US20120096864A1 - Air cooled condenser fogging control system - Google Patents

Air cooled condenser fogging control system Download PDF

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Publication number
US20120096864A1
US20120096864A1 US12/911,811 US91181110A US2012096864A1 US 20120096864 A1 US20120096864 A1 US 20120096864A1 US 91181110 A US91181110 A US 91181110A US 2012096864 A1 US2012096864 A1 US 2012096864A1
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Prior art keywords
cells
steam
coolant
selectively
towards
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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.)
Abandoned
Application number
US12/911,811
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English (en)
Inventor
Rahul J. Chillar
Gregory Diantonio
David Rogers
Erwing Calleros
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General Electric Co
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General Electric Co
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 General Electric Co filed Critical General Electric Co
Priority to US12/911,811 priority Critical patent/US20120096864A1/en
Assigned to GENERAL ELECTRIC COMPANY reassignment GENERAL ELECTRIC COMPANY ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: Diantonio, Gregory, CALLEROS, ERWING, CHILLAR, RAHUL J., ROGERS, DAVID
Priority to EP11186012A priority patent/EP2447480A2/en
Priority to CN2011103559165A priority patent/CN102454483A/zh
Publication of US20120096864A1 publication Critical patent/US20120096864A1/en
Abandoned legal-status Critical Current

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    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
    • F01K13/00—General layout or general methods of operation of complete plants
    • F01K13/02—Controlling, e.g. stopping or starting
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
    • F01K23/00—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids
    • F01K23/02—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled
    • F01K23/06—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
    • 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
    • F01K9/00—Plants characterised by condensers arranged or modified to co-operate with the engines
    • F01K9/003—Plants characterised by condensers arranged or modified to co-operate with the engines condenser cooling circuits
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22B—METHODS OF STEAM GENERATION; STEAM BOILERS
    • F22B1/00—Methods of steam generation characterised by form of heating method
    • F22B1/02—Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers
    • F22B1/18—Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers the heat carrier being a hot gas, e.g. waste gas such as exhaust gas of internal-combustion engines
    • F22B1/1807—Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers the heat carrier being a hot gas, e.g. waste gas such as exhaust gas of internal-combustion engines using the exhaust gases of combustion engines
    • F22B1/1815—Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers the heat carrier being a hot gas, e.g. waste gas such as exhaust gas of internal-combustion engines using the exhaust gases of combustion engines using the exhaust gases of gas-turbines

