-65 bar, to generate hot gases;
wherein said first turbine is configured and arranged to expand hot gases from said first combustor; wherein the second combustor is configured and arranged to combust a fuel with gases from the first turbine, to generate hot gases;
wherein the second turbine is configured and arranged to expand hot gases from said second combustor; a coal gasification syngas generation unit comprising an air separation unit, which receives compressed air from the compressors and having an outlet connected with the combustors configured and arranged to supply the combustors with syngas as fuel; and wherein the coal gasification syngas generation unit outlet is directly fluidly connected to the first combustor.
According to another aspect of the present invention, there is provided a reheating gas turbine comprising: compressors for the compression of air that has been drawn in; a first turbine and second turbine; a first combustor and a second combustor, said 3b first combustor in fluid communication with at least one of said compressors and with said first turbine, said second combustor in fluid communication with said first turbine and said second turbine; wherein the first combustor is configured and arranged to combust a fuel with compressed air from said at least one of said compressors at pressures within a range of 40-65 bar, to generate hot gases; wherein said first turbine is configured and arranged to expand hot gases from said first combustor;
wherein the second combustor is configured and arranged to combust a fuel with gases from the first turbine, to generate hot gases; wherein the second turbine is configured and arranged to expand hot gases from said second combustor; a coal gasification syngas generation unit having an outlet connected with the combustors configured and arranged to supply the combustors with syngas as fuel; wherein the coal gasification syngas generation unit outlet is directly fluidly connected to the first combuster, and wherein the coal gasification syngas generation unit comprises a CO2 separator which functions at pressures >40 bar.
Some embodiments of the present disclosure are directed to a method for operating a gas turbine that works together with a coal gasifier, which is characterized by an improved degree of efficiency, and which can, in addition, be realized to particularly good effect using available components, and to create a gas turbine for implementing the method.
In one aspect, a gas turbine with reheating, which comprises two combustors and two turbines, is used in a gas turbine unit that works with syngas from a coal gasifier, in which, in the first combustor, syngas is burned using the compressed =
4 air, and the resultant hot gases are expanded in the first turbine, and in which . syngas is burned in the second combustor, using the gases that come from the first turbine, and the resultant hot gases are expanded in the second turbine and the generation of the syngas is conducted in such a manner that the syngas that is produced can be led directly to the first combustor.
= In some embodiments of the method, the separation of the air is undertaken at pressures > 40 bar, or the gasification of the coal is undertaken at pressures > 40 bar, orgas that occurs in conjunction with the gasification of the coal is subjected to a filtration of the gas at pressures >
40 bar, or CO2 is removed from the gas that occurs in the gasification of the coal, and the withdrawal of the CO2 is undertaken at pressures > 40 bar.
In some embodiments of the gas turbine, =the syngas generation unit comprises an air separation unit and the air separation unit works at pressures > 40 bar, orthe syngas generation unit comprises a coal gasifier and the coal gasifier works at pressures > 40 bar, or the syngas generation unit comprises a filtration unit and the filtration unit works at = pressures > 40 bar, orthe syngas generation unit comprises a CO2 separator and=the CO2 separator works at pressures > 40 bar.
BRIEF EXPLANATION OF THE FIGURES
In what follows, the invention will be explained by virtue of embodiment examples in conjunction with the drawings.
Fig. 1 shows the simplified schematic of a combined cycle power plant with a gas turbine with reheating or sequential combustion in = accordance with the prior art; and Fig. 2 shows the simplified schematic of an IGCC unit with a gas turbine with reheating or sequential combustion, respectively, according to an embodiment example of the invention.
= In some embodiments of the method, the separation of the air is undertaken at pressures > 40 bar, or the gasification of the coal is undertaken at pressures > 40 bar, orgas that occurs in conjunction with the gasification of the coal is subjected to a filtration of the gas at pressures >
40 bar, or CO2 is removed from the gas that occurs in the gasification of the coal, and the withdrawal of the CO2 is undertaken at pressures > 40 bar.
