WO2001018372A1 - Turbine a gaz fonctionnant a des temperatures ambiantes elevees - Google Patents

Turbine a gaz fonctionnant a des temperatures ambiantes elevees Download PDF

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Publication number
WO2001018372A1
WO2001018372A1 PCT/US2000/023973 US0023973W WO0118372A1 WO 2001018372 A1 WO2001018372 A1 WO 2001018372A1 US 0023973 W US0023973 W US 0023973W WO 0118372 A1 WO0118372 A1 WO 0118372A1
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WO
WIPO (PCT)
Prior art keywords
turbine
compressor
gas
power plant
temperature
Prior art date
Application number
PCT/US2000/023973
Other languages
English (en)
Inventor
William Leslie Kopko
Original Assignee
Enhanced Turbine Output Holding, Llc
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 Enhanced Turbine Output Holding, Llc filed Critical Enhanced Turbine Output Holding, Llc
Priority to US10/070,247 priority Critical patent/US6718771B1/en
Priority to AU73402/00A priority patent/AU7340200A/en
Publication of WO2001018372A1 publication Critical patent/WO2001018372A1/fr

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Classifications

    • 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
    • F02C9/00—Controlling gas-turbine plants; Controlling fuel supply in air- breathing jet-propulsion plants
    • F02C9/16—Control of working fluid flow
    • F02C9/18—Control of working fluid flow by bleeding, bypassing or acting on variable working fluid interconnections between turbines or compressors or their 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
    • F02C7/12—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
    • F02C7/143—Cooling of plants of fluids in the plant, e.g. lubricant or fuel of working fluid before or between the compressor stages
    • F02C7/1435—Cooling of plants of fluids in the plant, e.g. lubricant or fuel of working fluid before or between the compressor stages by water injection
    • 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
    • F02C9/00—Controlling gas-turbine plants; Controlling fuel supply in air- breathing jet-propulsion plants
    • F02C9/26—Control of fuel supply
    • 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
    • F02C9/00—Controlling gas-turbine plants; Controlling fuel supply in air- breathing jet-propulsion plants
    • F02C9/26—Control of fuel supply
    • F02C9/28—Regulating systems responsive to plant or ambient parameters, e.g. temperature, pressure, rotor speed
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05D—INDEXING SCHEME FOR ASPECTS RELATING TO NON-POSITIVE-DISPLACEMENT MACHINES OR ENGINES, GAS-TURBINES OR JET-PROPULSION PLANTS
    • F05D2260/00—Function
    • F05D2260/20—Heat transfer, e.g. cooling
    • F05D2260/212—Heat transfer, e.g. cooling by water injection
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05D—INDEXING SCHEME FOR ASPECTS RELATING TO NON-POSITIVE-DISPLACEMENT MACHINES OR ENGINES, GAS-TURBINES OR JET-PROPULSION PLANTS
    • F05D2270/00—Control
    • F05D2270/01—Purpose of the control system
    • F05D2270/05—Purpose of the control system to affect the output of the engine
    • F05D2270/053—Explicitly mentioned power
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05D—INDEXING SCHEME FOR ASPECTS RELATING TO NON-POSITIVE-DISPLACEMENT MACHINES OR ENGINES, GAS-TURBINES OR JET-PROPULSION PLANTS
    • F05D2270/00—Control
    • F05D2270/01—Purpose of the control system
    • F05D2270/06—Purpose of the control system to match engine to driven device
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05D—INDEXING SCHEME FOR ASPECTS RELATING TO NON-POSITIVE-DISPLACEMENT MACHINES OR ENGINES, GAS-TURBINES OR JET-PROPULSION PLANTS
    • F05D2270/00—Control
    • F05D2270/01—Purpose of the control system
    • F05D2270/06—Purpose of the control system to match engine to driven device
    • F05D2270/061—Purpose of the control system to match engine to driven device in particular the electrical frequency of driven generator
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05D—INDEXING SCHEME FOR ASPECTS RELATING TO NON-POSITIVE-DISPLACEMENT MACHINES OR ENGINES, GAS-TURBINES OR JET-PROPULSION PLANTS
    • F05D2270/00—Control
    • F05D2270/01—Purpose of the control system
    • F05D2270/16—Purpose of the control system to control water or steam injection

