US20120055166A1 - Combined cycle power augmentation by efficient utilization of atomizing air energy - Google Patents
Combined cycle power augmentation by efficient utilization of atomizing air energy Download PDFInfo
- Publication number
- US20120055166A1 US20120055166A1 US12/877,427 US87742710A US2012055166A1 US 20120055166 A1 US20120055166 A1 US 20120055166A1 US 87742710 A US87742710 A US 87742710A US 2012055166 A1 US2012055166 A1 US 2012055166A1
- Authority
- US
- United States
- Prior art keywords
- steam generator
- combined cycle
- cycle power
- power plant
- heat exchanger
- 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.)
- Granted
Links
- 230000003416 augmentation Effects 0.000 title 1
- 230000001172 regenerating effect Effects 0.000 claims abstract description 43
- 239000012530 fluid Substances 0.000 claims abstract description 37
- 238000001816 cooling Methods 0.000 claims abstract description 21
- 238000000034 method Methods 0.000 claims abstract description 16
- 238000011144 upstream manufacturing Methods 0.000 claims description 11
- 239000002826 coolant Substances 0.000 claims description 10
- 239000000446 fuel Substances 0.000 claims description 9
- 238000004891 communication Methods 0.000 claims description 4
- 238000005086 pumping Methods 0.000 claims 2
- 239000007789 gas Substances 0.000 description 19
- 239000000567 combustion gas Substances 0.000 description 11
- 238000011084 recovery Methods 0.000 description 10
- 239000003085 diluting agent Substances 0.000 description 4
- 239000003570 air Substances 0.000 description 3
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 2
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 description 2
- 238000002485 combustion reaction Methods 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 230000005611 electricity Effects 0.000 description 2
- 239000003949 liquefied natural gas Substances 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 239000000203 mixture Substances 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 239000012080 ambient air Substances 0.000 description 1
- 239000000571 coke Substances 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000007865 diluting Methods 0.000 description 1
- 239000011261 inert gas Substances 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- 230000037361 pathway Effects 0.000 description 1
- 238000010248 power generation Methods 0.000 description 1
- 239000001294 propane Substances 0.000 description 1
- 238000012552 review Methods 0.000 description 1
- -1 steam Substances 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
Images
Classifications
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
- F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
- F01K23/00—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids
- F01K23/02—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled
- F01K23/06—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle
- F01K23/10—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
- F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
- 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
- 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
- F02C7/08—Heating air supply before combustion, e.g. by exhaust gases
- F02C7/10—Heating air supply before combustion, e.g. by exhaust gases by means of regenerative heat-exchangers
-
- 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
- F02C7/22—Fuel supply systems
- F02C7/236—Fuel delivery systems comprising two or more pumps
- F02C7/2365—Fuel delivery systems comprising two or more pumps comprising an air supply system for the atomisation of fuel
-
- 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
- Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
- Y02P80/00—Climate change mitigation technologies for sector-wide applications
- Y02P80/10—Efficient use of energy, e.g. using compressed air or pressurized fluid as energy carrier
- Y02P80/15—On-site combined power, heat or cool generation or distribution, e.g. combined heat and power [CHP] supply
Definitions
- the present invention generally involves a power plant that combines a conventional gas turbine with a heat recovery system to improve the overall efficiency of the combined cycle power plant.
- Specific embodiments of the present invention may include a regenerative heat exchanger that transfers heat from the gas turbine to the heat recovery system.
- Gas turbines are widely used in industrial and power generation operations.
- a typical gas turbine includes an axial compressor at the front, one or more combustors around the middle, and a turbine at the rear.
- Ambient air enters the compressor, and stationary vanes and rotating blades in the compressor progressively impart kinetic energy to the working fluid (air) to produce a compressed working fluid at a highly energized state.
- the compressed working fluid exits the compressor and flows through nozzles in the combustors where it mixes with fuel and ignites to generate combustion gases having a high temperature, pressure, and velocity.
- the combustion gases flow to the turbine where they expand to produce work. For example, expansion of the combustion gases in the turbine may rotate a shaft connected to a generator to produce electricity.
- the combination of the gas turbine and heat recovery system is commonly referred to as a combined cycle power plant.
- the heat recovery system typically includes a steam generator, a steam turbine, and a condenser.
- the exhaust combustion gases flow to the steam generator where they heat water to generate steam.
- the steam then flows through the steam generator where it expands to produce work. For example, expansion of the steam in the steam turbine may rotate a shaft connected to a generator to produce electricity.
- the shaft and generator may be the same shaft and generator connected to the gas turbine, or the gas turbine and heat recovery system may operate using separate shafts and generators.