In some embodiments of the gas turbine, =the syngas generation unit comprises an air separation unit and the air separation unit works at pressures > 40 bar, orthe syngas generation unit comprises a coal gasifier and the coal gasifier works at pressures > 40 bar, or the syngas generation unit comprises a filtration unit and the filtration unit works at = pressures > 40 bar, orthe syngas generation unit comprises a CO2 separator and=the CO2 separator works at pressures > 40 bar.
BRIEF EXPLANATION OF THE FIGURES
In what follows, the invention will be explained by virtue of embodiment examples in conjunction with the drawings.
Fig. 1 shows the simplified schematic of a combined cycle power plant with a gas turbine with reheating or sequential combustion in = accordance with the prior art; and Fig. 2 shows the simplified schematic of an IGCC unit with a gas turbine with reheating or sequential combustion, respectively, according to an embodiment example of the invention.
5 DESCRIPTION OF EMBODIMENTS
In a gas turbine with reheating, as represented by Type GT26, and in Fig. 1, air is removed at the compressor 13, 14 at intermediate pressures (11-20 bar) and at high pressures (> 30 bar).
The first combustor 18 [note: the list says high pressure combustor for 18]
requires syngas at a pressure that corresponds to the final pressure of the compressor 13, 14 plus a loss of pressure in the lines and in the combustor. In an IGCC plant of the customary type having a gas turbine with only one combustor, the pressure in the coal gasifier is about 30 bar. lf, instead of the gas turbine with only one combustor, a gas turbine with reheating were used, the syngas from the coal gasifier would have to be compressed from the final pressure of the coal gasifier (ca. 30 bar) to the pressure level of the first combustor, [that] of >45 bar, by means of one or more compressors.
lf, on the other hand, one were to increase the pressure in the coal gasifier for a gas turbine without reheating to 60 bar, for example, an expansion machine would have to be used to expand the syngas to the combustor's level of pressure.
The idea of some embodiments consists of operating the coal gasifying branch of the unit in an IGCC unit with a gas turbine with reheating, which commonly comprises an air separation unit, a coal gasifier, a gas filtering unit, and a separator, at a level of pressure that is adjusted to the level of pressure of the first combustor of the gas turbine and lies within the range of between 40 and 65 bar, thus clearly above the level of pressure in a gas turbine without reheating.
In this way, the use of an additional compressor for the compression of the syngas is avoided.
In a gas turbine with reheating, as represented by Type GT26, and in Fig. 1, air is removed at the compressor 13, 14 at intermediate pressures (11-20 bar) and at high pressures (> 30 bar).
The first combustor 18 [note: the list says high pressure combustor for 18]
requires syngas at a pressure that corresponds to the final pressure of the compressor 13, 14 plus a loss of pressure in the lines and in the combustor. In an IGCC plant of the customary type having a gas turbine with only one combustor, the pressure in the coal gasifier is about 30 bar. lf, instead of the gas turbine with only one combustor, a gas turbine with reheating were used, the syngas from the coal gasifier would have to be compressed from the final pressure of the coal gasifier (ca. 30 bar) to the pressure level of the first combustor, [that] of >45 bar, by means of one or more compressors.
lf, on the other hand, one were to increase the pressure in the coal gasifier for a gas turbine without reheating to 60 bar, for example, an expansion machine would have to be used to expand the syngas to the combustor's level of pressure.
The idea of some embodiments consists of operating the coal gasifying branch of the unit in an IGCC unit with a gas turbine with reheating, which commonly comprises an air separation unit, a coal gasifier, a gas filtering unit, and a separator, at a level of pressure that is adjusted to the level of pressure of the first combustor of the gas turbine and lies within the range of between 40 and 65 bar, thus clearly above the level of pressure in a gas turbine without reheating.
In this way, the use of an additional compressor for the compression of the syngas is avoided.