Definitions

  • This invention is related generally to gas-turbine power plants, and more specifically relates to gas-turbine generation plants with increased output at high ambient temperature conditions, and is especially suited for single-shaft gas turbines.
  • Figure 1 shows how inlet air temperature affects capacity for a typical gas turbine.
  • the normal rating condition is 59 °F and the capacity decreases at a rate of approximately .4% per °F.
  • the conventional approach used by designers of power plants for sizing generators, transformers, power distribution equipment, and other auxiliary equipment is based on achieving maximum turbine output at low ambient air temperatures.
  • the generator is sized for the lowest available ambient air, which can be -20
  • Mechanical inlet air chilling is another alternative that has seen limited use.
  • the air is typically chilled to approximately 50 degrees Fahrenheit, which gives a significant increase in capacity at high ambient temperatures.
  • relatively low temperatures force the cooling system to cool the inlet below the ambient dewpoint temperature, which results in a large latent cooling load.
  • the low cooling temperatures reduce the efficiency and capacity of the refrigeration systems used to provide the cooling.
  • U.S. patent 5,768,884 entitled “Gas turbine engine having flat rated horsepower,” describes a multishaft turbine with a variable intercooling system that maintains a constant temperature inlet air stream to a high-pressure compressor for a range of conditions.
  • This system maintains a constant power output over a range of temperatures, but at temperatures below 59 °F the intercooler is effectively off and the output increases in response to changes in ambient temperatures.
  • This approach has the disadvantages that the turbine capacity at lower ambient temperature is allowed to rise, which effectively sets the required size for the generator and related components and negates much of the advantage of the system.
  • the system requires a complicated and expensive arrangement of multiple spools and a heat exchanger for the intercooler. This cost and complexity means that it is not suitable for the majority of gas turbines for power generation, which use simple, single-spool configurations.
  • Variable compressor speed has also been used as an option for controlling turbine output.
  • U.S. patent 6,003,298, entitled, “Steam driven variable speed booster compressor for gas turbine” describes a multishaft gas turbine combined- cycle plant that uses a variable-speed steam turbine to drive a low-pressure compressor. The change in compressor speed is sufficient to maintain similar turbine operating conditions with the generator running at both 50 and 60 Hz line frequency.
  • U.S. Patents 4,251,987 and 3,853,432 describe variable-speed compressor arrangements using differential gearing. While these systems show additional ways of varying turbine capacity, none of them addresses the root problems with gas-turbine capacity at high ambient temperatures.
  • an improved gas-turbine power plant contains a compressor that is sized relative to the turbine section so that a maximum design power output occurs at a high ambient temperature, and a control system that modulates the turbine output to prevent overload at lower ambient temperatures.
  • Figure 1 is a graph which shows the effect of ambient temperature on turbine power output for the prior art
  • Figure 2 is a schematic diagram of a preferred embodiment of the invention with recirculation of compressor air to control power output;
  • Figure 3 is a schematic diagram of a preferred embodiment of the invention with burner control;
  • Figure 4 is a schematic diagram of an embodiment of the invention with a heater for the turbine inlet air stream
  • Figure 5 is a schematic diagram of a prefe ⁇ ed embodiment of the invention for new combined-cycle power plants
  • Figure 6 is a schematic diagram of a another prefe ⁇ ed embodiment of the invention that uses an indirect evaporative cooler
  • Figure 7 is a schematic diagram of a preferred embodiment of the invention that uses a fogger on the inlet to the compressor section of the gas turbine;
  • Figure 8 is a schematic diagram of an alternative embodiment of the invention that uses a mechanical cooling system to cool compressor inlet air that is suitable for sites that lack water for evaporative cooling;
  • Figure 9 is a graph that shows how turbine capacity with the present invention varies with ambient temperature.
  • FIG. 2 shows a preferred embodiment of a gas turbine generation system according to the invention, with a recirculation a ⁇ angement around the compressor to control capacity of the gas-turbine power plant.
  • the gas-turbine power plant 32 comprises a burner 22, compressor 20 and a turbine 24 that share a common shaft 30.
  • a compressor inlet air stream 40 enters the compressor 20 and is pressurized to form burner inlet air stream 42.
  • the burner 22 heats the air stream 42 and supplies it as burner outlet air stream 44 that enters turbine 24.