- the condenser downstream of the steam generator condenses the steam to condensate, and condensate pumps direct the condensate back to the steam generator.
- the heat recovery system thus captures energy from the exhaust combustion gases before they are eventually released to the environment, thus increasing the overall efficiency of the combined cycle power plant.
- the steam generator is typically located in or upstream of a vertical stack that allows the exhaust combustion gases to naturally rise across tubes in the steam generator to enhance steam generation.
- a customer may limit the height of the vertical stack, resulting in a corresponding limit in the size of the steam generator and the amount of steam that it may produce.
- the gas turbine often includes one or more heat exchangers associated with auxiliary components, and the heat removed by these heat exchangers is often not recaptured, thus reducing the overall efficiency of the combined cycle power plant. Consequently, there is a need for systems that makes more efficient use of the heat extracted by the heat exchangers of auxiliary components while increasing steam generation, particularly in systems having vertical stacks of limited height.
- One embodiment of the present invention is a combined cycle power plant that includes a gas turbine having a first compressor, at least one combustor downstream of the first compressor, a turbine downstream of the combustor, and a second compressor downstream of the first compressor.
- a regenerative heat exchanger is between the first and second compressors, and a steam generator is downstream of the turbine and receives exhaust from the turbine.
- a steam turbine is downstream of the steam generator, and a condenser is downstream of the steam turbine and upstream of the steam generator.
- a first condensate pump is between the condenser and the steam generator and in fluid communication with the regenerative heat exchanger.
- Another embodiment of the present invention is a combined cycle power plant that includes a gas turbine having a first compressor, a second compressor downstream of the first compressor, and a regenerative heat exchanger between the first and second compressors.
- a steam generator is downstream of the gas turbine and receives exhaust from the gas turbine.
- a closed loop cooling system through the regenerative heat exchanger and the steam generator transfers heat from the regenerative heat exchanger to the steam generator.
- the present invention also includes a method for operating a combined cycle power plant that includes compressing a working fluid in a compressor and cooling the compressed working fluid with a regenerative heat exchanger so as to create a cooled compressed working fluid.
- the method further includes transferring heat from the regenerative heat exchanger to a steam generator.
- FIG. 1 is a simplified block diagram of a combined cycle power plant according to one embodiment of the present invention.
- FIG. 1 shows a simplified block diagram of a combined cycle power plant 10 according to one embodiment of the present invention.
- the combined cycle power plant 10 generally includes a gas turbine 12 connected to a heat recovery system 14 as is known in the art.
- the gas turbine 12 includes a first compressor 16 , at least one combustor 18 downstream of the first compressor 16 , and a turbine 20 downstream of the combustor 18 .
- upstream and downstream refer to the relative location of components in a fluid pathway. For example, component A is upstream of component B if a fluid flows from component A to component B. Conversely, component B is downstream of component A if component B receives a fluid flow from component A.
- the first compressor 16 produces a compressed working fluid 22 which flows to the combustor 18 .
- the combustor 18 generally combines the compressed working fluid 22 with a supply of fuel 24 and/or diluent 26 and ignites the mixture to produce combustion gases 28 .
- the supplied fuel 24 may be any suitable fuel used by commercial combustion engines, such as blast furnace gas, coke oven gas, natural gas, vaporized liquefied natural gas (LNG), propane, and any form of liquid fuel.
- the diluent 26 may be any fluid suitable for diluting or cooling the fuel, such as compressed air, steam, nitrogen, or another inert gas.
- the combustion gases 28 flow to the turbine 20 where they expand to produce work.
- the heat recovery system 14 generally includes a steam generator 30 , a steam turbine 32 , and a condenser 34 .
- the steam generator 30 is located downstream from the turbine 20 , and exhaust combustion gases 36 from the turbine 20 flow through the steam generator 30 to produce steam 38 .
- the steam turbine 32 is located downstream of the steam generator 30 , and the steam 38 from the steam generator 30 expands in the steam turbine 32 to produce work.
- the condenser 34 is located downstream of the steam turbine 32 and upstream of the steam generator 30 and condenses the steam 38 from the steam generator 30 into condensate 40 which is returned to the steam generator 30 .
- a first condensate pump 42 between the condenser 34 and the steam generator 30 is in fluid communication with the steam generator 30 to provide condensate 40 from the condenser 34 to the steam generator 30 .
- a second condensate pump 44 may be present to increase the pressure of the condensate 40 supplied to subsequent stages of the steam generator 30 .
- the gas turbine 12 may further include a second compressor 46 downstream of the first compressor 16 and upstream of the combustor 18 .