6 An IGCC unit with a gas turbine with reheating or sequential combustion according to one embodiment example of the invention is depicted in Fig. 2, in a markedly simplified schematic. Combined cycle power plant 30 comprises a gas turbine 11 with a low pressure compressor 13, a downstream high pressure compressor 14, a high pressure combustor 18 with a downstream high pressure turbine 16, and a reheat combustor 19 with a downstream low pressure turbine 17. The compressors 13, 14 and the turbines 16, 17, sit on a commonly shared shaft 15, which drives a generator 12. The combustors .18 and 19 [note: the list says high pressure combustor for 18 and reheat combustor for 191 are supplied, via a syngas feed line, 31 with syngas as a fuel, which is generated by gasifying coal (coal feeding 33) in a coal gasifier 34. The coal gasifier 34 is topped by a cooler 35 for the syngas, a filtering device 36, and a CO2 separator 37 with a CO2 outlet 38 to release the separated CO2.
Oxygen (02), which is recovered in air separation unit 32 and introduced via an oxygen line 32a, is used to gasify the coal in the coal gasifier 34. The air separation unit 32 receives compressed air from the compressor 13, 14. The nitrogen (N2), which also occurs in the course of the separation, is conducted via nitrogen line 32b, for example, to the low pressure combustor 19.
To cool the components of the combustors 18, 19, and turbines 16, 17 that have been exposed to hot gas, compressed air is drawn off at the outlets of both compressors 13 and 14, cooled off in a topped OTC cooler 23 or 24, and then led to the points to be cooled via corresponding cooling lines 25 and 26.
A heat recovery steam generator 27, which, together with a connected steam turbine 29, is a portion of a water-steam circuit, is connected at the outlet of the low pressure turbine 17. The flue gas that is emitted from the heat recovery steam generator 27 is released to the outside via a flue gas line 28.
Oxygen (02), which is recovered in air separation unit 32 and introduced via an oxygen line 32a, is used to gasify the coal in the coal gasifier 34. The air separation unit 32 receives compressed air from the compressor 13, 14. The nitrogen (N2), which also occurs in the course of the separation, is conducted via nitrogen line 32b, for example, to the low pressure combustor 19.
To cool the components of the combustors 18, 19, and turbines 16, 17 that have been exposed to hot gas, compressed air is drawn off at the outlets of both compressors 13 and 14, cooled off in a topped OTC cooler 23 or 24, and then led to the points to be cooled via corresponding cooling lines 25 and 26.
A heat recovery steam generator 27, which, together with a connected steam turbine 29, is a portion of a water-steam circuit, is connected at the outlet of the low pressure turbine 17. The flue gas that is emitted from the heat recovery steam generator 27 is released to the outside via a flue gas line 28.
7 Now, in such a configuration of the unit, the branch of the unit for generating the syngas, which comprises the air separation unit 32, the coal gasifier 34, the filtering unit 36, and the CO2 separator 37, is designed and operated in such a way that the resultant syngas can be led directly to the first combustor 18. To this end, either the air separator 32 or the coal gasifier 34, or the filtering unit 36 or the CO2 separator 37 can work at pressures > 40 bar. To bring the gases that flow through this branch of the unit to the requisite level of pressure, an additional compressor 39 can be provided at a suitable point.
8 List of Reference Signs 10,30,40 combined cycle power plant 11 gas turbine 12 generator 13 low pressure compressor 14 high pressure compressor 15 shaft (gas turbine) 16 high pressure turbine 17 low pressure turbine 18 high pressure combustor 19 reheat combustor 20 air inlet 21,22 fuel feedline 23,24 OTC cooler 25,26 cooling line 27 heat recovery steam generator 28 flue gas line 29 steam turbine (steam cycle) 31 syngas feed line 32 air separation unit 32a oxygen line 32b nitrogen line 33 coal feeding 34 coal gasifier 35 cooling device 36 filtering device 37 CO2 separator 38 CO2 outlet 39 compressor
Claims (12)
1. A method for operating a gas turbine, the method comprising:
drawing in air through and compressing air in the gas turbine;
conducting compressed air to a combustor;
combusting a syngas that is recovered from coal with said compressed air in said combustor, to produce hot gases;
expanding the hot gases from said combustor in a downstream turbine as said hot gases perform work;
separating a portion of said compressed air into oxygen and nitrogen;
generating syngas in a coal gasifier using the oxygen from said separating;
conducting a portion of said compressed air to and cooling portions of the gas turbine that are exposed to hot air with said compressed air;
wherein said gas turbine comprises a reheating gas turbine which comprises two combustors and two turbines;
wherein combusting a syngas comprises combusting syngas in the first combustor with the compressed air at pressures within the range of 40-65 bar;
wherein expanding the hot gases from said combustor comprises expanding in the first turbine;
combusting syngas in the second combustor using gases coming from the first turbine, to generate hot gases;
expanding the hot gases from said second combustor in the second turbine; and wherein generating syngas comprises generating syngas suitable to be led directly to the first combustor.