  • the turbine 24 rotates in response to the heated air stream, thereby causing the shaft 30 to rotate (which exits as exhaust 46).
  • the gas-turbine power plant would normally also include structure, bearings, controls, and other components, which are described in the prior art, and thus are not shown here.
  • the gas-turbine power plant may also include a bottoming steam cycle or multiple-shaft a ⁇ angements.
  • the turbine 24 drives the compressor 20 and a generator 26, which also shares the shaft 30.
  • the generator supplies electric power to the utility grid through conductors 36 and a transformer 28.
  • the gas-turbine power plant may also include a supercharging fan for raising the pressure of the compressor inlet air stream as will be described in more detail later.
  • the prefe ⁇ ed design for increasing the capacity of the gas-turbine power plant at high ambient temperatures would include a compressor that is larger than normal in comparison to the turbine.
  • the objective is to size the compressor to maintain the conventional design flow and pressure to the gas turbine at higher ambient temperatures.
  • the advantage with this approach is that the extra generating capacity at high ambient temperatures is achieved without increasing the size of the turbine, generator, or other equipment. Because of its relatively low operating temperatures, the compressor is a much less expensive component than the turbine.
  • the only real disadvantage of changing the relative compressor sizing is that it requires a compressor/turbine combination that is specially designed for this application.
  • An evaporative cooler 70 is located upstream of the compressor 20.
  • the evaporative cooler comprises an evaporative pad 34 and a water pump 36, which circulates water over the pad to create a wet surface for cooling the compressor inlet air stream 40 through evaporation of water.
  • the evaporative cooler would normally also include a sump with a float valve to control water level and a means for bleeding off a small portion of the circulated water to prevent build up of salts.
  • the prior art includes numerous evaporative coolers available commercially from a variety of manufacturers, so the details of the cooler design are not included in the figure.
  • a particular feature of the present invention is the sizing of the gas-turbine power plant relative to the generator and associated equipment.
  • the generator and turbine are sized so that the generator operates at nearly full capacity at summer-peaking conditions. For example, for much of the eastern United States the summer design
  • temperatures at peak capacity are approximately 95 °F dry-bulb and 75 °F wet-bulb.
  • the generator and associated electrical auxiliaries such as
  • the transformer would preferably be sized to output maximum power for a compressor
  • the present invention includes means for controlling turbine capacity so as to prevent overloading the generator at low ambient temperatures.
  • a controller 60 receives a cu ⁇ ent signal 68 from a current sensor 62 that senses generator current.
  • the cu ⁇ ent sensor is preferably a cu ⁇ ent transformer in which case the signal is in the form an AC cu ⁇ ent.
  • Other possible sensors provide a voltage, optical, radio frequency output or other signal.
  • the controller 60 provides a damper control signal 64 to a damper 50 that controls flow of a heated air stream 54 to the inlet of compressor 20.
  • the damper is preferably capable of modulating air flow in response to a control signal and would normally include an actuator.
  • a heated air stream 52 is drawn from the burner inlet air stream 42 and circulates through the damper 50 to the compressor inlet as a controlled air stream 54.
  • the controller 60 also provides a pump control signal 66 to pump 36. The pump control would normally be a simple on/off control.
  • the cu ⁇ ent sensor 62 communicates a co ⁇ espondingly higher generator cu ⁇ ent signal 68 to the controller 60.
  • the controller responds by first turning off the pump 36 which thereby deactivates the evaporative cooler 70 and allows the compressor inlet air stream 40 to approach the
  • the preferred control response is to open the damper 50 by a first amount to allow flow of heated air from the compressor outlet. Further drops in ambient air temperature would result in a further opening of the damper so as to increase the amount of heated air provided to the compressor in order to limit the generator current to prevent overload.
  • FIG 3 shows another prefe ⁇ ed embodiment that controls burner output instead of a damper, to prevent generator overload at low ambient temperatures.
  • a controller 74 receives a current signal 68 from a current sensor 62 that senses generator cu ⁇ ent and the controller 74 provides a pump control signal 66 to pump 36 to control operation of the pump.
  • the controller 74 provides a burner control signal 72 to the burner 22 instead of controlling a flow of heated air to the compressor inlet. This control signal regulates the burner output.
