US20110232313A1 - Chiller Condensate System - Google Patents
Chiller Condensate System Download PDFInfo
- Publication number
- US20110232313A1 US20110232313A1 US12/730,334 US73033410A US2011232313A1 US 20110232313 A1 US20110232313 A1 US 20110232313A1 US 73033410 A US73033410 A US 73033410A US 2011232313 A1 US2011232313 A1 US 2011232313A1
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- Prior art keywords
- condensate
- chiller
- flow
- heat exchanger
- load
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Classifications
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F28—HEAT EXCHANGE IN GENERAL
- F28F—DETAILS OF HEAT-EXCHANGE AND HEAT-TRANSFER APPARATUS, OF GENERAL APPLICATION
- F28F17/00—Removing ice or water from heat-exchange apparatus
- F28F17/005—Means for draining condensates from heat exchangers, e.g. from evaporators
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- 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
- F01D25/12—Cooling
-
- 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
- F02C7/143—Cooling of plants of fluids in the plant, e.g. lubricant or fuel of working fluid before or between the compressor stages
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
- F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
- 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
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F28—HEAT EXCHANGE IN GENERAL
- F28C—HEAT-EXCHANGE APPARATUS, NOT PROVIDED FOR IN ANOTHER SUBCLASS, IN WHICH THE HEAT-EXCHANGE MEDIA COME INTO DIRECT CONTACT WITHOUT CHEMICAL INTERACTION
- F28C1/00—Direct-contact trickle coolers, e.g. cooling towers
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F28—HEAT EXCHANGE IN GENERAL
- F28C—HEAT-EXCHANGE APPARATUS, NOT PROVIDED FOR IN ANOTHER SUBCLASS, IN WHICH THE HEAT-EXCHANGE MEDIA COME INTO DIRECT CONTACT WITHOUT CHEMICAL INTERACTION
- F28C3/00—Other direct-contact heat-exchange apparatus
- F28C3/06—Other direct-contact heat-exchange apparatus the heat-exchange media being a liquid and a gas or vapour
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F28—HEAT EXCHANGE IN GENERAL
- F28D—HEAT-EXCHANGE APPARATUS, NOT PROVIDED FOR IN ANOTHER SUBCLASS, IN WHICH THE HEAT-EXCHANGE MEDIA DO NOT COME INTO DIRECT CONTACT
- F28D21/00—Heat-exchange apparatus not covered by any of the groups F28D1/00 - F28D20/00
- F28D21/0001—Recuperative heat exchangers
- F28D21/0012—Recuperative heat exchangers the heat being recuperated from waste water or from condensates
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- 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
- F05D2260/60—Fluid transfer
- F05D2260/602—Drainage
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- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02B—CLIMATE CHANGE MITIGATION TECHNOLOGIES RELATED TO BUILDINGS, e.g. HOUSING, HOUSE APPLIANCES OR RELATED END-USER APPLICATIONS
- Y02B30/00—Energy efficient heating, ventilation or air conditioning [HVAC]
- Y02B30/56—Heat recovery units
-
- 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
- Y02B—CLIMATE CHANGE MITIGATION TECHNOLOGIES RELATED TO BUILDINGS, e.g. HOUSING, HOUSE APPLIANCES OR RELATED END-USER APPLICATIONS
- Y02B30/00—Energy efficient heating, ventilation or air conditioning [HVAC]
- Y02B30/70—Efficient control or regulation technologies, e.g. for control of refrigerant flow, motor or heating
Definitions
- the present application relates generally to gas turbine engines and more particularly relates to a gas turbine engine with a chiller condensate system used for cooling purposes.
- the power output of a gas turbine engine is directly proportional to the inlet air mass flow rate.
- the inlet air mass depends upon the density of the inlet air and hence the temperature of the air.
- known gas turbine engines may use a chiller system to lower the air temperature about the compressor inlet. By lowering the inlet air temperature, the density of the inlet air may be increased and the mass flow rate to the compressor may increase. The power output of the gas turbine engine thus increases due to the higher mass flow rate.
