WO2013144006A2 - Combined cycle power plant and method for operating such a combined cycle power plant - Google Patents

Combined cycle power plant and method for operating such a combined cycle power plant Download PDF

Info

Publication number
WO2013144006A2
WO2013144006A2 PCT/EP2013/056055 EP2013056055W WO2013144006A2 WO 2013144006 A2 WO2013144006 A2 WO 2013144006A2 EP 2013056055 W EP2013056055 W EP 2013056055W WO 2013144006 A2 WO2013144006 A2 WO 2013144006A2
Authority
WO
WIPO (PCT)
Prior art keywords
steam
power
turbine
supplementary firing
combined cycle
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.)
Ceased
Application number
PCT/EP2013/056055
Other languages
French (fr)
Other versions
WO2013144006A3 (en
Inventor
Hongtao Li
Tjiptady Nugroho
Christoph Ruchti
Camille Pedretti
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
GE Vernova GmbH
Original Assignee
Alstom Technology AG
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Alstom Technology AG filed Critical Alstom Technology AG
Priority to IN7991DEN2014 priority Critical patent/IN2014DN07991A/en
Priority to CN201380017171.9A priority patent/CN104981587B/en
Priority to RU2014143268A priority patent/RU2014143268A/en
Priority to CA2867244A priority patent/CA2867244A1/en
Priority to JP2015502234A priority patent/JP2015514179A/en
Priority to EP13714237.8A priority patent/EP2831385B1/en
Publication of WO2013144006A2 publication Critical patent/WO2013144006A2/en
Priority to US14/494,860 priority patent/US20150007577A1/en
Anticipated expiration legal-status Critical
Publication of WO2013144006A3 publication Critical patent/WO2013144006A3/en
Ceased legal-status Critical Current

Links

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
    • F01K23/08—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 working fluid of one cycle heating the fluid in another cycle
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01D—NON-POSITIVE DISPLACEMENT MACHINES OR ENGINES, e.g. STEAM TURBINES
    • F01D19/00—Starting of machines or engines; Regulating, controlling, or safety means in connection therewith
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01D—NON-POSITIVE DISPLACEMENT MACHINES OR ENGINES, e.g. STEAM TURBINES
    • F01D25/00—Component parts, details, or accessories, not provided for in, or of interest apart from, other groups
    • F01D25/08—Cooling; Heating; Heat-insulation
    • F01D25/10—Heating, e.g. warming-up before starting
    • 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
    • F01K13/00—General layout or general methods of operation of complete plants
    • F01K13/02—Controlling, e.g. stopping or starting
    • 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
    • F01K23/04—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 condensation heat from one cycle heating the fluid in another cycle
    • 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
    • F01K23/103—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 with afterburner in exhaust boiler
    • F01K23/105—Regulating means specially adapted therefor
    • 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
    • F02C3/30—Adding water, steam or other fluids for influencing combustion, e.g. to obtain cleaner exhaust gases
    • F02C3/305—Increasing the power, speed, torque or efficiency of a gas turbine or the thrust of a turbojet engine by injecting or adding water, steam or other fluids
    • 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
    • F02C7/00—Features, components parts, details or accessories, not provided for in, or of interest apart form groups F02C1/00 - F02C6/00; Air intakes for jet-propulsion plants
    • F02C7/12—Cooling of plants
    • 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
    • F02C7/00—Features, components parts, details or accessories, not provided for in, or of interest apart form groups F02C1/00 - F02C6/00; Air intakes for jet-propulsion plants
    • F02C7/12—Cooling of plants
    • F02C7/14—Cooling of plants of fluids in the plant, e.g. lubricant or fuel
    • F02C7/141—Cooling of plants of fluids in the plant, e.g. lubricant or fuel of working fluid
    • 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
    • F02C7/00—Features, components parts, details or accessories, not provided for in, or of interest apart form groups F02C1/00 - F02C6/00; Air intakes for jet-propulsion plants
    • F02C7/12—Cooling of plants
    • F02C7/16—Cooling of plants characterised by cooling medium
    • F02C7/18—Cooling of plants characterised by cooling medium the medium being gaseous, e.g. air
    • F02C7/185—Cooling means for reducing the temperature of the cooling air or gas
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22B—METHODS OF STEAM GENERATION; STEAM BOILERS
    • F22B1/00—Methods of steam generation characterised by form of heating method
    • F22B1/02—Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers
    • F22B1/18—Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers the heat carrier being a hot gas, e.g. waste gas such as exhaust gas of internal-combustion engines
    • F22B1/1807—Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers the heat carrier being a hot gas, e.g. waste gas such as exhaust gas of internal-combustion engines using the exhaust gases of combustion engines
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22B—METHODS OF STEAM GENERATION; STEAM BOILERS
    • F22B1/00—Methods of steam generation characterised by form of heating method
    • F22B1/02—Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers
    • F22B1/18—Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers the heat carrier being a hot gas, e.g. waste gas such as exhaust gas of internal-combustion engines
    • F22B1/1807—Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers the heat carrier being a hot gas, e.g. waste gas such as exhaust gas of internal-combustion engines using the exhaust gases of combustion engines
    • F22B1/1815—Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers the heat carrier being a hot gas, e.g. waste gas such as exhaust gas of internal-combustion engines using the exhaust gases of combustion engines using the exhaust gases of gas-turbines
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22B—METHODS OF STEAM GENERATION; STEAM BOILERS
    • F22B1/00—Methods of steam generation characterised by form of heating method
    • F22B1/02—Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers
    • F22B1/18—Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers the heat carrier being a hot gas, e.g. waste gas such as exhaust gas of internal-combustion engines
    • F22B1/1861—Waste heat boilers with supplementary firing
    • 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
    • Y02E20/14—Combined heat and power generation [CHP]
    • 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
    • Y02E20/30—Technologies for a more efficient combustion or heat usage