- the second compressor 46 receives a portion of the compressed working fluid 48 from the first compressor 16 and increases the pressure of the compressed working fluid 48 from the first compressor 16 .
- the typical increase in pressure provided by the second compressor 46 is approximately 30 to 70%, although the actual increase in pressure is not a limitation of the invention unless recited in the claims.
- the output of the second compressor 46 may be referred to as atomizing air 50 and is injected into the combustor 18 with the fuel 24 and/or diluent 26 to atomize the mixture to enhance the efficiency of the combustion.
- the portion of the compressed working fluid 48 supplied by the first compressor 16 to the second compressor 46 typically has a temperature on the order of 650 to 900° F.
- a closed loop cooling system between the gas turbine 12 and the heat recovery system 14 may be used to reduce the temperature of the portion of the compressed working fluid 48 supplied by the first compressor 16 .
- a closed loop cooling system is defined as any cooling system in which at least some coolant in the system flows in a repeating loop, including a system in which coolant is added to or removed from the loop.
- a regenerative heat exchanger 52 may be located between the first and second compressors 16 , 46 to remove heat from the portion of the compressed working fluid 48 supplied by the first compressor 16 to the second compressor 46 .
- the regenerative heat exchanger 52 includes any heat exchanger in which the heat removed by the heat exchanger is transferred to another component for use prior to release to the environment.
- the closed loop cooling system provides a fluid communication for a coolant, such as the condensate 40 , to flow through and between the steam generator 30 and the regenerative heat exchanger 52 .
- the first condensate pump 42 may supply the coolant (e.g., the condensate 40 ) through piping to the regenerative heat exchanger 52 .
- the coolant flows through the regenerative heat exchanger 52 , it removes heat from the portion of the compressed working fluid 48 flowing through the regenerative heat exchanger 52 to the second compressor 46 .
- the regenerative heat exchanger 52 may reduce the temperature of the compressed working fluid 54 supplied to the second compressor 46 to less than 400°, 350°, 300°, or 250° F., as desired.
- the coolant may then flow to the second condensate pump 44 , at the point indicated by reference number 58 .
- the second condensate pump 44 increases the pressure of the coolant and supplies the coolant to the steam generator 30 .
- the closed loop cooling system transfers heat from the regenerative heat exchanger 52 to the steam generator 30 , thereby increasing the overall efficiency of the combined cycle power plant 10 .
- the amount of heat transferred from the regenerative heat exchanger 52 to the steam generator 30 may be capable of generating more than 200 to 650 kW of power.
- the combined cycle power plant 10 described and illustrated in FIG. 1 provides a method for operating the combined cycle power plant 10 at an improved efficiency.
- the method includes compressing the working fluid in the first compressor 16 and cooling the compressed working fluid 48 with the regenerative heat exchanger 52 so as to create the cooled compressed working fluid 54 .
- the method further includes transferring heat from the regenerative heat exchanger 52 to the steam generator 30 so that the heat removed by the regenerative heat exchanger 52 may be used to generate steam 38 and perform work.
- the steam 38 may then be condensed into condensate 40 and pumped through the closed loop cooling system through the regenerative heat exchanger 52 and steam generator 30 .
- the cooled compressed working fluid 54 may be further compressed and supplied to the combustors 18 to atomize the fuel 24 and/or diluent 26 with the cooled compressed working fluid 50 .
- the method may result in transferring more than 200 to 650 kW of power from the regenerative the exchanger 52 to the steam generator 30 .
Landscapes
- Engineering & Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- Combustion & Propulsion (AREA)
- Mechanical Engineering (AREA)
- General Engineering & Computer Science (AREA)
- Engine Equipment That Uses Special Cycles (AREA)
Abstract
Description
- The present invention generally involves a power plant that combines a conventional gas turbine with a heat recovery system to improve the overall efficiency of the combined cycle power plant. Specific embodiments of the present invention may include a regenerative heat exchanger that transfers heat from the gas turbine to the heat recovery system.
- Gas turbines are widely used in industrial and power generation operations. A typical gas turbine includes an axial compressor at the front, one or more combustors around the middle, and a turbine at the rear. Ambient air enters the compressor, and stationary vanes and rotating blades in the compressor progressively impart kinetic energy to the working fluid (air) to produce a compressed working fluid at a highly energized state. The compressed working fluid exits the compressor and flows through nozzles in the combustors where it mixes with fuel and ignites to generate combustion gases having a high temperature, pressure, and velocity. The combustion gases flow to the turbine where they expand to produce work. For example, expansion of the combustion gases in the turbine may rotate a shaft connected to a generator to produce electricity.