- Chiller systems generally use a series of coils to cool the inlet air. Sensible heat transfer from the inlet air to the low temperature water circulating through the chiller coils cools the inlet air. During operation of the chiller, water tends to condense on the coils due to the cooling effect. The condensate is drained and collected so as to avoid carryover downstream and into the compressor. The condensate generally is discharged to the atmosphere or otherwise disposed. The temperature of the condensate may be around about fifty (50) to about sixty (60) degrees Fahrenheit (about ten (10) to about 15.6 degrees Celsius) although other temperatures may be used. If a typical chiller system is operating at full load, the volume of the condensate may be at about 75 gallons per minute (about 284 liters per minute). Other condensate volumes may be used.
- the present application thus provides a chiller condensate system.
- the chiller condensate system may include a chiller that produces a flow of condensate, a condensate drain system positioned about the chiller to collect the flow of condensate, and a heat exchanger in communication with the condensate drain system for the condensate to flow therethrough.
- the present application thus provides a chiller condensate system.
- the chiller condensate system may include a chiller that produces a flow of condensate, a condensate drain system positioned about the chiller to collect the flow of condensate, and a nozzle in communication with the condensate drain system for the condensate to spray therethrough.
- the present application further provides a cooling tower.
- the cooling tower may include a chiller condensate system with a nozzle to provide a spray of condensate and a closed cooling circuit.
- the spray of condensate may chill the closed cooling circuit.
- FIG. 1 is a schematic view of a gas turbine engine.
- FIG. 2 is a schematic view of a portion of chiller condensate system as is claimed herein with a condensate collection and drainage system.
- FIG. 3 is a schematic view of a condensate heat exchanger system.
- FIG. 4 is a schematic view of the condensate heat exchanger system used with an air conditioning system.
- FIG. 5 is a schematic view of the condensate heat exchanger system used with a steam turbine condenser.
- FIG. 6 is a schematic view of the condensate heat exchanger system used with a turbine compartment.
- FIG. 7 is a schematic view of the condensate heat exchanger system used with an exhaust frame and bearing cooling system.
- FIG. 8 a schematic view of the condensate heat exchanger system used with a nozzle cooling system.
- FIG. 9 a schematic view of a condensate spray system.
- FIG. 10 a schematic view of the condensate spray system used with a cooling tower.
- FIG. 1 shows a schematic view of a gas turbine engine 100 .
- the gas turbine engine 100 may include a compressor 110 to compress an incoming flow of air.
- the compressor 110 delivers the compressed flow of air to a combustor 120 .
- the combustor 120 mixes the compressed flow of air with a compressed flow of fuel and ignites the mixture.
- the gas turbine engine 100 may include any number of combustors 120 .
- the hot combustion gases are in turn delivered to a turbine 130 .
- the hot combustion gases drive the turbine 130 so as to produce mechanical work.
- the mechanical work produced in the turbine 130 drives the compressor 110 and an external load 140 such as an electrical generator and the like.
- the gas turbine engine 100 may use natural gas, various types of syngas, and other types of fuels. Other gas turbine engine configurations may be used herein.
- the gas turbine engine 100 also may include a chiller system 150 .
- the chiller system 150 may be positioned about the inlet of the compressor 110 . As described above, the chiller system 150 chills an incoming airflow 160 to a desired temperature.
- Various types of chiller systems 150 are known.
- FIG. 2 shows an improved chiller system 170 as is described herein.
- the chiller system 170 may include a number of coils 180 . As described above, water flows through the coils 180 so as to chill the incoming airflow 160 .
- the chiller system 170 also may include a condensate drain system 190 .
- the condensate drain system may include a coil drain 200 positioned about each of the coils 180 .
- a flow of condensate 210 passes on to each coil drain 200 .
- the coil drain 200 may take the form of a trough or a similar structure to catch the condensate.
- the coil drains 200 may lead to a condensate pipe 220 or other type of central basin.
- the flow of condensate 210 may be at about 75 gallons per minute (about 284 liters per minute). Other condensate volumes may be used herein.
- FIG. 3 shows an example of a chiller condensate system 230 as is claimed herein.
- the chiller condensate system 230 may be in the form of a condensate heat exchange system 235 .
- the condensate heat exchange system 235 includes the chiller system 170 with the condensate drain system 190 .
- the flow of condensate 210 from the coil drains 200 is forwarded to a heat exchanger 240 by the condensate pipe 220 .