Definitions

  • the present invention relates to thermal power plants. It refers to a combined cycle power plant according to the preamble of claim 1 . It further refers to a method for operating such a combine cycle power plant.
  • CCPPs combined cycle power plants
  • the requested live steam pressure design margin may result in a substantial drop of live steam pressure at base load and correspondingly to a plant performance drop (can be up to 0.5%).
  • Document US 5,495,709 A discloses an air reservoir turbine installation having a gas turbine group connected to a compressed air reservoir, and comprising a hot water reservoir, a waste heat steam generator connected to receive an exhaust gas flow downstream of the gas turbine, the gas turbine group comprising a compressor unit, at least one combustion chamber and at least one turbine, wherein the waste heat steam generator is connected to introduce steam into the gas turbine group for increasing an output of the at least one turbine, and further comprising at least one heat exchanger to cool working air compressed by the compressor unit and a partial pressure evaporator to introduce water vapor into the working air, the at least one heat exchanger being connected to deliver heated water to the partial pressure evaporator.
  • Document US 4,509,324 A discloses a shipboard engine system and method of operating includes two compressors with an intercooler, a compressor turbine, a power turbine, a combustor for combining fuel, air and water.
  • Heat exchangers remove heat from the exhaust and use it to preheat the water to the combustor.
  • Spray condensers recover water from the exhaust for reuse.
  • Water purification apparatus is used to remove acid from the water.
  • the system is designed for stoichiometric operation at full load and run with increased efficiency at part load to give a total lower fuel consumption.
  • Document US 2006/248896 A1 discloses a method of operating a gas turbine power plant comprising of a first gas turbine group, consisting of a compressor and a turbine which are connected mechanically with one another, and a second gas turbine group, including a combustion device, which is placed in the gas flow stream between the first group's compressor and turbine, whereby the second gas turbine group consists of a compressor, a fuel injection device, a combustion chamber and a turbine, whereby the second gas turbine group's compressor and turbine are mechanically coupled to one another and at least one of the gas turbine groups having a device for the extraction of work, whereby the fact that a first flow of water and/or steam is heated with heat from the flue gas from the first group's turbine; that further amounts of water and/or steam are heated with heat from a gas stream that is compressed by the first group's compressor, and the produced water and/or steam is injected into the gas stream in such amounts that at least 60% of the oxygen content of the air in the stream is consumed through combustion in the combustion device, and in
  • a combined cycle power plant comprises a gas turbine the exhaust gas outlet of which is connected to a heat recovery steam generator, which is part of a water/steam cycle, whereby, for having a large power reserve and at the same time a higher design performance when operated at base load, the gas turbine is designed with a steam injection capability for power
  • the gas turbine comprises at least one combustor, and a compressor that provides cooling air for cooling said gas turbine, which is extracted from the compressor and cooled down in at least one cooling air cooler, and the steam for steam injection is generated in said cooling air cooler, whereby said steam can be injected into an air side inlet or outlet of said cooling air cooler and/or directly into said at least one combustor.
  • the heat recovery steam generator is equipped with a supplementary firing.
  • the supplementary firing is at least a single stage supplementary firing to increase the high-pressure steam production and providing augmentation power as power reserve to a grid when required.
  • the at least one cooling air cooler is a once-through cooler (OTC).
  • the steam for steam injection is taken from said heat recovery steam generator.
  • the supplementary firing is a two stage supplementary firing with a first stage for increasing the high pressure live steam production and providing augmentation power as power reserve to a grid, and a second stage arranged after a high pressure evaporator within the heat recovery steam generator for increasing intermediate pressure live steam production and providing additional power as power reserve to the grid when required.
  • a high-pressure steam turbine module is connected to the steam turbine by means of an automatic clutch.
  • a first method for operating a combined cycle power plant according to the invention is characterized in that in case of the need for power reserve the plant power is in a first step increased by means of steam injection into the gas turbine, and in the second step, the power of the steam turbine is augmented by means of increasing the load of the supplementary firing.
  • the method comprises the following steps:
  • the separated steam turbine module is warmed up by bleed steam from the main steam turbine or from the heat recovery steam generator, to keep the steam turbine warm;
  • a. plant power is firstly increased with steam injection
  • steam turbine power is augmented with a supplementary firing load increase