drawing in air through and compressing air in the gas turbine;
conducting compressed air to a combustor;
combusting a syngas that is recovered from coal with said compressed air in said combustor, to produce hot gases;
expanding the hot gases from said combustor in a downstream turbine as said hot gases perform work;
separating a portion of said compressed air into oxygen and nitrogen;
generating syngas in a coal gasifier using the oxygen from said separating;
conducting a portion of said compressed air to and cooling portions of the gas turbine that are exposed to hot air with said compressed air;
wherein said gas turbine comprises a reheating gas turbine which comprises two combustors and two turbines;
wherein combusting a syngas comprises combusting syngas in the first combustor with the compressed air at pressures within the range of 40-65 bar;
wherein expanding the hot gases from said combustor comprises expanding in the first turbine;
combusting syngas in the second combustor using gases coming from the first turbine, to generate hot gases;
expanding the hot gases from said second combustor in the second turbine; and wherein generating syngas comprises generating syngas suitable to be led directly to the first combustor.
2. A method according to claim 1, wherein separating a portion of said compressed air comprises separating at pressures > 40 bar.
3. A method according to claim 1, wherein generating syngas with coal comprises generating syngas at pressures > 40 bar.
4. A method according to claim 1, wherein generating syngas comprises gasifying coal to produce gas and filtering said gas at pressures > 40 bar.
5. A method according to claim 1, wherein generating syngas comprises gasifying coal to produce gas and CO2, and withdrawing CO2 is at pressures >
bar.
bar.
6. A method according to claim 1, wherein the gas turbine is part of a combined cycle power plant.
7. A reheating gas turbine comprising:
compressors for the compression of air that has been drawn in;
a first turbine and a second turbine;
a first combustor and a second combustor, said first combustor in fluid communication with at least one of said compressors and with said first turbine, said second combustor in fluid communication with said first turbine and said second turbine;
wherein the first combustor is configured and arranged to combust a fuel with compressed air from said at least one of said compressors at pressures within a range of 40-65 bar, to generate hot gases;
wherein said first turbine is configured and arranged to expand hot gases from said first combustor;
wherein the second combustor is configured and arranged to combust a fuel with gases from the first turbine, to generate hot gases;
wherein the second turbine is configured and arranged to expand hot gases from said second combustor;
a coal gasification syngas generation unit comprising an air separation unit, which receives compressed air from the compressors and having an outlet connected with the combustors configured and arranged to supply the combustors with syngas as fuel; and wherein the coal gasification syngas generation unit outlet is directly fluidly connected to the first combustor.
compressors for the compression of air that has been drawn in;
a first turbine and a second turbine;
a first combustor and a second combustor, said first combustor in fluid communication with at least one of said compressors and with said first turbine, said second combustor in fluid communication with said first turbine and said second turbine;
wherein the first combustor is configured and arranged to combust a fuel with compressed air from said at least one of said compressors at pressures within a range of 40-65 bar, to generate hot gases;
wherein said first turbine is configured and arranged to expand hot gases from said first combustor;
wherein the second combustor is configured and arranged to combust a fuel with gases from the first turbine, to generate hot gases;
wherein the second turbine is configured and arranged to expand hot gases from said second combustor;
a coal gasification syngas generation unit comprising an air separation unit, which receives compressed air from the compressors and having an outlet connected with the combustors configured and arranged to supply the combustors with syngas as fuel; and wherein the coal gasification syngas generation unit outlet is directly fluidly connected to the first combustor.
8. A gas turbine according to claim 7, wherein the coal gasification syngas generation unit comprises an air separation unit which functions at pressures >40 bar.