- The combustion gases exit the turbine, and, if released immediately to the environment, would result in wasted energy generated by the gas turbine that does not produce work. Therefore, a heat recovery system is often connected downstream of the turbine to receive the exhaust combustion gases from the turbine. The combination of the gas turbine and heat recovery system is commonly referred to as a combined cycle power plant. The heat recovery system typically includes a steam generator, a steam turbine, and a condenser. The exhaust combustion gases flow to the steam generator where they heat water to generate steam. The steam then flows through the steam generator where it expands to produce work. For example, expansion of the steam in the steam turbine may rotate a shaft connected to a generator to produce electricity. The shaft and generator may be the same shaft and generator connected to the gas turbine, or the gas turbine and heat recovery system may operate using separate shafts and generators. The condenser downstream of the steam generator condenses the steam to condensate, and condensate pumps direct the condensate back to the steam generator. The heat recovery system thus captures energy from the exhaust combustion gases before they are eventually released to the environment, thus increasing the overall efficiency of the combined cycle power plant.
- The steam generator is typically located in or upstream of a vertical stack that allows the exhaust combustion gases to naturally rise across tubes in the steam generator to enhance steam generation. In some instances, a customer may limit the height of the vertical stack, resulting in a corresponding limit in the size of the steam generator and the amount of steam that it may produce. In addition, the gas turbine often includes one or more heat exchangers associated with auxiliary components, and the heat removed by these heat exchangers is often not recaptured, thus reducing the overall efficiency of the combined cycle power plant. Consequently, there is a need for systems that makes more efficient use of the heat extracted by the heat exchangers of auxiliary components while increasing steam generation, particularly in systems having vertical stacks of limited height.
- Aspects and advantages of the invention are set forth below in the following description, or may be obvious from the description, or may be learned through practice of the invention.
- One embodiment of the present invention is a combined cycle power plant that includes a gas turbine having a first compressor, at least one combustor downstream of the first compressor, a turbine downstream of the combustor, and a second compressor downstream of the first compressor. A regenerative heat exchanger is between the first and second compressors, and a steam generator is downstream of the turbine and receives exhaust from the turbine. A steam turbine is downstream of the steam generator, and a condenser is downstream of the steam turbine and upstream of the steam generator. A first condensate pump is between the condenser and the steam generator and in fluid communication with the regenerative heat exchanger.
- Another embodiment of the present invention is a combined cycle power plant that includes a gas turbine having a first compressor, a second compressor downstream of the first compressor, and a regenerative heat exchanger between the first and second compressors. A steam generator is downstream of the gas turbine and receives exhaust from the gas turbine. A closed loop cooling system through the regenerative heat exchanger and the steam generator transfers heat from the regenerative heat exchanger to the steam generator.
- The present invention also includes a method for operating a combined cycle power plant that includes compressing a working fluid in a compressor and cooling the compressed working fluid with a regenerative heat exchanger so as to create a cooled compressed working fluid. The method further includes transferring heat from the regenerative heat exchanger to a steam generator.
- Those of ordinary skill in the art will better appreciate the features and aspects of such embodiments, and others, upon review of the specification.
- A full and enabling disclosure of the present invention, including the best mode thereof to one skilled in the art, is set forth more particularly in the remainder of the specification, including reference to the accompanying figures, in which:
-
FIG. 1 is a simplified block diagram of a combined cycle power plant according to one embodiment of the present invention. - Reference will now be made in detail to present embodiments of the invention, one or more examples of which are illustrated in the accompanying drawings. The detailed description uses numerical and letter designations to refer to features in the drawings. Like or similar designations in the drawings and description have been used to refer to like or similar parts of the invention.
- Each example is provided by way of explanation of the invention, not limitation of the invention. In fact, it will be apparent to those skilled in the art that modifications and variations can be made in the present invention without departing from the scope or spirit thereof. For instance, features illustrated or described as part of one embodiment may be used on another embodiment to yield a still further embodiment. Thus, it is intended that the present invention covers such modifications and variations as come within the scope of the appended claims and their equivalents.