  • the high-pressure steam turbine module is started; and d) before the steam turbine live steam operating pressure reaches a predetermined limit during supplementary firing loading, the high-pressure steam turbine module is ready for synchronization and connected by operating the automatic clutch.
  • the method comprises the following steps:
  • a. plant power is firstly increased with steam injection
  • steam turbine power is augmented with a supplementary firing load increase
  • the high-pressure steam turbine module is ready for synchronization and connected by operating the automatic clutch.
  • Fig. 1 shows a simplified diagram of a combined cycle power plant
  • FIG. 1 shows a simplified diagram of a combined cycle power plant according to a first embodiment of the invention with supplementary firing in the HRSG and steam injection by means of OTCs into the gas turbine; shows a simplified diagram of a combined cycle power plant according to a second embodiment of the invention with supplementary firing in the HRSG and steam injection from the HRSG directly into the combustor of the gas turbine; shows a simplified diagram of a combined cycle power plant according to a third embodiment of the invention with supplementary firing in the HRSG and steam injection by means of OTCs and from the HRSG into the gas turbine; and shows a simplified diagram of a combined cycle power plant according to a fourth embodiment of the invention similar to Fig. 1 and 3, with an additional high pressure steam turbine module being connected by means of an automatic clutch.
  • the invention is essentially to combine in a CCPP gas turbine steam injection and HRSG single or two-stage supplementary firing to improve the plant's performance when the supplementary firing SF is off, and to increase the capability of power reserve when needed.
  • Using directly steam generated from once through cooler (OTC) for steam injection has benefits in form of a design simplification compared to steam extraction from HRSG.
  • a combined cycle power plant (CCPP) 10a has a gas turbine 1 1 a with a compressor 12, two combustors 15 and 16, and two turbines 13 and 14, designed with steam injection for power augmentation through steam line 26 using steam generated from cooling air coolers such as once-through coolers 17 and 18.
  • the steam can be injected into an air side inlet our air side outlet of said air cooler 17 and/or directly into the combustor 15 (see Fig.1 ).
  • Such a steam injection to the hot air side of the cooling air cooler for gas turbine power augmentation is a preferred embodiment.
  • the gas turbine 1 1 a is cooled with cooling air from the compressor 12 through cooling air lines 23a and 23b.
  • a heat recovery steam generator (HRSG) 19 which is part of a water/steam cycle 35 comprising a steam turbine 20 and a condenser 21 as well as a high pressure live steam line 33 and a feed water line 34, is designed with a single stage supplementary firing 22 to increase the high pressure steam production and providing augmentation power as power reserve to a grid when required.
  • HRSG heat recovery steam generator
  • a HRSG design with two stage supplementary firing 22 and 22' may be used: one firing stage 22 for increasing the high pressure live steam production and providing augmentation power as power reserve to the grid when required, and another inter-stage supplementary firing 22' after the high pressure evaporator within the HRSG for increasing the intermediate pressure live steam production and providing additional augmentation power as power reserve to the grid when required.
  • Augmentation air or oxygen for the 2nd SF 22' may be required to allow sufficient 02 over the section area of the 2nd SF.
  • One of the possibilities is to preheat augmentation air with feed water, exhaust gas, cogeneration return water, CCS return condensate, or other sources to improve the efficiency.
  • a CCPP 10b has a gas turbine 1 1 b designed with steam injection at the combustor 15 for power augmentation using steam from the heat recovery steam generator (HRSG) 19.
  • HRSG heat recovery steam generator
  • a HRSG design with single stage supplementary firing 22 may be used to increase the high-pressure steam production and provide augmentation power as power reserve to the grid when required.
  • a HRSG design with two stage supplementary firing 22 and 22' may be used as an alternative: one (22) for increasing the high pressure live steam production and providing augmentation power as power reserve to the grid when required, and another 2nd supplementary firing (22') after high pressure
  • Augmentation air can be preheated with feed water, exhaust gas, cogeneration return water, CCS return condensate, or other sources to improve the efficiency.
  • a CCPP 10c is similar to Fig. 1 .
  • the steam for power augmentation can be injected into the Cooling Air Cooler's (17, 18) air side outlet or inlet, or directly into the combustor 15.
  • steam can be used from heat recovery steam generator (HRSG) 19 through steam line 28.
  • HRSG heat recovery steam generator
  • a CCPP 10d similar to Fig. 1 and 3 further comprises a (second) high pressure steam turbine module 30 connected to the (first) steam turbine 20 by means of an automatic clutch 31 (such as a SSS clutch) and a steam line 32.
  • an automatic clutch 31 such as a SSS clutch
  • further operation step includes:
  • the separated steam turbine module is warmed up by bleed steam from the main steam turbine or from HRSG, to keep the steam turbine warm to be able to fast startup.