  • the preferred arrangement is to integrate the normal operating and safety controls for the gas- turbine power plant into controller 74, but it can also be a stand-alone controller.
  • the control approach is similar to that of Figure 2. As the ambient temperature drops and causes a resulting increase in generator current, the controller 74 first responds by turning off pump 36 to deactivate the evaporative cooler 70. If the generator current is still excessive (such as caused by the ambient temperature continuing to fall), the controller 74 further responds by adjusting burner signal 72 so as to reduce output of burner 22.
  • I ⁇ Figure 4 shows a third embodiment that controls compressor inlet temperature using a heater.
  • a controller 84 receives a temperature signal 90 from temperature sensor 88 that is located in the compressor inlet air stream 40.
  • the controller 84 provides a heater control signal 82 to a heater 80 located upstream of the compressor inlet.
  • the heater provides a heated air stream 86 to the compressor 20 through the evaporative cooler 70.
  • the controller 84 actuates the heater 80 to heat the air stream being supplied to the compressor. While the preferred location for the heater is upstream of the evaporative cooler, the heater may be located between the evaporative cooler 70 and the compressor 20 if the heater is made of materials that can handle high relative humidity without excessive co ⁇ osion.
  • a number of options for the heater There are a number of options for the heater.
  • One simple option is a gas burner.
  • a second option is a boiler with a separate liquid-to-air heat exchanger.
  • a third option is a heat exchanger that recovers heat from the turbine exhaust 46. This heat-recovery option should provide the best efficiency and is the prefe ⁇ ed option if installed cost is not excessive.
  • Electric heaters are a fourth option, though not preferred because of their poor efficiency. Blowing of a portion of the exhaust 46 into the compressor inlet air stream 40 is a low-cost fifth option, but may cause corrosion problems in the compressor 20 or other components.
  • the heater should be capable of modulating its output so as to maintain an approximately constant temperature of the heated air stream 86.
  • the control system is based on maintaining a minimum temperature of compressor inlet air stream 40. As the ambient air temperature drops, the controller 84 responds by turning off the pump 36 to deactivate the evaporative cooler 70. If the ambient temperature drops further, the controller 84 provides a heater signal 82 to turn on heater 80 and adjust its output to maintain the required temperature of the compressor inlet air stream 40.
  • a more sophisticated option to controlling the evaporative cooler is to include multiple sections that can be independently controlled so as to provide multiple steps of control.
  • the evaporative cooler can be made with three sections that are arranged in a series flow configuration on the airside. Turning off an individual cooler reduces the effectiveness of the cooling and raises the air temperature. The depth of each section would preferably be unequal with the deepest section turned off first. This setup allows for roughly the same temperature rise with each step of control for the evaporative cooler.
  • FIG. 5 shows a fourth embodiment, which is especially suitable for use with a combined-cycle power plant.
  • a combined-cycle gas-turbine power plant 106 includes an additional steam cycle 98 that uses exhaust 110 from the turbine 24.
  • the steam cycle 98 comprises a boiler 104, a steam turbine 100, and a condenser 102 which are connected together to form a circuit.
  • a liquid-to-air heat exchanger 93 is in a fluid loop with pump 92 and heat-recovery heat exchanger 96.
  • the pump 92 circulates heat-transfer liquid 112 through the heat-recovery heat exchanger 96 where it receives
  • the pump receives a signal 94 from controller 84 to modulate flow of the heat-transfer liquid 112 to control the temperature of air stream 86.
  • the controller can turn off the evaporative cooler 70 as a first step in controlling turbine inlet temperature.
  • Figure 5 shows a heat-transfer loop for recovering waste heat
  • heat from the condenser 102 could warm the inlet air stream.
  • An air-to-air heat exchanger between the exhaust and inlet air streams is also an option.
  • Co ⁇ osion-resistant materials are required to handle the presence of nitric acid and possibly sulfuric acid.
  • plastic materials usually have relatively low temperature limits. It may be desirable to mix the exhaust with ambient air to reduce the maximum temperatures to allow the use of plastics. Direct contact liquid-to-gas heat exchange is also an option. The liquid would contain a suitable neutralizing agent such as sodium bicarbonate to prevent problems with acid condensate. Here again it may be desirable to mix the exhaust air stream with ambient air to reduce maximum operating temperatures.