9. A gas turbine according to claim 7, wherein the coal gasification syngas generation unit comprises a coal gasifier which functions at pressures > 40 bar.
10. A gas turbine according to claim 7, wherein the coal gasification syngas generation unit comprises a filtering unit which functions at pressures > 40 bar.
11. A gas turbine according to claim 7, further comprising:
an additional compressor between the compressors of the gas turbine and the outlet of the coal gasification syngas generation unit.
an additional compressor between the compressors of the gas turbine and the outlet of the coal gasification syngas generation unit.
12. A reheating gas turbine comprising:
compressors for the compression of air that has been drawn in;
a first turbine and second turbine;
a first combustor and a second combustor, said first combustor in fluid communication with at least one of said compressors and with said first turbine, said second combustor in fluid communication with said first turbine and said second turbine;
wherein the first combustor is configured and arranged to combust a fuel with compressed air from said at least one of said compressors at pressures within a range of 40-65 bar, to generate hot gases;
wherein said first turbine is configured and arranged to expand hot gases from said first combustor;
wherein the second combustor is configured and arranged to combust a fuel with gases from the first turbine, to generate hot gases;
wherein the second turbine is configured and arranged to expand hot gases from said second combustor;
a coal gasification syngas generation unit having an outlet connected with the combustors configured and arranged to supply the combustors with syngas as fuel;
wherein the coal gasification syngas generation unit outlet is directly fluidly connected to the first combuster, and wherein the coal gasification syngas generation unit comprises a CO2 separator which functions at pressures > 40 bar.
compressors for the compression of air that has been drawn in;
a first turbine and second turbine;
a first combustor and a second combustor, said first combustor in fluid communication with at least one of said compressors and with said first turbine, said second combustor in fluid communication with said first turbine and said second turbine;
wherein the first combustor is configured and arranged to combust a fuel with compressed air from said at least one of said compressors at pressures within a range of 40-65 bar, to generate hot gases;
wherein said first turbine is configured and arranged to expand hot gases from said first combustor;
wherein the second combustor is configured and arranged to combust a fuel with gases from the first turbine, to generate hot gases;
wherein the second turbine is configured and arranged to expand hot gases from said second combustor;
a coal gasification syngas generation unit having an outlet connected with the combustors configured and arranged to supply the combustors with syngas as fuel;
wherein the coal gasification syngas generation unit outlet is directly fluidly connected to the first combuster, and wherein the coal gasification syngas generation unit comprises a CO2 separator which functions at pressures > 40 bar.
Applications Claiming Priority (5)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US70677505P | 2005-08-10 | 2005-08-10 | |
| US60/706,775 | 2005-08-10 | ||
| CH2023/05 | 2005-12-20 | ||
| CH20232005 | 2005-12-20 | ||
| PCT/EP2006/065110 WO2007017490A1 (en) | 2005-08-10 | 2006-08-07 | Method for operating a gas turbine, and gas turbine for carrying out the method |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2618030A1 CA2618030A1 (en) | 2007-02-15 |
| CA2618030C true CA2618030C (en) | 2014-07-08 |
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| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2618030A Expired - Fee Related CA2618030C (en) | 2005-08-10 | 2006-08-07 | A method for operating a gas turbine and a gas turbine for implementing the method |
Country Status (5)
| Country | Link |
|---|---|
| JP (1) | JP2009504967A (en) |