- the heat exchanger 240 may be any type of heat exchange device including shell and tube heat exchangers, plate heat exchangers, plate and fin heat exchangers, air coils, direct contact, adiabatic heat exchangers, etc.
- the heat exchanger 240 exchanges heat with any type of load 245 such as an airflow, a turbine component, or other structure in a manner similar to those examples described below.
- a pump 250 may be positioned about the condensate pipe 220 . The flow of condensate 210 may then flow to additional heat exchangers 240 , discharged, or otherwise used.
- FIG. 4 shows use of the condensate heat exchanger system 235 with an example of a load 245 , an air conditioning system 260 .
- the heat exchanger 240 of the condensate heat exchanger system 235 may be positioned about a fan 270 or other type of air movement device of the air conditioning system 260 .
- the heat exchanger 240 may cool an air conditioning flow 280 therethrough.
- the condensate heat exchanger system 235 thus uses the flow of condensate 210 to provide cooling in the form of air conditioning.
- the use of the condensate heat exchanger system 235 thus reduces the need for externally generated chilled water that may be used exclusively for air conditioning purposes.
- Other air conditioning configurations and systems may be used herein.
- FIG. 5 shows the use of the condensate heat exchanger system 235 with a steam turbine condenser 290 .
- the heat exchanger 240 thus may take the form of tubes or other types of pathways through the condenser 290 .
- a vacuum is maintained in the steam turbine condenser 290 by expanding a flow of steam passing through a steam pathway 300 therein.
- the expansion may maintain the vacuum.
- the back pressure in the condenser 290 may be reduced. With lower back pressure, the steam may expand to a lower temperature and thus provide more output.
- the flow of condensate 210 also may be added to an existing ambient flow through the condenser 290 .
- Other steam turbine condenser configurations and other structures may be used herein.
- FIG. 6 shows the use of the condensate heat exchanger system 235 with a turbine compartment 310 .
- the turbine compartment 310 may be an enclosure of any shape with turbine equipment therein. Heat from the turbine casing and other components may cause safety and lifetime issues for the equipment therein.
- the turbine compartment 310 thus may include a cooling air pathway 320 extending therethrough.
- the heat exchanger 240 of the condensate heat exchanger system 235 may be positioned about the cooling air pathway 320 or otherwise to chill an incoming flow of air 325 along the cooling air pathway 320 . Alternatively, the heat exchanger 240 may be positioned about any of the specific pieces of equipment therein.
- Other turbine compartment configurations may be used herein.
- FIG. 7 shows use of the condensate heat exchanger system 235 with an exhaust frame and bearing system 330 .
- the exhaust frame and bearing system 330 may include a bearing housing 340 supporting a rotor 350 .
- the bearing housing 340 may be positioned within an exhaust frame 360 with a hot gas path 370 extending therethrough.
- the exhaust frame and bearing system 330 also may include a cooling air pathway 380 extending therethrough to cool the bearing housing 340 and the exhaust frame 360 with an incoming flow of air 385 .
- the heat exchanger 240 of the condenser heat exchanger system 235 may be positioned about the cooling air pathway 380 to cool the incoming airflow 385 . Further, the heat exchanger 240 may be positioned elsewhere within the exhaust frame and bearing system 330 . Cooling may increase the lifespan of the bearing housing 340 , the exhaust frame 360 , and the other components therein. Other exhaust frame and bearing system configurations may be used herein.
- FIG. 8 shows the use of the condensate heat exchanger system 235 with a nozzle cooling system 390 .
- Air extracted from, for example, a ninth stage 400 and the eleventh stage 410 of the compressor 110 may be used to cool a stage three nozzle 420 and a stage two nozzle 430 of the turbine 130 via a number of extraction lines 440 .
- the heat exchanger 240 of the condensate heat exchanger system 235 may be positioned about the extraction lines 440 so as to cool an air extraction 450 therein. Better cooling of the nozzles 420 , 430 thus may increase component lifetime.
- the heat exchanger 240 also may be positioned elsewhere about the nozzle cooling system 390 .
- other types of extractions may be used.
- Other types of nozzle cooling configurations also may be used herein.