  • Control inputs may include generator power, ambient dry-bulb temperature, ambient wet-bulb temperature, shaft torque, or other inputs.
  • FIG. 6 is a fifth embodiment of the invention that uses an indirect evaporative cooler that can approach the ambient dewpoint temperature.
  • An indirect evaporative cooler 260 is located in the air stream between the ambient atmosphere 238 and the gas turbine 210.
  • the gas turbine 210 and generator 228 form a gas-turbine power plant 211.
  • the gas turbine 210 comprises a compressor 212, a burner 214, and a turbine 216.
  • the indirect evaporative cooler 260 uses a secondary air stream 262 which is taken from a portion of the primary air stream 264 that exits a direct evaporative cooler 268.
  • the direct evaporative cooler 268 is located between the indirect evaporative cooler 260 and the turbine 210 to further cool the air entering the turbine.
  • the direct evaporative cooler is optional.
  • a turbine inlet air stream 266 is formed by the remaining portion of the primary air stream 264 and enters turbine 210. The air from the secondary air stream
  • a controller 250 receives an input signal from a temperature sensor 252 that is located in the primary air stream 264 or similar location to provide a measurement of the inlet air temperature to the compressor 212.
  • the controller provides a control output to the burner 214 to prevent overload at low ambient air temperatures.
  • FIG. 7 shows a sixth embodiment that uses foggers.
  • a gas turbine power plant 311 comprises a gas turbine 310 and a generator 328.
  • the gas turbine 310 comprises a compressor 330 that is driven by a turbine 316 by way of shaft 324.
  • An output shaft 326 drives the generator 328, which supplies electrical power to an electric power transmission system 336.
  • the compressor comprises a base compressor 332 and a low compressor stage 334.
  • the base compressor 332 is of a design that would normally be used for the gas turbine in the prior art.
  • the low compressor stage 334 provides an additional stage of compression. For axial flow compressors this low compressor stage 334 would typically comprise one or more rows of compressor blades.
  • a controller 350 receives an input signal from an ambient temperature sensor 354.
  • the sensor 354 would preferably sense wet-bulb temperature.
  • Alternative sensors can be enthalpy sensors or a combination of dry-bulb temperature and either relative humidity or dewpoint sensors.
  • ambient air 380 enters the compressor inlet through a duct 382, which serves as a flow path between the atmosphere and the compressor inlet. Filters and silencers as found in the prior art may be added in this duct, although they are not necessary to operate the turbine.
  • a compressor outlet air stream 321 flows to a burner 314 that supplies heated compressed air 322 to the turbine 322.
  • An exhaust air stream 326 exits the turbine.
  • a heat recovery boiler for steam cycle plant can be located in this exhaust air stream 326 to create a combined cycle plant.
  • the controller 350 is connected to a first, second, and third water pump 356, 358, and 360.
  • the water pumps supply high-pressure water to corresponding first, second, and third headers 366, 368, and 370.
  • the headers include multiple spray nozzles 371.
  • the nozzles create a fog or mist 372.
  • the preferred pressure for the pumps is approximately 1000 to 3000 psi, which can provide a droplet size on the order of 15 microns or less. The small droplet size prevents undesirable damage to the compressor blades.
  • the prefe ⁇ ed water source for the pumps is demineralized, filtered water. This treated water prevents clogging of nozzles and prevents dissolved solids from building up on turbine components.
  • the controller 350 also has a control signal line connected to a valve 352 that allows a portion of the compressor outlet air stream 321 to flow to the compressor inlet. This flow increases the compressor inlet air temperature and also decreases the portion of the compressor outlet air stream that is available for the turbine. Both of these effects act to reduce turbine output.
  • the controller modulates the position of the valve to limit turbine capacity at low ambient air temperatures.
  • the compressor is selected to provide a maximum design output for the gas turbine at a preselected ambient temperature.
  • the preferred preselected ambient temperature is approximately equal to the maximum design wet-bulb temperature. For most areas of the eastern United States this value would be between 75 and 80 degrees Fahrenheit.
  • the maximum design output would normally correspond to the maximum capacity of the gas-turbine power plant that it can run at for extended periods of time without damaging critical components. For a new installation, this would normally be set by the capacity limits of the turbine 316. To minimize cost the generator 328 and the transmission system 336 would be sized to handle this maximum design output. For existing installations, the generator and/or the transmission capacity may already be fixed at a level below that of the turbine. In this case the minimum of the generator and transmission limits would be used to set the maximum design output. The compressor would then be selected to match this maximum design output at the preselected ambient temperature.