Definitions

  • This invention generally relates to gas turbines, and more particularly relates to controlling turbine steam output.
  • Typical industrial gas turbine systems utilize heat recovery steam generators (HRSG) to recover energy that may otherwise be wasted as heat.
  • HRSG heat recovery steam generators
  • hot exhaust gases produced by the gas turbine can be directed to the HRSG, where the exhaust heat converts water into steam.
  • the steam in turn, can be used to drive a steam turbine to produce additional usable power, such as electrical power.
  • condensers can be used to cool the steam and return it to a liquid state for use again by the HRSG. Removing heat from the steam quickly helps reduce backpressure in the downstream steam path of the turbine, and increases the efficiency of the system.
  • Condensers can include a number of cooling tubes and/or fin tube bundles that act as heat exchangers for the steam.
  • Ambient air, forced air, or water-cooled condensers are typically used to reduce the steam temperature. For example, when cool air or water is forced across the fin tubes, heat is exchanged from the hot steam inside the condensers to the external air or water.
  • forced-air condensers require extra energy for fans to blow air across the cooling fin tubes.
  • Certain embodiments of the invention may include systems, methods, and apparatus for controlling turbine steam output.
  • a method for controlling steam turbine output.
  • the method can include measuring one or more temperatures or back pressures associated with one or more cells associated with a turbine cooling condenser, and controlling temperature distribution of the or more cells in response, at least in part, to the measured one or more temperatures or back pressures.
  • a system for controlling steam turbine output.
  • the system may include a heat recovery steam generator, a steam turbine associated with the heat recovery steam generator, and one or more condensers associated with the steam turbine.
  • the one or more condensers may include one or more cells.
  • the system may also include one or more sensors for measuring one or more temperature or back pressures of one or more cells, one or more valves for directing steam to the one or more cells, one or more nozzles for introducing coolant towards the one or more cells, one or more fans for forcing air and coolant past and around the one or more cells, and at least one processor configured to execute computer-executable instructions for controlling temperature distribution of the or more cells in response, at least in part, to the to the measured one or more temperatures or back pressures.
  • an apparatus for controlling steam turbine output.
  • the apparatus may include one or more condensers associated with the steam turbine.
  • the one or more condensers may include one or more cells.
  • the apparatus may also include one or more sensors for measuring one or more temperatures or back pressures of one or more cells.
  • the apparatus may also include one or more valves for directing steam to the one or more cells; one or more nozzles for introducing coolant towards the one or more cells; one or more fans for forcing air and coolant towards the one or more cells; and at least one processor configured to execute computer-executable instructions for controlling temperature distribution of the or more cells in response, at least in part, to the measured one or more temperatures or back pressures.
  • FIG. 1 is a block diagram of an illustrative turbine and cooling system, according to an example embodiment of the invention.
  • FIG. 2 depicts an illustrative condenser cooling system, according to an example embodiment of the invention.
  • FIG. 3 is a block diagram of an illustrative cooling control system, according to an example embodiment of the invention.
  • FIG. 4 is a block diagram of an illustrative cooling system, according to an example embodiment of the invention.
  • FIG. 5 is a block diagram of an illustrative cooling system with an alternate header arrangement, according to an example embodiment of the invention.
  • FIG. 6 is a block diagram of an illustrative cooling system with dual cooling path configuration, according to an example embodiment of the invention.
  • FIG. 7 is a flow diagram of an example method according to an example embodiment of the invention.
  • Certain embodiments of the invention may enable steam output associated with a heat recovery steam generator to be controlled.
  • forced air and/or fogging coolant may be directed to condenser banks and selectively activated to control a temperature distribution of the condenser cooling system.
  • FIG. 1 depicts a turbine and cooling system 100 , according to an example embodiment of the invention.
  • fuel 102 may be combusted to power a turbine 104 .
  • Part of the rotational energy produced by the turbine 104 may be utilized, at least in part, to drive a compressor 106 and a generator 108 .
  • electricity from the generator 108 may be supplied to a power grid 112 via a transformer 110 .
  • the generator 108 may be cooled by a cooling skid 114 .
  • an additional cooling skid 116 may be utilized to cool lube oil associated with the turbine 104 and the compressor 106 .
  • hot exhaust gas 118 from the turbine 104 may be directed to a heat recovery steam generator (HRSG) 120 and steam turbine 122 to extract and convert the heat energy from the exhaust to rotational energy that can be utilized to drive an additional generator, for example.