-
FIG. 1 shows a simplified block diagram of a combinedcycle power plant 10 according to one embodiment of the present invention. The combinedcycle power plant 10 generally includes agas turbine 12 connected to aheat recovery system 14 as is known in the art. For example, as shown inFIG. 1 , thegas turbine 12 includes afirst compressor 16, at least onecombustor 18 downstream of thefirst compressor 16, and aturbine 20 downstream of thecombustor 18. As used herein, the terms “upstream” and “downstream” refer to the relative location of components in a fluid pathway. For example, component A is upstream of component B if a fluid flows from component A to component B. Conversely, component B is downstream of component A if component B receives a fluid flow from component A. Thefirst compressor 16 produces a compressed workingfluid 22 which flows to thecombustor 18. Thecombustor 18 generally combines the compressed workingfluid 22 with a supply offuel 24 and/or diluent 26 and ignites the mixture to producecombustion gases 28. The suppliedfuel 24 may be any suitable fuel used by commercial combustion engines, such as blast furnace gas, coke oven gas, natural gas, vaporized liquefied natural gas (LNG), propane, and any form of liquid fuel. The diluent 26 may be any fluid suitable for diluting or cooling the fuel, such as compressed air, steam, nitrogen, or another inert gas. Thecombustion gases 28 flow to theturbine 20 where they expand to produce work. - The
heat recovery system 14 generally includes asteam generator 30, asteam turbine 32, and acondenser 34. Thesteam generator 30 is located downstream from theturbine 20, andexhaust combustion gases 36 from theturbine 20 flow through thesteam generator 30 to producesteam 38. Thesteam turbine 32 is located downstream of thesteam generator 30, and thesteam 38 from thesteam generator 30 expands in thesteam turbine 32 to produce work. Thecondenser 34 is located downstream of thesteam turbine 32 and upstream of thesteam generator 30 and condenses thesteam 38 from thesteam generator 30 intocondensate 40 which is returned to thesteam generator 30. Afirst condensate pump 42 between thecondenser 34 and thesteam generator 30 is in fluid communication with thesteam generator 30 to providecondensate 40 from thecondenser 34 to thesteam generator 30. In addition, asecond condensate pump 44 may be present to increase the pressure of thecondensate 40 supplied to subsequent stages of thesteam generator 30. - Returning to the
gas turbine 12 portion of the combinedcycle power plant 10, thegas turbine 12 may further include asecond compressor 46 downstream of thefirst compressor 16 and upstream of thecombustor 18. Thesecond compressor 46 receives a portion of the compressed workingfluid 48 from thefirst compressor 16 and increases the pressure of the compressed workingfluid 48 from thefirst compressor 16. The typical increase in pressure provided by thesecond compressor 46 is approximately 30 to 70%, although the actual increase in pressure is not a limitation of the invention unless recited in the claims. The output of thesecond compressor 46 may be referred to as atomizingair 50 and is injected into thecombustor 18 with thefuel 24 and/ordiluent 26 to atomize the mixture to enhance the efficiency of the combustion. - The portion of the compressed working
fluid 48 supplied by thefirst compressor 16 to thesecond compressor 46 typically has a temperature on the order of 650 to 900° F. A closed loop cooling system between thegas turbine 12 and theheat recovery system 14 may be used to reduce the temperature of the portion of the compressed workingfluid 48 supplied by thefirst compressor 16. As used herein, “a closed loop cooling system” is defined as any cooling system in which at least some coolant in the system flows in a repeating loop, including a system in which coolant is added to or removed from the loop. Specifically, aregenerative heat exchanger 52 may be located between the first andsecond compressors fluid 48 supplied by thefirst compressor 16 to thesecond compressor 46. As used herein, theregenerative heat exchanger 52 includes any heat exchanger in which the heat removed by the heat exchanger is transferred to another component for use prior to release to the environment. The closed loop cooling system provides a fluid communication for a coolant, such as thecondensate 40, to flow through and between thesteam generator 30 and theregenerative heat exchanger 52. For example, as shown inFIG. 