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)
  • Sustainable Energy (AREA)
  • Physics & Mathematics (AREA)
  • Thermal Sciences (AREA)
  • Engine Equipment That Uses Special Cycles (AREA)

Description

DESCRIPTION
COMBINED CYCLE POWER PLANT AND METHOD FOR OPERATING SUCH A COMBINED CYCLE POWER PLANT
BACKGROUND OF THE INVENTION The present invention relates to thermal power plants. It refers to a combined cycle power plant according to the preamble of claim 1 . It further refers to a method for operating such a combine cycle power plant.
PRIOR ART
Grids in some regions need rather large power reserve from combined cycle power plants (CCPPs) at a level of up to 10% of the plant's net power output, or even higher.
In the prior art, this large amount of power reserve is normally achieved by designing the CCPP with large supplementary firing (SF) within the heat recovery steam generator HRSG of the plant (for the general idea of supplementary firing in CCPPs see for example documents US 3,879,616 or WO 2010/072729 A2). The supplementary firing will lead to the following two consequences:
1 ) Because a pressure margin has to be preserved for supplementary firing, the base load and part load steam turbine live steam pressure with SF being off will be lower than the allowed operating pressure. The larger the SF, the lower the live steam pressure and plant performance when SF is off.
As an example, for a triple pressure reheat CCPP with about 500MW power output, considering 10% net power output to be provided by supplementary firing as power reserve, the requested live steam pressure design margin may result in a substantial drop of live steam pressure at base load and correspondingly to a plant performance drop (can be up to 0.5%).
2) Due to steam turbine live steam pressure operating range and HRSG
supplementary firing design limit, solely relying on supplementary firing with reduced base load steam turbine live steam pressure may not be able to provide sufficient power reserve without a change in configuration of the steam turbine ST and the HRSG, e.g. switching from 3p (p= pressure) design to 2p or 1 p design. This will lead to a further plant performance drop when SF is off.
Document US 5,495,709 A discloses an air reservoir turbine installation having a gas turbine group connected to a compressed air reservoir, and comprising a hot water reservoir, a waste heat steam generator connected to receive an exhaust gas flow downstream of the gas turbine, the gas turbine group comprising a compressor unit, at least one combustion chamber and at least one turbine, wherein the waste heat steam generator is connected to introduce steam into the gas turbine group for increasing an output of the at least one turbine, and further comprising at least one heat exchanger to cool working air compressed by the compressor unit and a partial pressure evaporator to introduce water vapor into the working air, the at least one heat exchanger being connected to deliver heated water to the partial pressure evaporator. Document US 4,509,324 A discloses a shipboard engine system and method of operating includes two compressors with an intercooler, a compressor turbine, a power turbine, a combustor for combining fuel, air and water. Heat exchangers remove heat from the exhaust and use it to preheat the water to the combustor. Spray condensers recover water from the exhaust for reuse. Water purification apparatus is used to remove acid from the water. The system is designed for stoichiometric operation at full load and run with increased efficiency at part load to give a total lower fuel consumption.
Document US 2006/248896 A1 discloses a method of operating a gas turbine power plant comprising of a first gas turbine group, consisting of a compressor and a turbine which are connected mechanically with one another, and a second gas turbine group, including a combustion device, which is placed in the gas flow stream between the first group's compressor and turbine, whereby the second gas turbine group consists of a compressor, a fuel injection device, a combustion chamber and a turbine, whereby the second gas turbine group's compressor and turbine are mechanically coupled to one another and at least one of the gas turbine groups having a device for the extraction of work, whereby the fact that a first flow of water and/or steam is heated with heat from the flue gas from the first group's turbine; that further amounts of water and/or steam are heated with heat from a gas stream that is compressed by the first group's compressor, and the produced water and/or steam is injected into the gas stream in such amounts that at least 60% of the oxygen content of the air in the stream is consumed through combustion in the combustion device, and in that the combustion gas that is fed into the turbine of the second gas turbine group has a pressure in the range 50- 300 bar. SUMMARY OF THE INVENTION
It is an object of the present invention to have a combined cycle power plant, which provides a large power reserve at improved and optimized design performance when the plant is being operated at base load.
It is another object of the invention to provide a method for operating such a combined cycle power plant. These and other objects are obtained by a combined cycle power plant according to claim 1 and an operating method according to claim 6.
According to the invention, a combined cycle power plant comprises a gas turbine the exhaust gas outlet of which is connected to a heat recovery steam generator, which is part of a water/steam cycle, whereby, for having a large power reserve and at the same time a higher design performance when operated at base load, the gas turbine is designed with a steam injection capability for power
augmentation, whereby the gas turbine comprises at least one combustor, and a compressor that provides cooling air for cooling said gas turbine, which is extracted from the compressor and cooled down in at least one cooling air cooler, and the steam for steam injection is generated in said cooling air cooler, whereby said steam can be injected into an air side inlet or outlet of said cooling air cooler and/or directly into said at least one combustor. The heat recovery steam generator is equipped with a supplementary firing. The supplementary firing is at least a single stage supplementary firing to increase the high-pressure steam production and providing augmentation power as power reserve to a grid when required.
According to an embodiment of the invention the at least one cooling air cooler is a once-through cooler (OTC). According to another embodiment of the invention the steam for steam injection is taken from said heat recovery steam generator.
According to another embodiment of the invention the supplementary firing is a two stage supplementary firing with a first stage for increasing the high pressure live steam production and providing augmentation power as power reserve to a grid, and a second stage arranged after a high pressure evaporator within the heat recovery steam generator for increasing intermediate pressure live steam production and providing additional power as power reserve to the grid when required.
According to a further embodiment of the invention a high-pressure steam turbine module is connected to the steam turbine by means of an automatic clutch. A first method for operating a combined cycle power plant according to the invention is characterized in that in case of the need for power reserve the plant power is in a first step increased by means of steam injection into the gas turbine, and in the second step, the power of the steam turbine is augmented by means of increasing the load of the supplementary firing.
Especially, when a high-pressure steam turbine module is connected to the steam turbine by means of an automatic clutch, the method comprises the following steps:
a) to provide fast power augmentation, the separated steam turbine module is warmed up by bleed steam from the main steam turbine or from the heat recovery steam generator, to keep the steam turbine warm;
b) when power reserve is needed, steam is injected into the gas turbine and the supplementary firing is started, whereby
a. plant power is firstly increased with steam injection, and
b. then steam turbine power is augmented with a supplementary firing load increase;
c) the high-pressure steam turbine module is started; and d) before the steam turbine live steam operating pressure reaches a predetermined limit during supplementary firing loading, the high-pressure steam turbine module is ready for synchronization and connected by operating the automatic clutch.
Alternatively, the method comprises the following steps:
a) when a scheduled larger amount of power augmentation is needed, then, before power reserve is needed, the steam turbine is warmed up by steam admission to the high-pressure steam turbine module;
b) when power reserve is needed, steam is injected into the gas turbine and the supplementary firing is started, whereby
a. plant power is firstly increased with steam injection, and
b. then steam turbine power is augmented with a supplementary firing load increase;
c) the high-pressure steam turbine module is started; and
d) before the steam turbine live steam operating pressure reaches a
predetermined limit during supplementary firing loading, the high-pressure steam turbine module is ready for synchronization and connected by operating the automatic clutch.
BRIEF DESCRIPTION OF THE DRAWINGS
The present invention is now to be explained more closely by means of different embodiments and with reference to the attached drawings.
Fig. 1 shows a simplified diagram of a combined cycle power plant
according to a first embodiment of the invention with supplementary firing in the HRSG and steam injection by means of OTCs into the gas turbine; shows a simplified diagram of a combined cycle power plant according to a second embodiment of the invention with supplementary firing in the HRSG and steam injection from the HRSG directly into the combustor of the gas turbine; shows a simplified diagram of a combined cycle power plant according to a third embodiment of the invention with supplementary firing in the HRSG and steam injection by means of OTCs and from the HRSG into the gas turbine; and shows a simplified diagram of a combined cycle power plant according to a fourth embodiment of the invention similar to Fig. 1 and 3, with an additional high pressure steam turbine module being connected by means of an automatic clutch.
DETAILED DESCRIPTION OF DIFFERENT EMBODIMENTS OF THE INVENTION The invention is essentially to combine in a CCPP gas turbine steam injection and HRSG single or two-stage supplementary firing to improve the plant's performance when the supplementary firing SF is off, and to increase the capability of power reserve when needed. Using directly steam generated from once through cooler (OTC) for steam injection has benefits in form of a design simplification compared to steam extraction from HRSG.
A separated 2nd high-pressure steam turbine will further increase the plant's performance and power reserve capability. As shown in Fig. 1 , a combined cycle power plant (CCPP) 10a has a gas turbine 1 1 a with a compressor 12, two combustors 15 and 16, and two turbines 13 and 14, designed with steam injection for power augmentation through steam line 26 using steam generated from cooling air coolers such as once-through coolers 17 and 18. The steam can be injected into an air side inlet our air side outlet of said air cooler 17 and/or directly into the combustor 15 (see Fig.1 ).
A steam injection to the hot air side (= air side inlet) of the cooling air cooler has the benefit of avoiding water droplets, which have happened when injecting the steam to the cold air side (= air side outlet) of the cooling air cooler. Such a steam injection to the hot air side of the cooling air cooler for gas turbine power augmentation (not necessarily combined with supplementary firing) is a preferred embodiment. The gas turbine 1 1 a is cooled with cooling air from the compressor 12 through cooling air lines 23a and 23b. A heat recovery steam generator (HRSG) 19, which is part of a water/steam cycle 35 comprising a steam turbine 20 and a condenser 21 as well as a high pressure live steam line 33 and a feed water line 34, is designed with a single stage supplementary firing 22 to increase the high pressure steam production and providing augmentation power as power reserve to a grid when required.
Alternatively, a HRSG design with two stage supplementary firing 22 and 22' may be used: one firing stage 22 for increasing the high pressure live steam production and providing augmentation power as power reserve to the grid when required, and another inter-stage supplementary firing 22' after the high pressure evaporator within the HRSG for increasing the intermediate pressure live steam production and providing additional augmentation power as power reserve to the grid when required.
Augmentation air or oxygen for the 2nd SF 22' may be required to allow sufficient 02 over the section area of the 2nd SF. One of the possibilities is to preheat augmentation air with feed water, exhaust gas, cogeneration return water, CCS return condensate, or other sources to improve the efficiency.
As the steam from the cooling air coolers (OTCs 17 and 18) is partially or totally used for gas turbine steam injection at gas turbine 1 1 a, for a given percentage of power reserve, e.g. 10% of plant net base load power output, a higher live steam pressure when SF is off could be utilized and the plant performance will be improved. On the other hand, it allows a large power reserve if needed. When an even larger power reserve is required, and the live steam pressure, when SF is on, is reaching the limit, the two-stage SF design (22 and 22') can provide additional power reserve. Optimizing HP and IP steam pressure margin for a given power reserve percentage can on the other hand improve the plant's performance at base load without power augmentation.
As shown in Fig. 2, a CCPP 10b has a gas turbine 1 1 b designed with steam injection at the combustor 15 for power augmentation using steam from the heat recovery steam generator (HRSG) 19. Again, a HRSG design with single stage supplementary firing 22 may be used to increase the high-pressure steam production and provide augmentation power as power reserve to the grid when required.
Again, a HRSG design with two stage supplementary firing 22 and 22' may be used as an alternative: one (22) for increasing the high pressure live steam production and providing augmentation power as power reserve to the grid when required, and another 2nd supplementary firing (22') after high pressure
evaporator for increasing the intermediate pressure live steam production and providing additional augmentation power as power reserve to the grid when required. Again, augmentation air or oxygen for the 2nd may be required to allow sufficient 02 over the section area of the 2nd SF. Augmentation air can be preheated with feed water, exhaust gas, cogeneration return water, CCS return condensate, or other sources to improve the efficiency.
As shown in Fig. 3, a CCPP 10c according to another embodiment of the invention is similar to Fig. 1 . The steam for power augmentation can be injected into the Cooling Air Cooler's (17, 18) air side outlet or inlet, or directly into the combustor 15. In addition, steam can be used from heat recovery steam generator (HRSG) 19 through steam line 28. The HRSG design is the same as in Fig. 1 .
As shown in Fig. 4, a CCPP 10d similar to Fig. 1 and 3 further comprises a (second) high pressure steam turbine module 30 connected to the (first) steam turbine 20 by means of an automatic clutch 31 (such as a SSS clutch) and a steam line 32.
For each embodiment of Figs. 1 to 4 the method of operation is as follows:
• When power reserve is needed, the gas turbine steam injection and
supplementary firing SF will start;
• Plant power will firstly increase with steam injection;
• Then steam turbine power is augmented with supplementary firing load increase.
For a CCPP 10d according to Fig. 4 the operation steps are:
· When a large amount power augmentation is needed, then before power reserve is needed, the steam admission to the 2nd high pressure steam turbine 30 starts to warm up the steam turbine 20;
• When power reserve is needed, gas turbine steam injection and SF will start;
· Plant power will firstly increase with steam injection;
• Then steam turbine power is augmented with supplementary firing load increase; • The 2nd steam turbine high pressure module 30 will start;
• Before the steam turbine live steam operating pressure reaching the limit during supplementary firing loading, the 2nd steam turbine 30 shall be ready for synchronization and the SSS clutch 31 starts to engage.
For a CCPP 10d according to Fig. 4, further operation step includes:
• The separated steam turbine module is warmed up by bleed steam from the main steam turbine or from HRSG, to keep the steam turbine warm to be able to fast startup.
LIST OF REFERENCE NUMERALS
10a-d combined cycle power plant (CCPP)
1 1 a,b gas turbine
12 compressor
13,14 turbine
15,16 combustor
17,18 once through cooler (OTC)
19 heat recovery steam generator (HRSG)
20,30 steam turbine
21 condenser
22,22' supplementary firing (SF)
23a,b cooling air line
24 feed water line
25-28,32 steam line
30 high pressure steam turbine module
31 clutch (automatic)
33 high-pressure live steam line
34 feed water line
35 water/steam cycle

