EP1801363A1 - Centrale électrique - Google Patents

Centrale électrique Download PDF

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Publication number
EP1801363A1
EP1801363A1 EP05027973A EP05027973A EP1801363A1 EP 1801363 A1 EP1801363 A1 EP 1801363A1 EP 05027973 A EP05027973 A EP 05027973A EP 05027973 A EP05027973 A EP 05027973A EP 1801363 A1 EP1801363 A1 EP 1801363A1
Authority
EP
European Patent Office
Prior art keywords
condensate
cooling
power plant
component
steam
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Withdrawn
Application number
EP05027973A
Other languages
German (de)
English (en)
Inventor
Uwe Juretzek
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Siemens AG
Original Assignee
Siemens AG
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Siemens AG filed Critical Siemens AG
Priority to EP05027973A priority Critical patent/EP1801363A1/fr
Priority to PCT/EP2006/069748 priority patent/WO2007071616A2/fr
Priority to EP06830643A priority patent/EP1963624A2/fr
Priority to CN2006800531216A priority patent/CN101379272B/zh
Priority to US12/086,782 priority patent/US20090178403A1/en
Publication of EP1801363A1 publication Critical patent/EP1801363A1/fr
Priority to EG2008060981A priority patent/EG25179A/xx
Priority to IL192271A priority patent/IL192271A/en
Withdrawn legal-status Critical Current

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Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F28—HEAT EXCHANGE IN GENERAL
    • F28B—STEAM OR VAPOUR CONDENSERS
    • F28B9/00—Auxiliary systems, arrangements, or devices
    • F28B9/08—Auxiliary systems, arrangements, or devices for collecting and removing condensate
    • 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
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F28—HEAT EXCHANGE IN GENERAL
    • F28B—STEAM OR VAPOUR CONDENSERS
    • F28B1/00—Condensers in which the steam or vapour is separate from the cooling medium by walls, e.g. surface condenser
    • F28B1/02—Condensers in which the steam or vapour is separate from the cooling medium by walls, e.g. surface condenser using water or other liquid as the cooling medium
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F28—HEAT EXCHANGE IN GENERAL
    • F28B—STEAM OR VAPOUR CONDENSERS
    • F28B9/00—Auxiliary systems, arrangements, or devices
    • F28B9/04—Auxiliary systems, arrangements, or devices for feeding, collecting, and storing cooling water or other cooling liquid
    • F28B9/06—Auxiliary systems, arrangements, or devices for feeding, collecting, and storing cooling water or other cooling liquid with provision for re-cooling the cooling water or other cooling liquid