1 , thefirst condensate pump 42 may supply the coolant (e.g., the condensate 40) through piping to theregenerative heat exchanger 52. As the coolant flows through theregenerative heat exchanger 52, it removes heat from the portion of the compressed workingfluid 48 flowing through theregenerative heat exchanger 52 to thesecond compressor 46. For example, theregenerative heat exchanger 52 may reduce the temperature of the compressed workingfluid 54 supplied to thesecond compressor 46 to less than 400°, 350°, 300°, or 250° F., as desired. After leaving theregenerative heat exchanger 52, at the point indicated byreference number 56, the coolant may then flow to thesecond condensate pump 44, at the point indicated byreference number 58. Thesecond condensate pump 44 increases the pressure of the coolant and supplies the coolant to thesteam generator 30. In this manner, the closed loop cooling system transfers heat from theregenerative heat exchanger 52 to thesteam generator 30, thereby increasing the overall efficiency of the combinedcycle power plant 10. In some embodiments, the amount of heat transferred from theregenerative heat exchanger 52 to thesteam generator 30 may be capable of generating more than 200 to 650 kW of power. - One of ordinary skill in the art will readily appreciate that the combined
cycle power plant 10 described and illustrated inFIG. 1 provides a method for operating the combinedcycle power plant 10 at an improved efficiency. Specifically, the method includes compressing the working fluid in thefirst compressor 16 and cooling the compressed workingfluid 48 with theregenerative heat exchanger 52 so as to create the cooled compressed workingfluid 54. The method further includes transferring heat from theregenerative heat exchanger 52 to thesteam generator 30 so that the heat removed by theregenerative heat exchanger 52 may be used to generatesteam 38 and perform work. Thesteam 38 may then be condensed intocondensate 40 and pumped through the closed loop cooling system through theregenerative heat exchanger 52 andsteam generator 30. The cooled compressed workingfluid 54 may be further compressed and supplied to thecombustors 18 to atomize thefuel 24 and/or diluent 26 with the cooled compressed workingfluid 50. Depending on the particular design needs, the method may result in transferring more than 200 to 650 kW of power from the regenerative theexchanger 52 to thesteam generator 30. - This written description uses examples to disclose the invention, including the best mode, and also to enable any person skilled in the art to practice the invention, including making and using any devices or systems and performing any incorporated methods. The patentable scope of the invention is defined by the claims, and may include other examples that occur to those skilled in the art. Such other and examples are intended to be within the scope of the claims if they include structural elements that do not differ from the literal language of the claims, or if they include equivalent structural elements with insubstantial differences from the literal languages of the claims.
Claims (20)
Priority Applications (6)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/877,427 US8141336B1 (en) | 2010-09-08 | 2010-09-08 | Combined cycle power augmentation by efficient utilization of atomizing air energy |
DE102011052933A DE102011052933A1 (en) | 2010-09-08 | 2011-08-23 | Increase the performance of a combined cycle power plant by efficiently using the energy of atomizing air |
CH01434/11A CH703748B1 (en) | 2010-09-08 | 2011-09-01 | Combined cycle power plant and method for operating a combined cycle power plant. |
JP2011193424A JP5184683B2 (en) | 2010-09-08 | 2011-09-06 | Enhanced combined cycle power through efficient use of atomized air energy |
CN201110283534.6A CN102444438B (en) | 2010-09-08 | 2011-09-08 | Combined cycle power plant and method of operation thereof |
US13/403,044 US20120144838A1 (en) | 2010-09-08 | 2012-02-23 | Combined cycle power augmentation by efficient utilization of atomizing air energy |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/877,427 US8141336B1 (en) | 2010-09-08 | 2010-09-08 | Combined cycle power augmentation by efficient utilization of atomizing air energy |
Related Child Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US13/403,044 Division US20120144838A1 (en) | 2010-09-08 | 2012-02-23 | Combined cycle power augmentation by efficient utilization of atomizing air energy |
Publications (2)
Publication Number | Publication Date |
---|---|
US20120055166A1 true US20120055166A1 (en) | 2012-03-08 |
US8141336B1 US8141336B1 (en) | 2012-03-27 |
Family
ID=45595540