- the chiller condensate system 230 also may be used with a fuel moisturizer 455 .
- Fuel moisturization systems have been used in combined cycle power plants in an attempt to increase power output and thermodynamic efficiency. In such systems, natural gas is saturated with water and the moisturized fuel is heated to saturation conditions at the design gas pressure. The increased gas mass flow due to the addition of moisture may result in increased power output from gas and steam turbines.
- the flow of condensate 210 may be directed to the saturator 455 to saturate a flow of fuel therein.
- the flow of condensate 210 may flow directly to the saturator 445 , exchange heat with the heat exchanger 240 , or otherwise be warmed. Such moisturization may improve the overall efficiency of the gas turbine engine 100 .
- the pump 250 also may be used herein.
- FIG. 9 shows a further example of the chiller condensate system 230 .
- the chiller condensate system 230 may be in the form of a condensate spray system 460 as may be described herein.
- the condensate spray system 460 may include one or more spray nozzles 470 so as to provide a spray 480 of the condensate 210 for cooling purposes to a load 490 in a manner similar to the heat exchanger 240 .
- the spray nozzles 470 may be any type of device that provides the spray 480 in any form.
- the spray 480 may take the form of a mist, a stream, or any type of output.
- the spray nozzles 470 also may be positioned downstream of the heat exchanger 240 for use therewith. Other positions and components may be used herein.
- the pump 250 also may be used herein.
- FIG. 10 shows the use of the condensate spray system 460 with a cooling tower 500 .
- the cooling tower 500 may include a water tube bundle 510 extending therethrough. (Although only one water tube is shown herein, the water tube bundle 510 may have any number of tubes.)
- the water tube bundle 510 may be part of a closed cooling circuit 520 .
- the closed cooling circuit 520 may include one or more heat exchangers 530 . Any type of heat exchanger or heat exchange device may be used herein.
- the water tube bundle 510 may be cooled by an incoming airflow 540 drawn in by a number of fans 550 or other types of air movement devices positioned within the cooling tower 500 .
- One or more nozzles 470 of the condensate spray system 460 may be positioned about the airflow 540 so as to provide the spray 480 to the airflow 540 . Cooling the airflow 540 with the spray 480 of the condensate 210 may further cool the water tube bundle 510 . As such, the overall operation of the heat exchanger 530 and the closed cooling circuit 520 may be improved.
- the heat exchanger 530 of the closed cooling circuit 520 may be used to cool any type of further load 560 such as a fluid flow, a component, and the like.
- the heat exchanger 530 may be a lube oil heat exchanger, a generator heat exchanger or cooler, a steam condenser, or any type of component for heat exchange therewith.
- Better cooling of the lube oil may increase the lube oil life and varnishing may be avoided.
- additional cooling for the generator may raise the efficiency of the generator.
- better cooling of the condenser may increase output due to better expansion of the steam. Other benefits of additional (and free) cooling may be found herein.
- the condensate heat exchanger system 235 and/or the condensate spray system 460 of the chiller condensate system 230 thus may be used to cool any component within the gas turbine engine 100 as well as related components such as power plant air conditioning and other types of loads 245 . Such cooling provided by otherwise discarded condensate thus serves to improve the overall efficiency of the gas turbine engine system 100 .
Abstract
The present application provides a chiller condensate system. The chiller condensate system may include a chiller that produces a flow of condensate, a condensate drain system positioned about the chiller to collect the flow of condensate, and a heat exchanger in communication with the condensate drain system for the flow of condensate to flow therethrough.
Description
- The present application relates generally to gas turbine engines and more particularly relates to a gas turbine engine with a chiller condensate system used for cooling purposes.
- The power output of a gas turbine engine is directly proportional to the inlet air mass flow rate. The inlet air mass depends upon the density of the inlet air and hence the temperature of the air. As such, known gas turbine engines may use a chiller system to lower the air temperature about the compressor inlet. By lowering the inlet air temperature, the density of the inlet air may be increased and the mass flow rate to the compressor may increase. The power output of the gas turbine engine thus increases due to the higher mass flow rate.