Definitions

  • the present invention relates to a power plant.
  • Such power plants are known in the art. They typically include a closed steam circuit subdivided into a steam zone and a condensate / feed water zone, a closed subcooling circuit and a closed intercooler circuit having component coolers for cooling individual components of the power plant. The heat emitted by the components to the intermediate cooling circuit heat is released unused to the secondary cooling circuit and then via a main cooling circuit to the environment.
  • the condensate / feed water is heated by means of a steam-heated preheating before entering the boiler to increase efficiency.
  • the steam turbine steam at various pressure and temperature levels taken and used for heating of heat exchangers.
  • the first steam-heated low-pressure preheater and the low-pressure preheater dewatering coolers and the steam vapor condenser heat the condensate to approx. 55 ° C.
  • the power plant according to the invention comprises a condenser condensing the process medium, wherein downstream of the condenser at least one separate cooling device for cooling the already condensed process medium and component coolers are provided, which are set up such that the cooling device cools the process medium to a predetermined temperature before entering the component coolers and the component coolers subsequently reheat the process medium, wherein the ongoing increase in temperature of the process medium is greater than the previously induced temperature reduction.
  • the condensate Upon exiting the condenser, the condensate is thus initially supercooled in order to set the condensate temperature required for cooling the components of the power plant to be cooled.
  • the component cooler can be integrated into the condensate region of the steam cycle, which is why neither a separate intermediate cooling circuit for cooling the power plant components nor a separate auxiliary cooling circuit for receiving the heat of the intermediate cooling circuit are required. Accordingly, the costs incurred for these cooling circuits costs can be at least largely saved.
  • the component cooler While the initially supercooled condensate flows through the component cooler, it absorbs the heat of the components to be cooled, wherein the temperature increase taking place is greater than the previously induced temperature reduction.
  • the output from the components to be cooled heat which has been released in known power plant so far on the secondary and main cooling circuit to the environment is used according to the invention for heating the condensate, whereby the effectiveness of the entire system is improved and also the costs are reduced.
  • the at least one cooling device is preferably a coldwell traversed by cooling tubes, which is arranged directly below the hot well of the capacitor. In this way, the condensate is supercooled before it enters the condensate pump, whereby the NPSH value is improved on the suction side of the condensate pump, which is why this is arranged higher and the condensate pump pit can be made correspondingly flatter.
  • the at least one cooling device is advantageously supplied by a cooling system with a cooling medium in order to ensure the subcooling of the condensate on exit from the condenser.
  • the component coolers are advantageously at least partially connected in series in order to largely match the component cooling water mass flow which is required for cooling the power plant components to be cooled to the steam cycle mass flow, which will be explained in more detail below with reference to the drawing.
  • a return line for returning condensate to the condenser is preferably provided downstream of the component cooler to ensure sufficient component cooling water mass flow if the steam cycle mass flow should not be sufficient for cooling the power plant components to be cooled.
  • a cooling unit may be connected, preferably a fin-fan cooler to cool the recirculated through the return line condensate. Due to the cooling unit, it is possible, for example, to take in short-term shutdowns of the power plant, the cooling device cooling cooling system from operation, the subcooling of the condensate is then ensured solely by the cooling unit. In this way, costs can also be saved.
  • a condensate cleaning system is preferably connected to the cooling device process media side. In this way it is ensured that the condensate fed into the condensate purification system has a low temperature, whereby the service life and the regeneration cycles of the condensate purification system are increased.
  • Fig. 1 shows a known gas and steam power plant 2, the steam cycle is designated by the reference numeral 4.
  • the steam circuit 4 is subdivided into a steam region 6 and into a condensate / feedwater region 8.
  • the reference numeral 8a designates the condensate preheating area of the condensate / feed water area 8.
  • the steam power plant 2 comprises a main cooling circuit 10, a secondary cooling circuit 11 and a cooled by the secondary cooling circuit 11 intermediate cooling circuit 12, which are shown on the right in Fig. 1 and will be explained in more detail below.
