EP2034137A1 - Verfahren zum Betreiben einer Gas- und Dampfturbinenanlage sowie dafür ausgelegte Gas- und Dampfturbinenanlage - Google Patents

Verfahren zum Betreiben einer Gas- und Dampfturbinenanlage sowie dafür ausgelegte Gas- und Dampfturbinenanlage Download PDF

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Publication number
EP2034137A1
EP2034137A1 EP07002014A EP07002014A EP2034137A1 EP 2034137 A1 EP2034137 A1 EP 2034137A1 EP 07002014 A EP07002014 A EP 07002014A EP 07002014 A EP07002014 A EP 07002014A EP 2034137 A1 EP2034137 A1 EP 2034137A1
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EP
European Patent Office
Prior art keywords
steam
gas
downpipes
pressure
evaporator
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Withdrawn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
EP07002014A
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German (de)
English (en)
French (fr)
Inventor
Jan BRÜCKNER
Rudolf Hess
Erich Schmid
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Siemens AG
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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 EP07002014A priority Critical patent/EP2034137A1/de
Priority to PL08828009.4T priority patent/PL2126291T3/pl
Priority to EP08828009.4A priority patent/EP2126291B1/de
Priority to PCT/EP2008/050954 priority patent/WO2009024358A2/de
Priority to RU2009132482/06A priority patent/RU2467250C2/ru
Priority to CN2008800034956A priority patent/CN101595279B/zh
Priority to US12/524,872 priority patent/US9429045B2/en
Publication of EP2034137A1 publication Critical patent/EP2034137A1/de
Withdrawn legal-status Critical Current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
    • 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
    • F01K23/106—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 with water evaporated or preheated at different pressures in exhaust boiler
    • F01K23/108—Regulating means specially adapted therefor