- Chiller systems generally use a series of coils to cool the inlet air. Sensible heat transfer from the inlet air to the low temperature water circulating through the chiller coils cools the inlet air. During operation of the chiller, water tends to condense on the coils due to the cooling effect. The condensate is drained and collected so as to avoid carryover downstream and into the compressor. The condensate generally is discharged to the atmosphere or otherwise disposed. The temperature of the condensate may be around about fifty (50) to about sixty (60) degrees Fahrenheit (about ten (10) to about 15.6 degrees Celsius) although other temperatures may be used. If a typical chiller system is operating at full load, the volume of the condensate may be at about 75 gallons per minute (about 284 liters per minute). Other condensate volumes may be used.
- There is therefore a desire to obtain useful work from this existing condensate flow. Specifically, the use of existing condensate may improve the overall efficiency of the gas turbine engine and related equipment while still providing adequate inlet air cooling.
- The present application thus provides a chiller condensate system. The chiller condensate system may include a chiller that produces a flow of condensate, a condensate drain system positioned about the chiller to collect the flow of condensate, and a heat exchanger in communication with the condensate drain system for the condensate to flow therethrough.
- The present application thus provides a chiller condensate system. The chiller condensate system may include a chiller that produces a flow of condensate, a condensate drain system positioned about the chiller to collect the flow of condensate, and a nozzle in communication with the condensate drain system for the condensate to spray therethrough.
- The present application further provides a cooling tower. The cooling tower may include a chiller condensate system with a nozzle to provide a spray of condensate and a closed cooling circuit. The spray of condensate may chill the closed cooling circuit.
- These and other features and improvement of the present application will become apparent to one of ordinary skill in the art upon review of the following detailed description when taken in conjunction with the several drawings and the appended claims.
-
FIG. 1 is a schematic view of a gas turbine engine. -
FIG. 2 is a schematic view of a portion of chiller condensate system as is claimed herein with a condensate collection and drainage system. -
FIG. 3 is a schematic view of a condensate heat exchanger system. -
FIG. 4 is a schematic view of the condensate heat exchanger system used with an air conditioning system. -
FIG. 5 is a schematic view of the condensate heat exchanger system used with a steam turbine condenser. -
FIG. 6 is a schematic view of the condensate heat exchanger system used with a turbine compartment. -
FIG. 7 is a schematic view of the condensate heat exchanger system used with an exhaust frame and bearing cooling system. -
FIG. 8 a schematic view of the condensate heat exchanger system used with a nozzle cooling system. -
FIG. 9 a schematic view of a condensate spray system. -
FIG. 10 a schematic view of the condensate spray system used with a cooling tower. - Referring now to the drawings, in which like numerals refer to like elements throughout the several views,
FIG. 1 shows a schematic view of agas turbine engine 100. As is known, thegas turbine engine 100 may include acompressor 110 to compress an incoming flow of air. Thecompressor 110 delivers the compressed flow of air to acombustor 120. Thecombustor 120 mixes the compressed flow of air with a compressed flow of fuel and ignites the mixture. Although only asingle combustor 120 is shown, thegas turbine engine 100 may include any number ofcombustors 120. The hot combustion gases are in turn delivered to aturbine 130. The hot combustion gases drive theturbine 130 so as to produce mechanical work. The mechanical work produced in theturbine 130 drives thecompressor 110 and anexternal load 140 such as an electrical generator and the like. Thegas turbine engine 100 may use natural gas, various types of syngas, and other types of fuels. Other gas turbine engine configurations may be used herein. - The
gas turbine engine 100 also may include achiller system 150. Thechiller system 150 may be positioned about the inlet of thecompressor 110. As described above, thechiller system 150 chills anincoming airflow 160 to a desired temperature. Various types ofchiller systems 150 are known. -