  • the steam turbine 14 includes three pressure stages; namely a low pressure stage 16, a medium pressure stage 18 and a high pressure stage 20th
  • water is evaporated in an evaporator 30, and the steam generated in this way is subsequently fed to a high-pressure drum 32. Subsequently, the steam is superheated in a superheater 34 and fed to the high-pressure stage 20 of the steam turbine 14 via a line 36.
  • the steam generated is fed to a medium-pressure drum 40 and then overheated in a superheater 42.
  • the superheated steam then flows through a conduit 44 and optionally mixes with Steam, which is returned via a line 46 after leaving the high pressure stage 20 of the steam turbine 14 (so-called cold reheat).
  • the vapor mixture thus produced is heated in a so-called reheater 48 and fed to the medium-pressure stage 18 of the steam turbine 14 via a line 50.
  • the steam leaving the steam turbine 14 is condensed in a condenser 52, which is cooled by the main cooling circuit 10.
  • the condensate thus produced is passed into a hotwell 56 arranged below the condenser 52 and pumped from there via a condensate pump 58 into the conduit 60.
  • a condensate preheater 62 the condensate is then preheated, whereupon the line 60 branches into the lines 64 and 66.
  • the line 64 passes the condensate to the low-pressure drum 24, whereupon it is re-evaporated by the evaporator 22.
  • the condensed into the line 66 condensate is passed through a feedwater pump 68 via branch lines 70 and 72 to economizers 74 and 76 and further heated there.
  • the condensate leaving the economizer 74 is supplied in the medium-pressure drum 40 and then evaporated in the evaporator 38.
  • the condensate leaving the economizer 76 is supplied to the high-pressure drum 32 and then evaporated using the evaporator 30.
  • the main cooling circuit 10 includes a cooling tower 78 from which cooling water is pumped into a conduit 82 using a cooling water pump 80.
  • the conduit 82 branches into branch conduits 84 and 86, with the branch conduit 84 delivering cooling water to the condenser 52 to cool it.
  • the partial cooling water flow flowing through the branch line 86 into the auxiliary cooling circuit 11 is pumped via a booster pump 88 into the two branch lines 90 and 92, where it is passed through corresponding heat exchangers 94 and 96 for cooling the cooling water flowing through the intermediate cooling circuit.
  • the cooling water After leaving the heat exchangers 94 and 96, the cooling water through a line 98 back into the main cooling circuit 10th passed there, mixed with the exiting the condenser 52 cooling water and finally flows through a line 100 back to the cooling tower 78th
  • a closed main cooling circuit 10 with integrated secondary cooling circuit 11 wherein the main cooling circuit 10 is supplied via a line 102 treated cooling tower additive water and can be drained from the via a line 104 water, which is also referred to as cooling tower slurry.
  • the intermediate cooling circuit 12 is a closed system which serves for cooling individual components of the gas and steam power plant 2.
  • a plurality of component coolers 106 to 112 arranged parallel to one another are provided, through which cooling water flows, which absorbs the heat released by the components.
  • the heated cooling water flows through a conduit 114 and is pumped through the heat exchangers 96 and 94 using a pump 116, where it is cooled.
  • the cooled cooling water is then again supplied to the component coolers 106 to 112 for cooling the respective components.
  • an expansion tank 120 is finally operatively connected to the line 114 to compensate for pressure fluctuations caused by temperature changes in the intermediate cooling circuit 12.
  • Fig. 2 is a schematic view showing an embodiment of a gas and steam power plant 200 according to the present invention.
  • the gas and steam power plant 200 comprises a steam circuit 202, which is divided into a steam region 204 and a condensate / feed water region 206.
  • the gas and steam power plant 200 includes a cooling circuit 208, which, similar to the main cooling circuit 10 shown in FIG. 1, among other things, cools the condenser 210.
  • the gas and steam power plant 200 differs from the known gas and steam power plant 2 shown in FIG. 1 essentially by the structure of the condensate / feed water area 206 and by that of the cooling circuit 208, which will be described in more detail below with reference to FIGS Fig. 3 is an enlarged and more detailed view of the condensate / feedwater section 206 shown in Fig. 2.
  • the condenser 210 includes a hot well 212 and a coldwell 214 disposed therebelow.
  • the coldwell 214 is traversed by cooling tubes which are fed via line 216 with cooling water from the refrigeration cycle 208, which is then passed via line 218 back into the refrigeration cycle 208.
  • the cooling water flowing through the cooling tubes removes heat from the condensate flowing through the coldwell 214, so that it leaves the coldwell 214 via the line 222 under the use of the condensate pump 220.