Family Applications (2)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US12/877,427 Expired - Fee Related US8141336B1 (en) | 2010-09-08 | 2010-09-08 | Combined cycle power augmentation by efficient utilization of atomizing air energy |
US13/403,044 Abandoned US20120144838A1 (en) | 2010-09-08 | 2012-02-23 | Combined cycle power augmentation by efficient utilization of atomizing air energy |
Family Applications After (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US13/403,044 Abandoned US20120144838A1 (en) | 2010-09-08 | 2012-02-23 | Combined cycle power augmentation by efficient utilization of atomizing air energy |
Country Status (5)
Country | Link |
---|---|
US (2) | US8141336B1 (en) |
JP (1) | JP5184683B2 (en) |
CN (1) | CN102444438B (en) |
CH (1) | CH703748B1 (en) |
DE (1) | DE102011052933A1 (en) |
Cited By (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP2642091A1 (en) * | 2012-03-22 | 2013-09-25 | Siemens Aktiengesellschaft | Combined cycle power plant |
EP2679784A1 (en) * | 2012-06-26 | 2014-01-01 | General Electric Company | Hot water injection for turbomachine |
US20140110092A1 (en) * | 2012-10-23 | 2014-04-24 | General Electric Company | Atomizing air heat for attemperation |
US20140318134A1 (en) * | 2013-04-24 | 2014-10-30 | General Electric Company | Backup fuel supply for a gas turbine |
US20160169106A1 (en) * | 2013-07-04 | 2016-06-16 | Hanwha Techwin Co., Ltd. | Gas turbine system |
Families Citing this family (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2014158244A2 (en) | 2013-03-14 | 2014-10-02 | Rolls-Royce North American Technologies, Inc. | Intercooled gas turbine with closed combined power cycle |
Citations (7)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4896499A (en) * | 1978-10-26 | 1990-01-30 | Rice Ivan G | Compression intercooled gas turbine combined cycle |
US5313782A (en) * | 1991-06-01 | 1994-05-24 | Asea Brown Boveri Ltd. | Combined gas/steam power station plant |
US5457951A (en) * | 1993-12-10 | 1995-10-17 | Cabot Corporation | Improved liquefied natural gas fueled combined cycle power plant |
US5664414A (en) * | 1995-08-31 | 1997-09-09 | Ormat Industries Ltd. | Method of and apparatus for generating power |
US5758502A (en) * | 1995-07-12 | 1998-06-02 | Hitachi, Ltd. | Gas turbine intake air cooling system and operating method thereof |
US6198786B1 (en) * | 1998-05-22 | 2001-03-06 | General Electric Company | Methods of reactor system pressure control by reactor core power modulation |
US20020078689A1 (en) * | 2000-10-02 | 2002-06-27 | Coleman Richard R. | Coleman regenerative engine with exhaust gas water extraction |
Family Cites Families (7)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
FR2681416B1 (en) * | 1991-09-13 | 1993-11-19 | Air Liquide | METHOD FOR COOLING A GAS IN AN AIR GAS OPERATING INSTALLATION, AND INSTALLATION. |
DE4237665A1 (en) * | 1992-11-07 | 1994-05-11 | Asea Brown Boveri | Method for operating a combination system |
JP3593488B2 (en) * | 2000-02-25 | 2004-11-24 | 株式会社日立製作所 | gas turbine |
NL1020350C2 (en) * | 2002-04-10 | 2003-10-13 | Henk Ouwerkerk | Steam and gas turbine installation. |
US20070017207A1 (en) | 2005-07-25 | 2007-01-25 | General Electric Company | Combined Cycle Power Plant |
US7644573B2 (en) | 2006-04-18 | 2010-01-12 | General Electric Company | Gas turbine inlet conditioning system and method |
US7730712B2 (en) | 2008-07-31 | 2010-06-08 | General Electric Company | System and method for use in a combined cycle or rankine cycle power plant using an air-cooled steam condenser |
-
2010
- 2010-09-08 US US12/877,427 patent/US8141336B1/en not_active Expired - Fee Related
-
2011
- 2011-08-23 DE DE102011052933A patent/DE102011052933A1/en not_active Withdrawn
- 2011-09-01 CH CH01434/11A patent/CH703748B1/en not_active IP Right Cessation
- 2011-09-06 JP JP2011193424A patent/JP5184683B2/en not_active Expired - Fee Related
- 2011-09-08 CN CN201110283534.6A patent/CN102444438B/en not_active Expired - Fee Related
-
2012
- 2012-02-23 US US13/403,044 patent/US20120144838A1/en not_active Abandoned
Patent Citations (8)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4896499A (en) * | 1978-10-26 | 1990-01-30 | Rice Ivan G | Compression intercooled gas turbine combined cycle |
US4896499B1 (en) * | 1978-10-26 | 1992-09-15 | G Rice Ivan | |
US5313782A (en) * | 1991-06-01 | 1994-05-24 | Asea Brown Boveri Ltd. | Combined gas/steam power station plant |
US5457951A (en) * | 1993-12-10 | 1995-10-17 | Cabot Corporation | Improved liquefied natural gas fueled combined cycle power plant |
US5758502A (en) * | 1995-07-12 | 1998-06-02 | Hitachi, Ltd. | Gas turbine intake air cooling system and operating method thereof |
US5664414A (en) * | 1995-08-31 | 1997-09-09 | Ormat Industries Ltd. | Method of and apparatus for generating power |