| CN (1) | CN101238341B (en) |
| CA (1) | CA2618030C (en) |
| DE (1) | DE112006002028B4 (en) |
| WO (1) | WO2007017490A1 (en) |
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| EP2290202A1 (en) | 2009-07-13 | 2011-03-02 | Siemens Aktiengesellschaft | Cogeneration plant and cogeneration method |
| CN102337936A (en) * | 2011-09-13 | 2012-02-01 | 华北电力大学 | Flue gas reheating combined cycle power system |
| CN102305109B (en) * | 2011-09-13 | 2014-03-26 | 华北电力大学 | Oxygen enrichment-coal gasification flue gas reheating combined cycle power system |
| CN102337937B (en) * | 2011-09-13 | 2014-08-20 | 华北电力大学 | Coal integrally-gasified smoke reheating combined-cycle power system |
| CN104314704B (en) * | 2013-09-22 | 2016-04-27 | 摩尔动力(北京)技术股份有限公司 | Velocity profile heat engine |
| CN109854382A (en) * | 2019-03-13 | 2019-06-07 | 上海发电设备成套设计研究院有限责任公司 | Zero carbon emission heat power generating system of one kind and method |
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| NL63476C (en) * | ||||
| DE947843C (en) * | 1954-09-11 | 1956-08-23 | Henschel & Sohn G M B H | Method for using the lock gas produced by pressurized gasifiers in gas turbine operation |
| US4896499A (en) * | 1978-10-26 | 1990-01-30 | Rice Ivan G | Compression intercooled gas turbine combined cycle |
| US4785622A (en) * | 1984-12-03 | 1988-11-22 | General Electric Company | Integrated coal gasification plant and combined cycle system with air bleed and steam injection |
| US4785621A (en) * | 1987-05-28 | 1988-11-22 | General Electric Company | Air bottoming cycle for coal gasification plant |
| DE4118062A1 (en) | 1991-06-01 | 1992-12-03 | Asea Brown Boveri | COMBINED GAS / VAPOR POWER PLANT |
| CH687269A5 (en) * | 1993-04-08 | 1996-10-31 | Abb Management Ag | Gas turbine group. |
| US5388395A (en) * | 1993-04-27 | 1995-02-14 | Air Products And Chemicals, Inc. | Use of nitrogen from an air separation unit as gas turbine air compressor feed refrigerant to improve power output |
| US5406786A (en) * | 1993-07-16 | 1995-04-18 | Air Products And Chemicals, Inc. | Integrated air separation - gas turbine electrical generation process |
| US5740673A (en) * | 1995-11-07 | 1998-04-21 | Air Products And Chemicals, Inc. | Operation of integrated gasification combined cycle power generation systems at part load |
| GB2335953A (en) * | 1998-03-30 | 1999-10-06 | Magnox Electric Plc | Air extraction from a power generation turbine |
| DE19832294C1 (en) | 1998-07-17 | 1999-12-30 | Siemens Ag | Gas-and-steam turbine installation with integrated fossil fuel gasification |
| US6148602A (en) | 1998-08-12 | 2000-11-21 | Norther Research & Engineering Corporation | Solid-fueled power generation system with carbon dioxide sequestration and method therefor |
| US6314715B1 (en) * | 1999-06-03 | 2001-11-13 | General Electric Co. | Modified fuel gas turbo-expander for oxygen blown gasifiers and related method |
| DE10002084C2 (en) | 2000-01-19 | 2001-11-08 | Siemens Ag | Gas and steam turbine plant |
| US6513317B2 (en) | 2001-01-11 | 2003-02-04 | General Electric Company | Apparatus for controlling nitrogen injection into gas turbine |
| CN100504053C (en) * | 2003-01-27 | 2009-06-24 | 中国科学院工程热物理研究所 | Inside and outside burning coal integrative combined cycle generation system and method |
-
2006
- 2006-08-07 CN CN2006800289706A patent/CN101238341B/en active Active
- 2006-08-07 JP JP2008525566A patent/JP2009504967A/en not_active Withdrawn
- 2006-08-07 CA CA2618030A patent/CA2618030C/en not_active Expired - Fee Related
- 2006-08-07 DE DE112006002028.5T patent/DE112006002028B4/en not_active Expired - Fee Related
- 2006-08-07 WO PCT/EP2006/065110 patent/WO2007017490A1/en active Application Filing
Also Published As
| Publication number | Publication date |
|---|---|
| JP2009504967A (en) | 2009-02-05 |
| CA2618030A1 (en) | 2007-02-15 |
| WO2007017490A1 (en) | 2007-02-15 |
| DE112006002028A5 (en) | 2008-06-19 |
| CN101238341A (en) | 2008-08-06 |
| CN101238341B (en) | 2012-04-18 |
| DE112006002028B4 (en) | 2022-01-13 |
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