  • the supercooled condensate is fed via branch lines 224, 226 and 228 to a plurality of component coolers 230 to 246 which, partly connected in series, partly in parallel, each serve to cool individual components of the power plant 200.
  • the through the lines 224, 226 and 228 gradually heated condensate, wherein the taking place in the component coolers 230 to 246 increase in temperature of the condensate is greater than that taking place in the coldwell 214 temperature reduction of the condensate, ie in the component coolers 230 to 246 the condensate is supplied more heat than him previously withdrawn in Coldwell 214.
  • a trim valve 248, 250 and 252 is provided to adjust the amount of condensate flowing through the lines 224, 226 and 228, respectively.
  • the condensate leaving lines 224 to 228 is merged into line 254, which in turn branches into line 256 and return line 258.
  • a condensate mass flow is guided through the return line, which supplements the steam mass flow flowing from the steam region into the condenser 210 to such an extent that proper cooling of the components of the power plant 200 to be cooled by the component coolers 230 to 246 is ensured.
  • the valve 263 controls the recirculated through the return line 258 condensate mass flow.
  • a separate fin-fan cooler 265 may be provided which serves to cool the condensate flowing through the return line 258 back into the condenser 210.
  • the fin fan cooler 265 Due to the fin fan cooler 265, it is possible, for example, to take the cooling circuit 208 out of operation during brief stoppages of the power plant 200, the cooling then taking place solely via the fin fan cooler 265. In this way costs can also be saved. Due to the existing large surfaces of the condenser 210, the hot well 212 and the cold well 214, is discharged through the heat to the environment, may even be dispensed with the fin fan cooler 265 in case of a short-term system downtime.
  • the condensate flowing through the line 256 first flows through a quick-acting valve 262.
  • a line 266 branches off from the line 256, through which condensate is conducted to the low-pressure deflection station during the bypass operation.
  • the conduit 256 Downstream of the quick-acting valve, the conduit 256 includes a condensate pump 264 which further pumps the condensate to the condensate preheater 62.
  • a line 268 is passed through the during the bypass operation condensate to Mittelchristumleitstation.
  • the condensate is heated and then pumped by the condensate preheater 62 further via the line 272 to the low-pressure drum 24 and to the inlet of the feedwater pump 68.
  • the condensate pump 264 allows the recirculation of condensate exiting from the condensate preheater 62 to ensure the required condensate preheater inlet temperature, via a valve 276 the required condensate mass flow via a line 278 is fed before the entry of the condensate pump 264.
  • a valve 280 disposed in a conduit 282 releases the cold bypass, if required, such as in oil operation and at the same time failed bypass (or by-pass) as described below.
  • the valve 284 which is provided in the line 256 in front of the feed water pump 68, serves to accumulate the pressure of the condensate pump 264, which thus reaches the required pressure level for providing the injection water for the medium-pressure diverter. In this case, the cold bypass is partially opened. In addition, the valve 284 allows the necessary trim when opening cold bypass.
  • the recirculation of the condensate with the condensate pump 264 is adjusted during the bypass operation (i.e., the generated steam is passed directly into the condenser 210).
  • the heating of the greatly reduced condensate flow in the direction of the condensate preheater 62 is effected by means of a bypass dumper 285. In this way it is ensured that the dew point at the cold end of the boiler is not undershot.
  • the size of the condensate pump 264 does not have to be dimensioned for bypass operation.
  • the pump size can be more closely aligned with normal operation (including recirculation), which reduces the energy requirements and size of the pump.
  • bypass damper 285 is supplied via the condensate mass flow conveyed by condensate pump 264 as a medium to be degassed as well as for partial heating of the condensate mass flow.
  • the degassed condensate is fed via a corresponding pump 286 downstream of the condensate pump 264 via a line 288 downstream of the line 268 leading to the intermediate pressure bypass station.
  • a surge tank 290 is arranged with nitrogen pad. This surge tank is used during a planned or unplanned shutdown of the pump 220 to maintain pressure in the system. To ensure this pressure maintenance, the corresponding quick-closing valves 260 and 262 are to close. In addition, provided with a valve 292 make-up line 293 from the Deminiganverteilsystem the pressure maintenance safely.
  • An optional condensate purification system 300 can be connected to the coldwell 214. Due to the supercooled condensate can be increased accordingly, the life and the regeneration cycles of the condensate cleaning system 300, which entails a reduction in costs.