FIG. 2 shows an improvedchiller system 170 as is described herein. Thechiller system 170 may include a number ofcoils 180. As described above, water flows through thecoils 180 so as to chill theincoming airflow 160. Thechiller system 170 also may include acondensate drain system 190. The condensate drain system may include acoil drain 200 positioned about each of thecoils 180. A flow ofcondensate 210 passes on to eachcoil drain 200. Thecoil drain 200 may take the form of a trough or a similar structure to catch the condensate. Thecoil drains 200 may lead to acondensate pipe 220 or other type of central basin. As described above, the flow ofcondensate 210 may be at about 75 gallons per minute (about 284 liters per minute). Other condensate volumes may be used herein. -
FIG. 3 shows an example of achiller condensate system 230 as is claimed herein. In this example, thechiller condensate system 230 may be in the form of a condensateheat exchange system 235. Specifically, the condensateheat exchange system 235 includes thechiller system 170 with thecondensate drain system 190. The flow ofcondensate 210 from the coil drains 200 is forwarded to aheat exchanger 240 by thecondensate pipe 220. Theheat exchanger 240 may be any type of heat exchange device including shell and tube heat exchangers, plate heat exchangers, plate and fin heat exchangers, air coils, direct contact, adiabatic heat exchangers, etc. Theheat exchanger 240 exchanges heat with any type ofload 245 such as an airflow, a turbine component, or other structure in a manner similar to those examples described below. Apump 250 may be positioned about thecondensate pipe 220. The flow ofcondensate 210 may then flow toadditional heat exchangers 240, discharged, or otherwise used. -
FIG. 4 shows use of the condensateheat exchanger system 235 with an example of aload 245, anair conditioning system 260. Specifically, theheat exchanger 240 of the condensateheat exchanger system 235 may be positioned about afan 270 or other type of air movement device of theair conditioning system 260. Theheat exchanger 240 may cool anair conditioning flow 280 therethrough. The condensateheat exchanger system 235 thus uses the flow ofcondensate 210 to provide cooling in the form of air conditioning. Moreover, the use of the condensateheat exchanger system 235 thus reduces the need for externally generated chilled water that may be used exclusively for air conditioning purposes. Other air conditioning configurations and systems may be used herein. -
FIG. 5 shows the use of the condensateheat exchanger system 235 with asteam turbine condenser 290. Theheat exchanger 240 thus may take the form of tubes or other types of pathways through thecondenser 290. Generally described, a vacuum is maintained in thesteam turbine condenser 290 by expanding a flow of steam passing through asteam pathway 300 therein. By reducing the temperature inside thecondenser 290 via theheat exchanger 240, the expansion may maintain the vacuum. As such, the back pressure in thecondenser 290 may be reduced. With lower back pressure, the steam may expand to a lower temperature and thus provide more output. The flow ofcondensate 210 also may be added to an existing ambient flow through thecondenser 290. Other steam turbine condenser configurations and other structures may be used herein. -
FIG. 6 shows the use of the condensateheat exchanger system 235 with aturbine compartment 310. Theturbine compartment 310 may be an enclosure of any shape with turbine equipment therein. Heat from the turbine casing and other components may cause safety and lifetime issues for the equipment therein. Theturbine compartment 310 thus may include a coolingair pathway 320 extending therethrough. Theheat exchanger 240 of the condensateheat exchanger system 235 may be positioned about the coolingair pathway 320 or otherwise to chill an incoming flow ofair 325 along the coolingair pathway 320. Alternatively, theheat exchanger 240 may be positioned about any of the specific pieces of equipment therein. Other turbine compartment configurations may be used herein. -
FIG. 7 shows use of the condensateheat exchanger system 235 with an exhaust frame andbearing system 330. The exhaust frame andbearing system 330 may include a bearinghousing 340 supporting arotor 350. The bearinghousing 340 may be positioned within anexhaust frame 360 with ahot gas path 370 extending therethrough. The exhaust frame andbearing system 330 also may include a cooling air pathway 380 extending therethrough to cool the bearinghousing 340 and theexhaust frame 360 with an incoming flow ofair 385. Theheat exchanger 240 of the condenserheat exchanger system 235 may be positioned about the cooling air pathway 380 to cool theincoming airflow 385. Further, theheat exchanger 240 may be positioned elsewhere within the exhaust frame andbearing system 330. Cooling may increase the lifespan of the bearinghousing 340, theexhaust frame 360, and the other components therein. Other exhaust frame and bearing system configurations may be used herein. -