Claims

1 . Combined cycle power plant (1 Oa-d) comprising a gas turbine (1 1 a,b) the exhaust gas outlet of which is connected to a heat recovery steam generator (19), which is part of a water/steam cycle (35), whereby, for having a large power reserve and at the same time a higher design performance when operated at base load, the gas turbine (1 1 a,b) is designed with a steam injection capability (26, 27) for power augmentation, whereby the gas turbine (1 1 a) comprises at least one combustor (15, 16), and a compressor (12) for providing cooling air for said gas turbine (1 1 a,b), which is extracted from the compressor (12) and cooled down in at least one cooling air cooler (17, 18), and the steam for steam injection is
generated in said cooling air cooler (17, 18), whereby said steam is injected into an air side inlet or outlet of said cooling air cooler (17, 18) and/or directly into said at least one combustor (15, 16), and the heat recovery steam generator (19) is equipped with a supplementary firing (22, 22'), characterized in that the
supplementary firing is at least a single stage supplementary firing (22) to increase the high pressure steam production and providing augmentation power as power reserve to a grid when required.
2. Combined cycle power plant according to claim 1 , characterized in that the at least one cooling air cooler (17, 18) is a once-through cooler (OTC).
3. Combined cycle power plant according to claim 1 or 2, characterized that the steam for steam injection is taken from said heat recovery steam
generator (19).
4. Combined cycle power plant according to claim 1 , characterized in that the supplementary firing is a two stage supplementary firing (22, 22') with a first stage (22) for increasing the high pressure live steam production and providing augmentation power as power reserve to a grid, and a second stage (22') arranged after a high pressure evaporator within the heat recovery steam generator (19) for increasing intermediate pressure live steam production and providing additional power as power reserve to the grid when required.
5. Combined cycle power plant according to one of the claims 1 to 4, characterized in that an additional high-pressure steam turbine module (30) is connected to the steam turbine (20) by means of an automatic clutch (31 ).
6. Method for operating a combined cycle power plant according to one of the claims 1 to 5, characterized in that in case of the need for power reserve the plant power is in a first step increased by means of steam injection into the gas turbine (1 1 a,b), and in the second step, the power of the steam turbine (20) is augmented by means of increasing the load of the supplementary firing (22, 22').
7. Method according to claim 6 for operating a combined cycle power plant according to claim 5, comprising the following steps:
a) to provide fast power augmentation, the separated steam turbine module is warmed up by bleed steam from the main steam turbine or from the heat recovery steam generator (19), to keep the steam turbine warm;
b) when power reserve is needed, steam is injected into the gas turbine and the supplementary firing is started, whereby
a. plant power is firstly increased with steam injection, and
b. then steam turbine power is augmented with a supplementary firing load increase;
c) the additional high-pressure steam turbine module (30) is started; and d) before the steam turbine live steam operating pressure reaches a predetermined limit during supplementary firing loading, the high-pressure steam turbine module (30) is ready for synchronization and connected by operating the automatic clutch (31 ).
8. Method according to claim 7 for operating a combined cycle power plant according to claim 5, comprising the following steps: a) when a scheduled larger amount of power augmentation is needed, then, before power reserve is needed, the steam turbine is warmed up by steam admission to the additional high-pressure steam turbine module (30);
b) when power reserve is needed, steam is injected into the gas turbine (1 1 a) and the supplementary firing (22) is started, whereby
a. plant power is firstly increased with steam injection, and
b. then steam turbine power is augmented with a supplementary firing load increase;
c) the high-pressure steam turbine module (30) is started; and
d) before the steam turbine live steam operating pressure reaches a predetermined limit during supplementary firing loading, the additional high- pressure steam turbine module (30) is ready for synchronization and connected by operating the automatic clutch (31 ).
PCT/EP2013/056055 2012-03-28 2013-03-22 Combined cycle power plant and method for operating such a combined cycle power plant Ceased WO2013144006A2 (en)

Priority Applications (7)

Application Number Priority Date Filing Date Title
IN7991DEN2014 IN2014DN07991A (en) 2012-03-28 2013-03-22
CN201380017171.9A CN104981587B (en) 2012-03-28 2013-03-22 Combined cycle power plant and method for operating such a combined cycle power plant
RU2014143268A RU2014143268A (en) 2012-03-28 2013-03-22 POWER PLANT OF THE COMBINED CYCLE AND METHOD OF OPERATION OF SUCH POWER PLANT OF THE COMBINED CYCLE
CA2867244A CA2867244A1 (en) 2012-03-28 2013-03-22 Combined cycle power plant and method for operating such a combined cycle power plant
JP2015502234A JP2015514179A (en) 2012-03-28 2013-03-22 Combined cycle power plant and method for operating a combined cycle power plant
EP13714237.8A EP2831385B1 (en) 2012-03-28 2013-03-22 Combined cycle power plant and method for operating such a combined cycle power plant
US14/494,860 US20150007577A1 (en) 2012-03-28 2014-09-24 Combined cycle power plant and method for operating such a combined cycle power plant

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
EP12161898.7 2012-03-28
EP12161898 2012-03-28

Related Child Applications (1)

Application Number Title Priority Date Filing Date
US14/494,860 Continuation US20150007577A1 (en) 2012-03-28 2014-09-24 Combined cycle power plant and method for operating such a combined cycle power plant

Publications (2)

Publication Number Publication Date
WO2013144006A2 true WO2013144006A2 (en) 2013-10-03
WO2013144006A3 WO2013144006A3 (en) 2014-10-23

Family

ID=48047997

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/EP2013/056055 Ceased WO2013144006A2 (en) 2012-03-28 2013-03-22 Combined cycle power plant and method for operating such a combined cycle power plant

Country Status (8)