  • the capacitor is enlarged and separated into two regions, namely the hot well 212 and the cold well 214.
  • the hot well 212 is substantially the same size like the Hotwell 56 on and serves to compensate for level fluctuations.
  • the condensate is then passed through a sufficiently large-sized opening in the underlying, always completely filled Coldwell 214 and subcooled by means of the Coldwell 214 passing through the cooling tubes. This arrangement ensures, on the one hand, that the condensate temperature at the surface of the hot well 212 is not reduced and therefore no increased solution of gases takes place.
  • the cooling tubes routed through the coldwell 214 have the same inside diameter as the other condenser bore, but are considerably shorter, which results in a lower pressure loss, which is why the booster pump 88 shown in FIG. 1 can be dispensed with.
  • the NPSH value at the suction side of the condensate pump 220 is improved so that it can be placed higher, and therefore the condensate pump pit can be made shallower.
  • a cooling water partial mass flow defined according to worst case ensures that the condensate leaving Coldwell 214 is max. 5 K is warmer than the incoming cooling water (thus it corresponds to the previously applicable for the intermediate cooling system 12 and the main cooling water system 10 boundary conditions).
  • This worst-case cooling water partial mass flow is approximately the Half of the mass flow, since at full load, the entire intercooler heat in normal operation in the direction of the boiler is discharged (or at high ambient temperatures, a large part of it). It is therefore only the incoming, relatively low-energy condensate mass flow from the steam region to cool down. Even at low partial load and in bypass mode, this reduced secondary cooling water circuit cooling water mass flow is sufficient because the heat input by the generator or the load of the generator are reduced accordingly. This reduction of the mass flow leads to a slight reduction of the cooling water pump 80 shown in Fig. 1 of the cooling water circuit, whereby the energy demand is reduced.
  • the condensate pump 220 In addition to the conveyance of the condensate from the coldwell 214 in the direction of the boiler, the condensate pump 220 also assumes the function of the pump 116 of the intermediate cooling circuit 12 shown in FIG. 1.
  • the delivery pressure must be set so that under all operating conditions the pressure in the condensate region is higher than in the Lubricating oil system and the sealing oil system is to be able to safely exclude an oil contamination of the water vapor circuit due to leaks.
  • a surge tank On the pressure side of the condensate pump 220, a surge tank is arranged with nitrogen pads. This surge tank is used during a planned or unplanned shutdown of the pump 220 to maintain pressure in the system. To ensure this pressure maintenance, the corresponding quick-closing valves 260 and 262 are to close. In addition, a make-up from the demineralizer distribution system ensures the pressure maintenance.
  • valve 263 controls the condensate mass flow required to cool the individual components of the power plant 200 which is needed in addition to the mass flow from the steam zone to the condenser 210.
  • the regulation of this recirculation mass flow is dependent on the temperatures measured at the components to be cooled and the specified Temperature target values and temperature limits. In this case, the recirculation mass flow is increased or decreased until all temperature target values or temperature limit values are maintained.
  • the basic idea behind the basic sequence in the series connection of the component coolers is that the components to be cooled, depending on their function, permit different degrees of cooling water temperatures, so that the temperature limit values are correspondingly different.
  • the component with the lowest temperature limit is set accordingly first, and the one with the highest temperature limit last in the row.
  • coolers of components are arranged in the series, in which the function and dimensioning of the component to be cooled depend strongly on a low temperature or in which a low temperature is required to ensure the accuracy of measurement, but the absolute heat input is comparatively low, Therefore, the cooling of subsequent components is only slightly affected (this usually concerns the evacuation pumps (MAJ) and the sampling system (QU)).
  • component coolers of components are arranged in which the design and dimensioning of the component to be cooled depend strongly on a low temperature, such as the generator.
  • component coolers of components are arranged in which the design or dimensioning of the components to be cooled are not or only slightly impaired by higher coolant temperatures (this applies in particular to the lubricating oil coolers and the pump bearing cooling).
  • the component cooler for the Wrasendampfkondensator is usually arranged, with a strong flow must be ensured.