  • cooling water 140 may be converted to steam via the HRSG 120 , and the resulting steam pressure may be harnessed to drive the steam turbine 122 .
  • a condenser 126 may be utilized to cool and condense the low quality steam 124 to help reduce the backpressure from the steam turbine 122 .
  • the turbine and cooling system 100 may include supporting structures, steam ducting from the steam turbine interface, auxiliaries such as the condensate and drain pumps, condensate and duct drain tanks, air evacuation units, and related piping works and instrumentation.
  • spraying water mist or fogging 134 towards and around the condensers 126 may reduce the ambient air temperature via an evaporation process.
  • the lower ambient air temperature may lower the temperature of the air stream.
  • Such a reduction in temperature of air may internally lower the temperature of the water and steam flowing in the cooling tubes via heat exchange as the cooler air blows across the air-cooled condenser cooling tubes.
  • one or more condensers 126 sections may be selectively cooled via fogging skids 126 .
  • the fogging skids 126 may include pumps and fans.
  • one or more condenser 126 regions, zones, or sections may be selectively cooled with ambient or forced air 132 .
  • the one or more condensers 126 may be selectively cooled with fogging 134 in addition to the ambient or forced air 132 .
  • fogging coolant may include aerosolized water that is sprayed through fogging nozzles or nozzle arrays.
  • the heat from the condenser 126 may be exchanged with the ambient or forced air 132 with fogging 134 resulting in heat 136 being released from the condenser 126 and the low quality team 124 condensing to water 140 for recycling through the HRSG 120 .
  • a fogging spray pattern may be optimized for maximizing cooling impact on the condenser.
  • a fogging spray pattern may be optimized for minimizing water usage.
  • the wind direction may be monitored and used to control the fogging spray nozzle array 130 to minimize wastage of water and maximize cooling.
  • forced air and/or the fogging spray pattern 134 may be based on localized temperature readings from the cooling tower condensate tubes. For example, tubes that run hotter may receive greater percentages of forced air and/or spray of water.
  • coolant such as water
  • the forced air fan speeds may be controlled or adjusted by zone.
  • the flow of steam may be selectively directed through certain condenser banks and cooled as needed to reduce the parasitic load of the fans and/or to conserve fogging water.
  • FIG. 2 depicts a plan view of a condenser cooling system 200 , according to an example embodiment of the invention.
  • steam 202 may enter the condenser piping 206 and may be directed to cooling cells 207 .
  • the steam from the turbine 202 may be selectively directed towards certain cooling cell banks or rows by one or more valves 214 .
  • the valves 214 may control the flow of the steam to banks or rows of cooling cells 207 , and the steam may flow through the individual condenser piping 206 .
  • the cooling cells 207 may include fans and condensers 212 .
  • the condenser piping 206 may direct the steam 202 to condensers 212 , where cooling air and/or fogging coolant may be utilized to exchange heat with the steam to condense it to a liquid. The liquid may then be recycled via a condenser return to a hot well 204 .
  • the condenser cooling system 200 may include multiple condensers 212 and associated cooling cells 207 .
  • the various cooling cells 207 in the condenser cooling system 200 may have different temperatures, depending on factors such as wind direction, fan speed, coolant, humidity, nearby heat sources, etc. For example, certain cells may run cooler due to their proximity to the perimeter of the system.
  • FIG. 2 indicates a lower temperature cell 208 in the corner of the system 200 , a mid temperature cell 210 along a side of a row of cells, and example higher temperature cells 212 towards the middle of the system 200 .
  • many other temperature distributions may occur due to the factors mentioned above, and other factors.
  • steam 202 may be selectively directed to certain cells or rows of cells.
  • directing the steam 202 to certain rows of cells may allow maintenance or repair to be carried out in certain condenser cells, while other cells of the condenser cooling system 200 may still be operational.
  • directing the steam 202 to certain rows of cells may facilitate a more efficient cooling of the steam 202 . For example, if the HRSG is operating at less than full capacity, it may be more cost effective to activate only certain rows of condenser cells to reduce parasitic power, wear and tear on fans, and/or to conserve fogging coolant.
  • the temperature of the individual cooling cells 207 may be measured by one or more temperature sensors.
  • the operation of the condenser cooling system 200 may be based, at least in part, on the measured temperatures of the cooling cells.
  • the speed of individual cooling fans may be controlled based on the measured temperatures to direct more cool air towards the cells that need a higher level of heat transfer.
  • fogging spray may be selectively controlled based on measured cell temperature, wind direction, humidity etc. to further provide efficient and selective cooling of the cells 207 .
  • controlling the temperature distribution of the cooling cells 207 may include selectively directing steam through the one or more cells 207 .