  • the preferred preselected ambient temperature for maximum design output would be lower.
  • the capacity available at typical summer design conditions may correspond to an ambient temperature of 60 °F with no fogging. Below this temperature the controller would turn the foggers off and air would be recirculated from the compressor outlet to prevent overload of the turbine, generator, or transmission system.
  • the prefe ⁇ ed preselected ambient temperature for the maximum design output would then approximately the maximum design dry-bulb temperature.
  • the compressor would be selected to provide the maximum design output at this condition and the valve 352 would allow bypass of compressor air below this temperature to prevent overload of the turbine. This setup may be necessary in applications where water for evaporative cooling is unavailable.
  • FIG 8 shows a seventh embodiment with an air-cooled mechanical cooling system that is suitable for installations with limited water supplies.
  • the gas-turbine power- plant 311 is the same as that described Figure 7 and the description will not be repeated here.
  • a chiller 400 has a refrigeration circuit formed by an air-cooled condenser 404 with a condenser fan 402, an expansion valve 408, a cooler 410, and a compressor 406.
  • a chilled water pump 412 moves water or other liquid through the cooler 410 and a chilled water supply line 414 to a cooling coil 418 which cools ambient air 380 that enters the gas turbine 310 through the duct 382.
  • a return chilled water line 416 brings warmed water back to the chilled water pump 412 to complete the loop.
  • a controller 420 receives an input signal from an inlet air temperature sensor 430 and controls the action of the chiller 400 and chilled water pump 412 and valve 352. At high ambient temperatures the controller runs the compressor 406 in the chiller at full capacity while at low temperatures it turns off the chiller and chilled water pump and actuates the valve 352 to limit turbine capacity. At intermediate temperatures the controller can modulate the cooling capacity of the chiller 400 to maintain a constant inlet air temperature to the gas turbine.
  • the prior art typically cools the inlet air to about 50°F, which results in a large cooling power requirement.
  • the present system would preferably cool to a much higher temperature, roughly equal to the coincident dewpoint at design maximum ambient temperature. For moderately humid climates, such as those in much of the eastern United States, this coincident dewpoint temperature is roughly 67 °F.
  • This approach eliminates the need for removal of latent heat associated with condensing moisture from the inlet air stream.
  • the cooling system can run with a much high refrigerant evaporating temperature, which increases system efficiency and capacity.
  • the compressor 330 would be selected to provide a maximum design capacity at this inlet air temperature. This setup gives a large capacity increase with much lower installed cost compared to conventional mechanical cooling systems.
  • the turbine may drive a compressor for compressing natural gas or refrigeration applications.
  • the output load is either flat or increases with higher ambient air temperature, which allows the present invention to better match the capability of the turbine to the load.
  • Figure 9 shows the capacity of the present invention compared to conventional gas- turbine systems. This figure shows that the capacity of the present invention is essentially flat, while the capacity for conventional systems drops rapidly at high ambient air temperatures.
  • the base system is a simple-cycle turbine that gives a
  • the present invention also has the same 100 MW capacity but maintains it at high ambient temperatures.
  • the bigger base and bigger base with evaporative cooler are simple-cycle turbines designed to match the present invention
  • the bigger base with evaporative cooler takes advantage of the lower inlet temperatures available from an evaporative cooler.
  • the design and operation of the present invention give it a large advantage over a conventional gas-turbine system. Specifically the capacity at high ambient temperatures can be increased by over 20% compared to a base turbine system through the addition of a low-cost evaporative cooler and an additional low-pressure stage on the compressor.
  • the conventional approach used by designers of gas-turbine power plants would be to increase the capacity of the turbine, generator, and transmission system, in addition to the compressor.
  • the conventional approach results in a much larger increase in cost to supply the same capacity as the present invention at high ambient temperatures.