  • a parallel connection must always be used if temperature limits for individual components can not be met by series connection and a corresponding change in the design of the components to be cooled is not technically possible or economically meaningful.
  • Components with similar cooling water flow requirements can be grouped together to avoid unnecessary over-dimensioning of the component coolers.
  • trim valves which may be motorized, are provided at the end of each strand.
  • the injection water station of Niederdruckumleitstation is powered by the condensate pump 220.
  • medium voltage can be switched to low voltage (for systems greater than 400 MW) due to the reduced power consumption.
  • the naturally further required increase in pressure is ensured by the condensate pump 264, which will only need a low-voltage drive due to their size.
  • the condensate pump 264 conveys the condensate to the intermediate pressure bypass station (only during bypass operation), into the bypass and boiler condensate preheaters, and thence into the low pressure drum and to the inlet of the feed water pump.
  • the condensate preheater heating surface in the boiler can be reduced by approx. 20% (which corresponds to approx. 6% of the total boiler heating surface). This is accompanied by a corresponding reduction of the boiler and thus the space required and a reduction of the necessary foundation. In an extreme case, depending on the ambient / operating conditions, cooling of the cold-well 214, at least temporarily, can be completely dispensed with. Accordingly, the condensate preheater heating surface can be reduced by up to about 30%.
  • the reduction of the heating surface leads, in addition to the reduction of boiler costs, to a slight reduction of the exhaust gas pressure loss of the gas turbine and thus to a performance increase of the gas turbine.
  • the heating surface reduction results in a reduction of the water-side pressure losses and thus a reduction in the energy demand.
  • the condensate pump 264 allows, as previously mentioned, the recirculation of the condensate to ensure the required minimum condensate preheat inlet temperature by supplying the required mass flow via the valve 276 before the pump inlet of the condensate pump 264 becomes. This can be dispensed with separate recirculation pumps or taps on the feedwater pump 68.
  • the preheating of the condensate leads to a reduction in the required recirculation mass flow and thus to a reduction in energy demand.
  • the valve 280 releases the cold bypass, if required (eg, in oil operation and at the same time failed bypass generator 285, or the bypass operation described below).
  • the valve 284 serves to accumulate the pressure of the condensate pump 264, which thus achieves the required pressure level for providing the injection water for the medium-pressure diverter. In this case, the cold bypass is partially opened. In addition, the valve allows for the required clearance when opening the cold bypass.
  • the recirculation of the condensate by means of the condensate pump 264 is adjusted during the bypass operation (i.e., the generated steam is passed directly into the condenser 210).
  • the heating of the greatly reduced condensate flow in the direction of the condensate preheater 270) takes place through the bypassdearator 284 (in this way it is ensured that the dew point at the cold end of the boiler is not undershot).
  • the size of the condensate pump 264 does not have to be dimensioned for bypass operation.
  • the pump size can be better aligned with the normal operation (including recirculation), so that the own use and the pump size can be reduced.
  • bypass damper 285 is supplied via the mass flow conveyed by condensate pump 264 (as a medium to be degassed and for partial heating of the mass flow).
  • the degasified condensate is fed via the pump 286 downstream of the condensate pump 264, behind the branch for injection into the Weglichumleitstation.
  • a fuel gas preheating via a line 294 with the funded by the condensate pump 264 mass flow be supplied.
  • the return is fed via a line 296 before the pump inlet of the condensate pump 264.
  • FIG. 4 shows a schematic partial view of an embodiment of a steam power plant according to the invention.
  • the partial view illustrated in FIG. 4 differs from the partial view shown in FIG. 3 in that, following the valve 262, the condensate pump 264 does not follow, but a low pressure preheater 400 is provided which is supplied with bleed steam from the steam turbine (not shown) ).
  • the dewatering of this low-pressure preheater 400 is guided by means of a pump 402 back into the main condensate, and not as usual on the capacitor.
  • a further condensate pump 404 is provided which conveys the condensate through further preheaters in the direction of the boiler.
  • the low-pressure preheater 400 can be dispensed with and the heat input via the further preheaters 406 can be reduced.
  • the benefit in this case not only results from the cost savings of electrical energy but above all from a gross performance and gross efficiency increase and would thus be higher than for a GUD.