  • controlling the temperature distribution may include selectively introducing coolant towards the one or more cells 207 such that heat from the steam is transferred by the one or more cells 207 to the coolant.
  • selectively introducing the coolant may include manipulating one or more nozzles (such as 130 in FIG. 1 ) in response to one or more of: temperature, humidity, back pressure, ambient wind direction, zonal temperature distribution, steam flow, parasitic load balance, or power demand.
  • controlling the temperature distribution of the one or more cooling cells 207 may include selectively forcing air towards the one or more cells 207 .
  • heat from the steam may be transferred from the one or more cells 207 to the forced air.
  • selectively forcing air may include selectively manipulating one or more fans in response to one or more of: temperature, humidity, backpressure, ambient wind direction, zonal temperature distribution, steam flow, parasitic load balance, or power demand.
  • cooling of the one or more cooling cells 207 may further include selectively introducing coolant towards the one or more condensers wherein heat from the steam may be transferred by the one or more cells ( 207 ) to one or more of the coolant, the forced air, or air-entrained coolant.
  • the steam turbine output may be controlled at least in part by measuring one or more temperature associated with the condensers cells, and/or by measuring the cooling air exit temperature from the air cooled condensers.
  • temperature may be measured at or near the steam header (condenser tube inlet) and at or near the exit condensate header (steam discharge) of a particular cell.
  • that particular cell may be sprayed with water or fogging coolant to increase the temperature differential.
  • an increase in vacuum and/or reduction in back pressure may result from the cooling of the cell.
  • vacuum and/or back pressure measurements may be utilized in place of, or in conjunction with temperature differential measurements to determine the appropriate action for directing fog coolant towards a particular condenser cell.
  • increasing the heat rejection capability of the condenser by spraying fogging coolant on the cell may facilitate conditions for creating more output from the steam turbine.
  • FIG. 3 depicts a cooling control system 300 , according to an example embodiment of the invention.
  • the cooling control system may include a controller 302 , which may include a memory 304 , one or more processors 306 , one or more input/output interfaces 308 , and/or one or more network interfaces 310 .
  • the memory 304 may include an operating system 312 , data 314 , and one or more control modules 318 .
  • the one or more control modules 318 may include specialized computer executable code for processing inputs, stored data 314 , and for directing certain data for output or control.
  • the cooling control system 300 may receive information from, send information to, and interact with various valves, pumps, and sensors 320 , the a turbine and steam system (such as 100 in FIG. 1 ), and a condenser cooling system (such as 200 in FIG. 2 ).
  • the controller may be utilized to receive temperature measurement data from the condenser cooling system (such as 200 in FIG. 2 ) and provide independent control for each condenser cell fan.
  • FIG. 4 depicts an end view example of a single condenser cell associated with a cooling system 400 for condensing steam 402 .
  • the steam may be supplied from a turbine supply header, for example.
  • the steam 402 may be directed through condenser tubes 404 for heat exchange with ambient air, forced air, and/or cooling water fogging.
  • the condenser tubes may include chilling fins for increased surface area and increased efficiency of the heat exchange. After the steam is cooled, it may condense and may return in the form of liquid to a hot well via well collection headers 406 .
  • the cooling air 408 may be drawn towards the cooling cell via a fan.
  • the fan may include a fan motor 410 and one or more blades 412 .
  • the fan may blow the cooling air 408 past and around the condenser tubes 404 to exchange heat from the steam within the condenser tubes 404 .
  • the exchanged heat may be carried away from the condenser cell via discharge air 416 .
  • FIGS. 4-6 depict example embodiments of cooling systems 400 , 500 , 600 that each represent different embodiments for placement of respective cooling water fogging headers 414 , 504 , 602 .
  • approximate fogging coolant paths 414 may be controlled, at least in part, by the placement of the fogging headers 414 .
  • the fogging header spray nozzle orientation may further allow control of the fogging coolant paths 114 .
  • FIG. 4 depicts an example cooling system 400 where the fogging headers 414 are placed approximately parallel with the condenser tubes 404 .
  • FIG. 5 depicts another example embodiment where the fogging headers 502 are placed approximately parallel with the plane of the fan blades.
  • the length of the approximate cooling fog path 504 may be longer for fog traveling towards the higher temperature portion of the condenser pipes and fins, and may provide additional cooling of the air prior to the heat exchange process.
  • FIG. 6 depicts another example embodiment where the fogging headers 602 may be placed in an arrangement that may facilitate one, two, or more interaction regions 608 between the fogging paths 604 and the condenser tubes and chilling fins 610 .