FIG. 8 shows the use of the condensateheat exchanger system 235 with anozzle cooling system 390. Air extracted from, for example, a ninth stage 400 and theeleventh stage 410 of thecompressor 110 may be used to cool a stage threenozzle 420 and a stage twonozzle 430 of theturbine 130 via a number ofextraction lines 440. Theheat exchanger 240 of the condensateheat exchanger system 235 may be positioned about theextraction lines 440 so as to cool anair extraction 450 therein. Better cooling of thenozzles heat exchanger 240 also may be positioned elsewhere about thenozzle cooling system 390. Likewise, other types of extractions may be used. Other types of nozzle cooling configurations also may be used herein. - Referring again to
FIG. 3 , thechiller condensate system 230 also may be used with afuel moisturizer 455. Fuel moisturization systems have been used in combined cycle power plants in an attempt to increase power output and thermodynamic efficiency. In such systems, natural gas is saturated with water and the moisturized fuel is heated to saturation conditions at the design gas pressure. The increased gas mass flow due to the addition of moisture may result in increased power output from gas and steam turbines. In this example, the flow ofcondensate 210 may be directed to thesaturator 455 to saturate a flow of fuel therein. The flow ofcondensate 210 may flow directly to the saturator 445, exchange heat with theheat exchanger 240, or otherwise be warmed. Such moisturization may improve the overall efficiency of thegas turbine engine 100. Thepump 250 also may be used herein. -
FIG. 9 shows a further example of thechiller condensate system 230. Thechiller condensate system 230 may be in the form of acondensate spray system 460 as may be described herein. Thecondensate spray system 460 may include one ormore spray nozzles 470 so as to provide aspray 480 of thecondensate 210 for cooling purposes to aload 490 in a manner similar to theheat exchanger 240. Thespray nozzles 470 may be any type of device that provides thespray 480 in any form. For example, thespray 480 may take the form of a mist, a stream, or any type of output. Thespray nozzles 470 also may be positioned downstream of theheat exchanger 240 for use therewith. Other positions and components may be used herein. Thepump 250 also may be used herein. -
FIG. 10 shows the use of thecondensate spray system 460 with acooling tower 500. Thecooling tower 500 may include awater tube bundle 510 extending therethrough. (Although only one water tube is shown herein, thewater tube bundle 510 may have any number of tubes.) Thewater tube bundle 510 may be part of aclosed cooling circuit 520. Theclosed cooling circuit 520 may include one ormore heat exchangers 530. Any type of heat exchanger or heat exchange device may be used herein. - The
water tube bundle 510 may be cooled by anincoming airflow 540 drawn in by a number offans 550 or other types of air movement devices positioned within thecooling tower 500. One ormore nozzles 470 of thecondensate spray system 460 may be positioned about theairflow 540 so as to provide thespray 480 to theairflow 540. Cooling theairflow 540 with thespray 480 of thecondensate 210 may further cool thewater tube bundle 510. As such, the overall operation of theheat exchanger 530 and theclosed cooling circuit 520 may be improved. - The
heat exchanger 530 of theclosed cooling circuit 520 may be used to cool any type offurther load 560 such as a fluid flow, a component, and the like. For example, theheat exchanger 530 may be a lube oil heat exchanger, a generator heat exchanger or cooler, a steam condenser, or any type of component for heat exchange therewith. Better cooling of the lube oil may increase the lube oil life and varnishing may be avoided. Likewise, additional cooling for the generator may raise the efficiency of the generator. Similarly, better cooling of the condenser may increase output due to better expansion of the steam. Other benefits of additional (and free) cooling may be found herein. - In summary, the condensate
heat exchanger system 235 and/or thecondensate spray system 460 of thechiller condensate system 230 thus may be used to cool any component within thegas turbine engine 100 as well as related components such as power plant air conditioning and other types ofloads 245. Such cooling provided by otherwise discarded condensate thus serves to improve the overall efficiency of the gasturbine engine system 100. - It should be apparent that the foregoing relates only to certain embodiments of the present application and that numerous changes and modifications may be made herein by one of ordinary skill in the art without departing from the general spirit and scope of the invention as defined by the following claims and the equivalents thereof.
Claims (20)
1. A chiller condensate system, comprising:
a chiller;
wherein the chiller produces a flow of condensate;
a condensate drain system positioned about the chiller to collect the flow of condensate; and
a heat exchanger in communication with the condensate drain system for the condensate to flow therethrough.