Country Link
US (1) US20150007577A1 (en)
EP (1) EP2831385B1 (en)
JP (1) JP2015514179A (en)
CN (1) CN104981587B (en)
CA (1) CA2867244A1 (en)
IN (1) IN2014DN07991A (en)
RU (1) RU2014143268A (en)
WO (1) WO2013144006A2 (en)

Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2896806A1 (en) * 2014-01-20 2015-07-22 Siemens Aktiengesellschaft Modification of the power yield of a gas turbine plant
EP2957733A1 (en) * 2014-06-18 2015-12-23 Alstom Technology Ltd Method for increasing the power of a combined-cycle power plant, and combined-cycle power plant for conducting said method
JP2017503947A (en) * 2013-11-26 2017-02-02 ボルボ トラック コーポレイション Auxiliary heating in waste heat recovery
DE112015001443B4 (en) 2014-03-24 2020-06-18 Mitsubishi Hitachi Power Systems, Ltd. Waste heat recovery system, equipped with this gas turbine system, waste heat recovery process and installation process for the waste heat recovery system
US11248536B2 (en) 2016-06-20 2022-02-15 General Electric Company Systems and methods for flame holding avoidance in gas turbine combustors

Families Citing this family (17)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
ES2535513T3 (en) * 2011-09-07 2015-05-12 Alstom Technology Ltd Method for operating a power plant
KR102149133B1 (en) * 2015-09-24 2020-08-28 미쓰비시주코마린마시나리 가부시키가이샤 Waste heat recovery equipment, internal combustion engine system, ship, and waste heat recovery method
WO2017078653A1 (en) 2015-11-02 2017-05-11 Lukashenko Gennadii Power plant
US11603794B2 (en) 2015-12-30 2023-03-14 Leonard Morgensen Andersen Method and apparatus for increasing useful energy/thrust of a gas turbine engine by one or more rotating fluid moving (agitator) pieces due to formation of a defined steam region
US10774741B2 (en) * 2016-01-26 2020-09-15 General Electric Company Hybrid propulsion system for a gas turbine engine including a fuel cell
KR101842370B1 (en) * 2016-12-05 2018-03-26 두산중공업 주식회사 System and Method for Fast Startup of a Combined Cycle Power Plant
US12291982B2 (en) 2020-11-30 2025-05-06 Rondo Energy, Inc. Thermal energy storage systems for use in material processing
WO2021176666A1 (en) * 2020-03-05 2021-09-10 株式会社エコ・サポート Autonomous and regional distributed power production/supply system
US11525375B2 (en) * 2020-04-09 2022-12-13 General Electric Company Modeling and control of gas cycle power plant operation with variant control profile
US11913361B2 (en) 2020-11-30 2024-02-27 Rondo Energy, Inc. Energy storage system and alumina calcination applications
ES3018461T3 (en) 2020-11-30 2025-05-16 Rondo Energy Inc Energy storage system and applications
US11913362B2 (en) 2020-11-30 2024-02-27 Rondo Energy, Inc. Thermal energy storage system coupled with steam cracking system
US12018596B2 (en) 2020-11-30 2024-06-25 Rondo Energy, Inc. Thermal energy storage system coupled with thermal power cycle systems
CN113914959B (en) * 2021-12-13 2022-02-15 华能（天津）煤气化发电有限公司 Modularized setting method for automatically switching unit operation modes
KR102737033B1 (en) 2022-11-24 2024-12-02 두산에너빌리티 주식회사 Combined power plant and operating method of the same
US12480719B2 (en) * 2024-04-24 2025-11-25 Rondo Energy, Inc. Thermal energy storage system for simple and combined cycle power generation
US12566034B1 (en) 2024-07-02 2026-03-03 Rondo Energy, Inc. Thermal energy storage system coupled to a heat exchanger with thermal protection

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3879616A (en) 1973-09-17 1975-04-22 Gen Electric Combined steam turbine and gas turbine power plant control system
US4509324A (en) 1983-05-09 1985-04-09 Urbach Herman B Direct open loop Rankine engine system and method of operating same
US5495709A (en) 1994-08-05 1996-03-05 Abb Management Ag Air reservoir turbine
US20060248896A1 (en) 2003-05-30 2006-11-09 Euroturine Ab Method for operation of a gas turbine group
WO2010072729A2 (en) 2008-12-24 2010-07-01 Alstom Technology Ltd Power plant with co2 capture

Family Cites Families (18)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4765142A (en) * 1987-05-12 1988-08-23 Gibbs & Hill, Inc. Compressed air energy storage turbomachinery cycle with compression heat recovery, storage, steam generation and utilization during power generation
US5054279A (en) * 1987-11-30 1991-10-08 General Electric Company Water spray ejector system for steam injected engine
AU659170B2 (en) * 1991-06-17 1995-05-11 Electric Power Research Institute, Inc. Power plant utilizing compressed air energy storage and saturation
JPH0688502A (en) * 1992-09-04 1994-03-29 Mitsubishi Heavy Ind Ltd Power generating plant
DE19541914A1 (en) * 1995-11-10 1997-05-15 Asea Brown Boveri Cooling air cooler for power plants
US6003298A (en) * 1997-10-22 1999-12-21 General Electric Company Steam driven variable speed booster compressor for gas turbine
DE59811106D1 (en) * 1998-02-25 2004-05-06 Alstom Technology Ltd Baden Power plant and method for operating a power plant with a CO2 process
CN2349361Y (en) * 1998-12-11 1999-11-17 陈伯禄 Gas-steam parallel-effect turbine engine
US6244033B1 (en) * 1999-03-19 2001-06-12 Roger Wylie Process for generating electric power
DE10041413B4 (en) * 1999-08-25 2011-05-05 Alstom (Switzerland) Ltd. Method for operating a power plant
DE10001112A1 (en) * 2000-01-13 2001-07-19 Alstom Power Schweiz Ag Baden Cooling air cooler for gas turbine unit, with water separator on cooling air side behind jet device in flow direction
CN1318737C (en) * 2000-05-31 2007-05-30 西门子公司 Method and device operating system turbine comprising sereral no-load or light-load phases
US6474069B1 (en) * 2000-10-18 2002-11-05 General Electric Company Gas turbine having combined cycle power augmentation
JP4457778B2 (en) * 2004-06-30 2010-04-28 株式会社日立製作所 High humidity gas turbine power plant
US7640724B2 (en) * 2006-01-25 2010-01-05 Siemens Energy, Inc. System and method for improving the heat rate of a turbine
JP5185677B2 (en) * 2008-03-31 2013-04-17 三菱重工業株式会社 Axial displacement detection method in driving force transmission mechanism using self-aligning engagement clutch
EP2199547A1 (en) * 2008-12-19 2010-06-23 Siemens Aktiengesellschaft Heat steam producer and method for improved operation of same
CN103409171A (en) * 2013-07-16 2013-11-27 南京师范大学 Biomass pressurized fluidized bed gasification gas turbine combined cycle power generation system