  • cooling may be enhanced by selectively directing the coolant towards the condenser tubes and chilling fins 610 of one or more cells, and in an opposing direction of the forced air such that at least a portion of the coolant removes heat from the one or more cells.
  • the fogging headers 602 may be placed on the outside of the condenser tube structures with the fogging nozzles directing fog towards the condenser tubes and chilling fins 610 .
  • the fog paths 604 may first encounter the condenser tubes and chilling fins 610 in an interaction region 608 , and then by the airflow 606 produced by the fan, may again encounter the condenser tubes and chilling fins 610 in another interaction region 608 .
  • Similar example embodiments may be utilized to increase the efficiency of the heat exchange process.
  • Other example configurations may be utilized without departing from the scope of the claimed inventions.
  • the method 700 starts in block 702 and includes measuring one or more temperatures or back pressures associated with one or more cells associated with a turbine cooling condenser.
  • the method 700 includes controlling temperature distribution of the one or more cells in response, at least in part, to the measured one or more temperatures or back pressures. The method 700 ends after block 704 .
  • example embodiments of the invention can provide the technical effects of providing enhanced control and cooling of condenser cells.
  • Example embodiments of the invention can provide the further technical effects of selectively cooling certain condenser cells based on temperature measurements of the cells.
  • the turbine and cooling system 100 , the cooling control system 300 , and the cooling systems 400 - 600 may include any number of hardware and/or software applications that are executed to facilitate any of the operations.
  • one or more I/O interfaces may facilitate communication between the turbine and cooling system 100 , the cooling control system 300 , and the cooling systems 400 - 600 and one or more input/output devices.
  • a universal serial bus port, a serial port, a disk drive, a CD-ROM drive, and/or one or more user interface devices such as a display, keyboard, keypad, mouse, control panel, touch screen display, microphone, etc.
  • the one or more I/O interfaces may be utilized to receive or collect data and/or user instructions from a wide variety of input devices. Received data may be processed by one or more computer processors as desired in various embodiments of the invention and/or stored in one or more memory devices.
  • One or more network interfaces may facilitate connection of the turbine and cooling system 100 , the cooling control system 300 , and the cooling systems 400 - 600 inputs and outputs to one or more suitable networks and/or connections.
  • the connections may facilitate communication with any number of sensors associated with the system.
  • the one or more network interfaces may further facilitate connection to one or more suitable networks; for example, a local area network, a wide area network, the Internet, a cellular network, a radio frequency network, a BluetoothTM (owned by Konaktiebolaget LM Ericsson) enabled network, a Wi-FiTM (owned by Wi-Fi Alliance) enabled network, a satellite-based network any wired network, any wireless network, etc., for communication with external devices and/or systems.
  • embodiments of the invention may include the turbine and cooling system 100 , the cooling control system 300 , and the cooling systems 400 - 600 with more or less of the components illustrated in FIGS. 1 , 3 , 4 , 5 , and 6 .
  • These computer-executable program instructions may be loaded onto a general-purpose computer, a special-purpose computer, a processor, or other programmable data processing apparatus to produce a particular machine, such that the instructions that execute on the computer, processor, or other programmable data processing apparatus create means for implementing one or more functions specified in the flow diagram block or blocks.
  • These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means that implement one or more functions specified in the flow diagram block or blocks.
  • embodiments of the invention may provide for a computer program product, comprising a computer-usable medium having a computer-readable program code or program instructions embodied therein, said computer-readable program code adapted to be executed to implement one or more functions specified in the flow diagram block or blocks.
  • the computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational elements or steps to be performed on the computer or other programmable apparatus to produce a computer-implemented process such that the instructions that execute on the computer or other programmable apparatus provide elements or steps for implementing the functions specified in the flow diagram block or blocks.
  • blocks of the block diagrams and flow diagrams support combinations of means for performing the specified functions, combinations of elements or steps for performing the specified functions and program instruction means for performing the specified functions. It will also be understood that each block of the block diagrams and flow diagrams, and combinations of blocks in the block diagrams and flow diagrams, can be implemented by special-purpose, hardware-based computer systems that perform the specified functions, elements or steps, or combinations of special-purpose hardware and computer instructions.