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  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Engine Equipment That Uses Special Cycles (AREA)
EP05027973A 2005-12-20 2005-12-20 Centrale électrique Withdrawn EP1801363A1 (fr)

Priority Applications (7)

Application Number Priority Date Filing Date Title
EP05027973A EP1801363A1 (fr) 2005-12-20 2005-12-20 Centrale électrique
PCT/EP2006/069748 WO2007071616A2 (fr) 2005-12-20 2006-12-15 Centrale electrique
EP06830643A EP1963624A2 (fr) 2005-12-20 2006-12-15 Centrale electrique
CN2006800531216A CN101379272B (zh) 2005-12-20 2006-12-15 电站设备
US12/086,782 US20090178403A1 (en) 2005-12-20 2006-12-15 Power Station
EG2008060981A EG25179A (en) 2005-12-20 2008-06-12 Power plant.
IL192271A IL192271A (en) 2005-12-20 2008-06-18 Power station

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
EP05027973A EP1801363A1 (fr) 2005-12-20 2005-12-20 Centrale électrique

Publications (1)

Publication Number Publication Date
EP1801363A1 true EP1801363A1 (fr) 2007-06-27

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Application Number Title Priority Date Filing Date
EP05027973A Withdrawn EP1801363A1 (fr) 2005-12-20 2005-12-20 Centrale électrique
EP06830643A Withdrawn EP1963624A2 (fr) 2005-12-20 2006-12-15 Centrale electrique

Family Applications After (1)

Application Number Title Priority Date Filing Date
EP06830643A Withdrawn EP1963624A2 (fr) 2005-12-20 2006-12-15 Centrale electrique

Country Status (6)

Country Link
US (1) US20090178403A1 (fr)
EP (2) EP1801363A1 (fr)
CN (1) CN101379272B (fr)
EG (1) EG25179A (fr)
IL (1) IL192271A (fr)
WO (1) WO2007071616A2 (fr)

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CN102140963A (zh) * 2010-01-28 2011-08-03 通用电气公司 用于稀释剂氮饱和的方法与装置
WO2013160293A1 (fr) * 2012-04-25 2013-10-31 Basf Se Procédé permettant de fournir un réfrigérant dans un circuit secondaire

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US20090301078A1 (en) * 2008-06-10 2009-12-10 General Electric Company System for recovering the waste heat generated by an auxiliary system of a turbomachine
US20130230415A1 (en) * 2010-03-29 2013-09-05 Mauro Dallai Reciprocating compressor with high freezing effect
DE102013204396A1 (de) * 2013-03-13 2014-09-18 Siemens Aktiengesellschaft Kondensatvorwärmer für einen Abhitzedampferzeuger
JP2016223316A (ja) * 2015-05-28 2016-12-28 株式会社東芝 蒸気タービン用冷却装置およびその制御方法
CN106247309B (zh) * 2016-08-23 2018-07-13 东方菱日锅炉有限公司 余热锅炉的整体式连续排污系统

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EG25179A (en) 2011-10-11
IL192271A (en) 2012-01-31
WO2007071616A2 (fr) 2007-06-28
US20090178403A1 (en) 2009-07-16
EP1963624A2 (fr) 2008-09-03
WO2007071616A3 (fr) 2008-03-13
CN101379272A (zh) 2009-03-04
IL192271A0 (en) 2009-08-03

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