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  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Fluid Mechanics (AREA)
  • Structures Of Non-Positive Displacement Pumps (AREA)

Abstract

L'invention concerne une centrale électrique à capacité améliorée, à des températures ambiantes élevées, comprenant une turbine à gaz (32) adaptée à un générateur (26) dans des conditions de pointes estivales. La centrale comprend un système permettant de limiter une sortie de turbine à des températures ambiantes inférieures, de façon à empêcher la surcharge du générateur ou d'autres composants. Elle comprend également, de préférence, un dispositif de refroidissement (70) par évaporation destiné à refroidir l'air admis dans la turbine à gaz.
PCT/US2000/023973 1999-09-03 2000-09-01 Turbine a gaz fonctionnant a des temperatures ambiantes elevees WO2001018372A1 (fr)

Priority Applications (2)

Application Number Priority Date Filing Date Title
US10/070,247 US6718771B1 (en) 1999-09-03 2000-09-01 Gas turbine operative at high ambient temperatures
AU73402/00A AU7340200A (en) 1999-09-03 2000-09-01 Gas turbine operative at high ambient temperatures

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US15227799P 1999-09-03 1999-09-03
US60/152,277 1999-09-03

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WO2001018372A1 true WO2001018372A1 (fr) 2001-03-15

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EP1203866A2 (fr) * 2000-11-06 2002-05-08 General Electric Company Procédé et installation de régulation de l'alimentation de brouillard pour compresseur de turbine à gaz
CN102926875A (zh) * 2011-08-08 2013-02-13 通用电气公司 用于热环境的系统和方法以及用于燃气轮机的电网频率补偿
US9492780B2 (en) 2014-01-16 2016-11-15 Bha Altair, Llc Gas turbine inlet gas phase contaminant removal
US10502136B2 (en) 2014-10-06 2019-12-10 Bha Altair, Llc Filtration system for use in a gas turbine engine assembly and method of assembling thereof

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US2584232A (en) * 1946-09-04 1952-02-05 Rateau Soc Gas turbine power plant, including means to treat combustion products between successive stages of expansion
US3394265A (en) * 1965-12-15 1968-07-23 Gen Electric Spinning reserve with inlet throttling and compressor recirculation
US5353585A (en) * 1992-03-03 1994-10-11 Michael Munk Controlled fog injection for internal combustion system
US5675188A (en) * 1993-07-23 1997-10-07 Hitachi, Ltd. Adjustable speed gas turbine power generation apparatus and its operation method independent of ambient temperature
US5655373A (en) * 1994-09-28 1997-08-12 Kabushiki Kaisha Toshiba Gas turbine intake air cooling apparatus
US5669217A (en) * 1995-09-25 1997-09-23 Anderson; J. Hilbert Method and apparatus for intercooling gas turbines

Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP1203866A2 (fr) * 2000-11-06 2002-05-08 General Electric Company Procédé et installation de régulation de l'alimentation de brouillard pour compresseur de turbine à gaz
EP1203866A3 (fr) * 2000-11-06 2004-08-25 General Electric Company Procédé et installation de régulation de l'alimentation de brouillard pour compresseur de turbine à gaz
CN102926875A (zh) * 2011-08-08 2013-02-13 通用电气公司 用于热环境的系统和方法以及用于燃气轮机的电网频率补偿
US9492780B2 (en) 2014-01-16 2016-11-15 Bha Altair, Llc Gas turbine inlet gas phase contaminant removal
US10502136B2 (en) 2014-10-06 2019-12-10 Bha Altair, Llc Filtration system for use in a gas turbine engine assembly and method of assembling thereof

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