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  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Sustainable Development (AREA)
  • Sustainable Energy (AREA)
  • Physics & Mathematics (AREA)
  • Thermal Sciences (AREA)
  • Control Of Turbines (AREA)
  • Engine Equipment That Uses Special Cycles (AREA)
US12/911,811 2010-10-26 2010-10-26 Air cooled condenser fogging control system Abandoned US20120096864A1 (en)

Priority Applications (3)

Application Number Priority Date Filing Date Title
US12/911,811 US20120096864A1 (en) 2010-10-26 2010-10-26 Air cooled condenser fogging control system
EP11186012A EP2447480A2 (en) 2010-10-26 2011-10-20 Air cooled condenser fogging control system
CN2011103559165A CN102454483A (zh) 2010-10-26 2011-10-26 空气冷却式冷凝器雾化控制系统

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Application Number Priority Date Filing Date Title
US12/911,811 US20120096864A1 (en) 2010-10-26 2010-10-26 Air cooled condenser fogging control system

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US (1) US20120096864A1 (zh)
EP (1) EP2447480A2 (zh)
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US20140202151A1 (en) * 2013-01-21 2014-07-24 Alliance For Sustainable Energy, Llc Hybrid Air-Cooled Condenser For Power Plants and Other Applications
US20140223907A1 (en) * 2013-02-14 2014-08-14 Anest Iwata Corporation Power generating apparatus and method of operating power generating apparatus
US9540962B2 (en) 2014-07-14 2017-01-10 Siemens Energy, Inc. Power plant air cooled heat exchanger or condenser with pressurized gas entrained cooling liquid mister
EP3315735A1 (en) * 2016-10-05 2018-05-02 General Electric Company System for higher plant efficiency

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CN105652692B (zh) * 2016-03-23 2019-08-27 武汉理工大学 基于热发电的电厂仪控系统的半实物仿真平台及控制方法
CN108093601A (zh) * 2016-11-22 2018-05-29 英业达科技有限公司 散热装置及应用其的精简客户端

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US6588499B1 (en) * 1998-11-13 2003-07-08 Pacificorp Air ejector vacuum control valve
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Cited By (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20140202151A1 (en) * 2013-01-21 2014-07-24 Alliance For Sustainable Energy, Llc Hybrid Air-Cooled Condenser For Power Plants and Other Applications
US20140223907A1 (en) * 2013-02-14 2014-08-14 Anest Iwata Corporation Power generating apparatus and method of operating power generating apparatus
JP2014156795A (ja) * 2013-02-14 2014-08-28 Anest Iwata Corp 動力発生装置及びその運転方法
US9528394B2 (en) * 2013-02-14 2016-12-27 Anest Iwata Corporation Power generating apparatus and method of operating power generating apparatus
US9540962B2 (en) 2014-07-14 2017-01-10 Siemens Energy, Inc. Power plant air cooled heat exchanger or condenser with pressurized gas entrained cooling liquid mister
EP3315735A1 (en) * 2016-10-05 2018-05-02 General Electric Company System for higher plant efficiency
JP2018084228A (ja) * 2016-10-05 2018-05-31 ゼネラル・エレクトリック・カンパニイ より高いプラント効率のためのシステムおよび方法
US10465564B2 (en) 2016-10-05 2019-11-05 General Electric Company System and method for higher plant efficiency
JP7106257B2 (ja) 2016-10-05 2022-07-26 ゼネラル・エレクトリック・カンパニイ より高いプラント効率のためのシステムおよび方法

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EP2447480A2 (en) 2012-05-02

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