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3879616A (en) 1973-09-17 1975-04-22 Gen Electric Combined steam turbine and gas turbine power plant control system
US4509324A (en) 1983-05-09 1985-04-09 Urbach Herman B Direct open loop Rankine engine system and method of operating same
US5495709A (en) 1994-08-05 1996-03-05 Abb Management Ag Air reservoir turbine
US20060248896A1 (en) 2003-05-30 2006-11-09 Euroturine Ab Method for operation of a gas turbine group
WO2010072729A2 (en) 2008-12-24 2010-07-01 Alstom Technology Ltd Power plant with co2 capture

Cited By (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JP2017503947A (en) * 2013-11-26 2017-02-02 ボルボ トラック コーポレイション Auxiliary heating in waste heat recovery
EP2896806A1 (en) * 2014-01-20 2015-07-22 Siemens Aktiengesellschaft Modification of the power yield of a gas turbine plant
DE112015001443B4 (en) 2014-03-24 2020-06-18 Mitsubishi Hitachi Power Systems, Ltd. Waste heat recovery system, equipped with this gas turbine system, waste heat recovery process and installation process for the waste heat recovery system
US11519303B2 (en) 2014-03-24 2022-12-06 Mitsubishi Heavy Industries, Ltd. Waste heat recovery system, gas turbine plant provided with same, waste heat recovery method, and installation method for waste heat recovery system
EP2957733A1 (en) * 2014-06-18 2015-12-23 Alstom Technology Ltd Method for increasing the power of a combined-cycle power plant, and combined-cycle power plant for conducting said method
EP2957731A1 (en) * 2014-06-18 2015-12-23 Alstom Technology Ltd Method for increasing the power of a combined-cycle power plant, and combined-cycle power plant for conducting said method
CN105201575A (en) * 2014-06-18 2015-12-30 阿尔斯通技术有限公司 Method for increasing the power of a combined-cycle power plant, and combined-cycle power plant for conducting said method
US11248536B2 (en) 2016-06-20 2022-02-15 General Electric Company Systems and methods for flame holding avoidance in gas turbine combustors

Also Published As

Publication number Publication date
JP2015514179A (en) 2015-05-18
IN2014DN07991A (en) 2015-05-01
CA2867244A1 (en) 2013-10-03
RU2014143268A (en) 2016-05-20
WO2013144006A3 (en) 2014-10-23
CN104981587B (en) 2017-05-03
CN104981587A (en) 2015-10-14
EP2831385B1 (en) 2016-11-09
EP2831385A2 (en) 2015-02-04
US20150007577A1 (en) 2015-01-08

Similar Documents

Publication Publication Date Title
EP2831385B1 (en) Combined cycle power plant and method for operating such a combined cycle power plant
US11686250B2 (en) Gas turbine energy supplementing systems and heating systems, and methods of making and using the same
EP1905964B1 (en) Gas turbine engine
EP2482958B1 (en) Power plant for co2 capture
US20180058326A1 (en) Gas turbine efficiency and regulation speed improvements using supplementary air system continuous and storage systems and methods of using the same
EP2957733A1 (en) Method for increasing the power of a combined-cycle power plant, and combined-cycle power plant for conducting said method
EP2625405B1 (en) Combined cycle power plant with co2 capture and method to operate it
US20110247335A1 (en) Waste heat steam generator and method for improved operation of a waste heat steam generator
US8387356B2 (en) Method of increasing power output of a combined cycle power plant during select operating periods
US20100242429A1 (en) Split flow regenerative power cycle
EP2351915A1 (en) Combined cycle power plant and method of operating such power plant
US20150192038A1 (en) Combined cycle plant injection water preheating arrangement
US20120067057A1 (en) Intake air temperature control device and a method for operating an intake air temperature control device
US20100077722A1 (en) Peak load management by combined cycle power augmentation using peaking cycle exhaust heat recovery
US20150052906A1 (en) Duct Fired Combined Cycle System
CN102606237A (en) Open forward and inverse cycle coupling triple supply system of electricity, heat and cold based on combustion gas turbine
GB2445486A (en) Gas turbine engine exhaust plume suppression

Legal Events

Date Code Title Description
REEP Request for entry into the european phase

Ref document number: 2013714237

Country of ref document: EP

WWE Wipo information: entry into national phase

Ref document number: 2013714237

Country of ref document: EP

ENP Entry into the national phase

Ref document number: 2867244

Country of ref document: CA

ENP Entry into the national phase

Ref document number: 2015502234

Country of ref document: JP

Kind code of ref document: A

ENP Entry into the national phase

Ref document number: 2014143268

Country of ref document: RU

Kind code of ref document: A

121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 13714237

Country of ref document: EP

Kind code of ref document: A2