2. The chiller condensate system of claim 1 , wherein the chiller comprises a plurality of coils.
3. The chiller condensate system of claim 1 , wherein the condensate drain system comprises a plurality of coil drains and a condensate pipe.
4. The chiller condensate system of claim 1 , further comprising a pump in communication with the condensate drain system.
5. The chiller condensate system of claim 1 , further comprising a load in communication with the heat exchanger.
6. The chiller condensate system of claim 5 , wherein the load comprises an air conditioning system.
7. The chiller condensate system of claim 5 , wherein the load comprises a condenser.
8. The chiller condensate system of claim 5 , wherein the load comprises a turbine compartment.
9. The chiller condensate system of claim 5 , wherein the load comprises an exhaust frame and bearing system.
10. The chiller condensate system of claim 5 , wherein the load comprises a nozzle cooling system.
11. The chiller condensate system of claim 5 , wherein the heat exchanger comprises a spray nozzle.
12. The chiller condensate system of claim 11 , wherein the load comprises a closed cooling circuit.
13. The chiller condensate system of claim 12 , wherein the closed cooling circuit is in communication with a further load.
14. The chiller condensate system of claim 5 , wherein the load comprises a flow of air.
15. The chiller condensate system of claim 5 , wherein the load comprises a flow of steam.
16. The chiller condensate system of claim 5 , wherein the load comprises a flow of fluid.
17. The chiller condensate system of claim 1 , further comprising a moisturizer.
18. A chiller condensate system, comprising:
a chiller;
wherein the chiller produces a flow of condensate;
a condensate drain system positioned about the chiller to collect the flow of condensate; and
a nozzle in communication with the condensate drain system for the condensate to spray therethrough.
19. The chiller condensate system of claim 18 , further comprising a load in communication with the nozzle.
20. A cooling tower, comprising:
a chiller condensate system;
wherein the chiller condensate system comprises a nozzle to provide a spray of condensate; and
a closed cooling circuit;
wherein the spray of condensate chills the closed cooling circuit.
Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/730,334 US20110232313A1 (en) | 2010-03-24 | 2010-03-24 | Chiller Condensate System |
EP11159010.5A EP2375207A3 (en) | 2010-03-24 | 2011-03-21 | Chiller condensate system |
JP2011062673A JP2011202657A (en) | 2010-03-24 | 2011-03-22 | Chiller condensate system |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/730,334 US20110232313A1 (en) | 2010-03-24 | 2010-03-24 | Chiller Condensate System |
Publications (1)
Publication Number | Publication Date |
---|---|
US20110232313A1 true US20110232313A1 (en) | 2011-09-29 |
Family
ID=44484110
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US12/730,334 Abandoned US20110232313A1 (en) | 2010-03-24 | 2010-03-24 | Chiller Condensate System |
Country Status (3)
Country | Link |
---|---|
US (1) | US20110232313A1 (en) |
EP (1) | EP2375207A3 (en) |
JP (1) | JP2011202657A (en) |
Cited By (7)
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CN103321879A (en) * | 2012-03-22 | 2013-09-25 | 简明堃 | Gas supply device |
US20140123623A1 (en) * | 2012-11-08 | 2014-05-08 | General Electric Company | Gas turbomachine system including an inlet chiller condensate recovery system |
WO2015066837A1 (en) * | 2013-11-05 | 2015-05-14 | General Electric Company | Gas turbine inlet air conditioning coil system |
US20150240717A1 (en) * | 2012-10-16 | 2015-08-27 | Loren K. Starcher | Increasing Combustibility of Low BTU Natural Gas |
US20170175638A1 (en) * | 2015-12-22 | 2017-06-22 | General Electric Company | False start drain system with vertical header |
US10443898B2 (en) | 2016-10-28 | 2019-10-15 | Ingersoll-Rand Company | Air compressor system including a refrigerated dryer and a condensate harvester and water supply |
CN117288000A (en) * | 2023-11-22 | 2023-12-26 | 山东华科环境科技有限公司 | Water-saving cooling tower water mist recovery device |
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Also Published As
Publication number | Publication date |
---|---|
JP2011202657A (en) | 2011-10-13 |
EP2375207A2 (en) | 2011-10-12 |
EP2375207A3 (en) | 2014-02-26 |
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