US6198786B1 (en) * | 1998-05-22 | 2001-03-06 | General Electric Company | Methods of reactor system pressure control by reactor core power modulation |
US20020078689A1 (en) * | 2000-10-02 | 2002-06-27 | Coleman Richard R. | Coleman regenerative engine with exhaust gas water extraction |
Cited By (9)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP2642091A1 (en) * | 2012-03-22 | 2013-09-25 | Siemens Aktiengesellschaft | Combined cycle power plant |
EP2679784A1 (en) * | 2012-06-26 | 2014-01-01 | General Electric Company | Hot water injection for turbomachine |
US20140110092A1 (en) * | 2012-10-23 | 2014-04-24 | General Electric Company | Atomizing air heat for attemperation |
US9341113B2 (en) * | 2012-10-23 | 2016-05-17 | General Electric Company | Atomizing air heat exchange for heating attemperation feed water in a combined cycle turbine |
EP2725213A3 (en) * | 2012-10-23 | 2017-11-29 | General Electric Company | Atomizing air heat for attemperation |
US20140318134A1 (en) * | 2013-04-24 | 2014-10-30 | General Electric Company | Backup fuel supply for a gas turbine |
US9347376B2 (en) * | 2013-04-24 | 2016-05-24 | General Electric Company | Liquified fuel backup fuel supply for a gas turbine |
US20160169106A1 (en) * | 2013-07-04 | 2016-06-16 | Hanwha Techwin Co., Ltd. | Gas turbine system |
US10273882B2 (en) * | 2013-07-04 | 2019-04-30 | Hanwha Aerospace Co., Ltd. | Gas turbine system using supplemental compressed air to cool |
Also Published As
Publication number | Publication date |
---|---|
CH703748B1 (en) | 2015-12-31 |
CH703748A2 (en) | 2012-03-15 |
JP5184683B2 (en) | 2013-04-17 |
CN102444438A (en) | 2012-05-09 |
DE102011052933A1 (en) | 2012-03-08 |
US20120144838A1 (en) | 2012-06-14 |
US8141336B1 (en) | 2012-03-27 |
CN102444438B (en) | 2016-01-27 |
JP2012057617A (en) | 2012-03-22 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US11047264B2 (en) | Power generation system and method with partially recuperated flow path | |
US11047307B2 (en) | Hybrid expander cycle with intercooling and turbo-generator | |
US9797310B2 (en) | Heat pipe temperature management system for a turbomachine | |
US20200088098A1 (en) | Hybrid expander cycle with pre-compression cooling and turbo-generator | |
EP3183433B1 (en) | Power generation system and method for generating power | |
US8281565B2 (en) | Reheat gas turbine | |
RU2719413C2 (en) | Systems with closed regenerative thermodynamic cycle of electric power generation and methods of their operation | |
US8141336B1 (en) | Combined cycle power augmentation by efficient utilization of atomizing air energy | |
US20140150443A1 (en) | Gas Turbine Engine with Integrated Bottoming Cycle System | |
JPH0586898A (en) | Halfopen cycle operation type natural gas steam turbine system | |
US20150192036A1 (en) | Preheating arrangement for a combined cycle plant | |
JP2012132454A (en) | System and method for using gas turbine intercooler heat in bottoming steam cycle | |
US20140345278A1 (en) | Method for operating a gas and steam turbine installation for frequency support | |
EP2294298A1 (en) | Combined cycle power plant | |
US20120180493A1 (en) | Apparatus and method for controlling oxygen emissions from a gas turbine | |
EP3318733B1 (en) | Feedwater bypass system for a desuperheater | |
US11371395B2 (en) | Gland steam condenser for a combined cycle power plant and methods of operating the same | |
US20140216045A1 (en) | Gas turbine with improved power output | |
KR101457783B1 (en) | Combined cycle power generator | |
JP2005054622A (en) | Open cycle gas turbine apparatus |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
AS | Assignment |
Owner name: GENERAL ELECTRIC COMPANY, NEW YORK Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:JOHN, JOSEPH;MARUTHAMUTHU, JEGADEESAN;RAJAN, SUDHAHAR;AND OTHERS;REEL/FRAME:024954/0666 Effective date: 20100803 |
|
STCF | Information on status: patent grant |
Free format text: PATENTED CASE |
|
CC | Certificate of correction | ||
FPAY | Fee payment |
Year of fee payment: 4 |
|
FEPP | Fee payment procedure |
Free format text: MAINTENANCE FEE REMINDER MAILED (ORIGINAL EVENT CODE: REM.); ENTITY STATUS OF PATENT OWNER: LARGE ENTITY |
|
LAPS | Lapse for failure to pay maintenance fees |
Free format text: PATENT EXPIRED FOR FAILURE TO PAY MAINTENANCE FEES (ORIGINAL EVENT CODE: EXP.); ENTITY STATUS OF PATENT OWNER: LARGE ENTITY |
|
STCH | Information on status: patent discontinuation |
Free format text: PATENT EXPIRED DUE TO NONPAYMENT OF MAINTENANCE FEES UNDER 37 CFR 1.362 |
|
FP | Expired due to failure to pay maintenance fee |
Effective date: 20200327 |