Definitions

  • the invention relates to a method for operating a gas and steam turbine plant in which the flue gas emerging from a gas turbine is passed through a heat recovery steam generator and in which a fluid used for driving a steam turbine is guided in a fluid circuit comprising a number of pressure stages, wherein at least one the pressure stages having an evaporator circulation with a steam drum, with a number of downpipes connected to the steam drum and with a number of the downcomers downstream, also connected to the steam drum and heated by the flue gas in the heat recovery steam riser riser.
  • the invention further relates to a gas and steam turbine plant designed for such an operating method.
  • the fluid circuit comprises several, for example three, pressure stages, each with its own evaporator section.
  • a design and design concept for such an evaporator section which has proved its worth because of its comparatively simple structure and its relatively simple operability is based on the natural circulation principle, at least in the area of subcritical vapor pressures. It serves a above the flue gas flow channel of the heat recovery steam generator arranged steam drum, which is sometimes referred to as "top drum", as a reservoir for the condensate or feed water ago her running, optionally preheated by a condensate preheater or economizer condensate or feed water.
  • the sunken water is on a number of parallel connected and bundled to heating surfaces, by the heat contained in the flue gas and / or heated by the radiant heat generated by an additional burner of Abhitzedampfkessels risers distributed, in which the desired evaporation takes place.
  • the heating surfaces formed from the riser tubes can be part of the enclosure wall of the heat recovery steam boiler or in the manner of Schottsammlung inhabit within the of the Surrounding wall enclosed flue gas flow channel may be arranged.
  • the water-vapor mixture produced in the riser pipes by (partial) evaporation of the water rises and finally re-enters the steam drum above the liquid level, whereby the evaporator circulation is closed.
  • the water-steam separation also referred to as phase separation takes place; the water vapor present above the water level under saturated steam conditions is withdrawn via a steam extraction line connected to the top of the steam drum and, if necessary, overheating of its further use, eg. B. for driving a steam turbine supplied.
  • Evaporator stages based on the forced circulation principle have a similar structure, but still have a circulating pump connected in the evaporator loop, which supports or forces the circulation of the water or of the water / steam mixture.
  • the current compliance with the medium pressure drum (MD drum) and low pressure drum (LP drum) levels above the minimum oil level requires complex inlet temperature control for the economizers of the high and medium pressure systems and the condensate preheater.
  • Changes in stationary conditions due to different operating conditions in oil operation result in internal heat shifts in the heat recovery steam generator, which influence the heat absorption of the medium-pressure and low-pressure evaporator.
  • This can, for example, cause fluctuations in the drum water levels of the MD and LP drum and an undesirably high pressure increase in the LP drum.
  • the quantities of water must additionally be superimposed accordingly via the HP and MD economizer bypass valves, which requires increased control effort.
  • the drop in the water level in the low-pressure drum during a quick-closing of the steam turbine is particularly drastic here due to the deliberately induced increase in pressure in the low-pressure system. Contrary to the original orientation of the concept can therefore not be completely dispensed with in practice on a Niederbuchumleitstation that reduces the drop in water level at a quick closing of the steam turbine accordingly.
  • the invention is therefore based on the object of specifying a method for operating a gas and steam turbine plant of the type mentioned, which is particularly flexible adaptable to various operating conditions of the system with high reliability and high operational safety, and a particularly cost-effective design of the components respective evaporator circulation possible. Furthermore, a suitable for carrying out the process gas and steam turbine plant should be specified.
  • the object is achieved by monitoring the height of the liquid column formed by the flow medium in the downpipes connected to the steam drum.
  • the invention is based on the consideration that, due to the advances recently achieved in the material technology and material development for evaporator heating pipes contrary to the hitherto held in the professional world view interpretation of a gas and steam turbine both in technical Considerable as well as under the given economic constraints in practice is competitive, in which at least temporarily during special operating conditions, a partial or complete dry operation of an evaporator circulation, that is a drop in the liquid level in the downpipes below the level of the steam drum tolerated.
  • a metrological detection of the level height of the liquid column formed by the liquid flow medium within the downpipes of the evaporator circulation is provided.
  • the measuring device not only provides information as to whether the liquid level is actually dropping below a minimum level in the steam drum or below the level of the downpipe connections, but quantifies this state even more closely by detecting at least one further height level or a plurality of discrete height measuring points within the downpipe monitors and metrologically dissolves.
  • a continuous or quasi-continuous measurement of the level height can be provided in the downpipe, expediently with the arranged at the lower end of the manifold manifold as a reference point.
  • the temperature of the flue gas is also monitored in the riser, wherein in an operating condition with a lying below the connection to the steam drum liquid level in the downcomers a safety measure is initiated as soon as the temperature of the flue gas in the downstream of the downcomers risers exceeds a predetermined limit.
  • a cascade of staggered limit values can also be defined, whereby, when a first limit value is exceeded, a relatively "mild" countermeasure is initially introduced, but increasingly more drastic countermeasures upon further increase in temperature.
  • the respective temperature limit value is determined as a function of the liquid level in the downpipes determined by measurement, so that the cooling influence of the remaining amount of the fluid flowing through the downstream riser pipes and taken into account appropriately takes into account when deciding on the type and timing of initiation of safety measures can be.
  • a first, relatively mild safety measure is preferably to open a bypass line of a condensate preheater upstream of the evaporator circuit or feedwater preheater on the flue gas side in order to generally exceed the permissible flue gas temperatures during various load change states, in particular when the gas and steam turbine system is started or stopped prevent evaporators concerned. If the regular operation is then resumed and steam is again generated in the relevant evaporator stage, then the respective evaporator system is filled with hot water from the upstream economizer (in the MD evaporator) or from the condensate preheater (in the LP evaporator). By deliberately closing the cold condensate preheater bypass or the economizer bypass, the respective heating temperature is increased and steam production reintroduced.
  • the opening of the condensate preheater bypass line or the bypass line of the MD economizer in the standard case that, as in DE 100 04 187 C1 described, the HD evaporator flue gas side of the MD evaporator and this in turn upstream of the LP evaporator, to the advantageous side effect that now the evaporator circulation of the HD stage is supplied with comparatively cooler feed water, so that the flue gas of the gas turbine already in the Entry area of the heat recovery steam generator comparatively much heat is withdrawn.
  • the temperature load in the area of the MD and LP heating surfaces which is in any case moderate in comparison to the high pressure stage, is thereby reduced particularly quickly and effectively when required. Especially with such an effective, if necessary activatable safety measure, a temporary drying of the MD and / or LP evaporator circulation can therefore be tolerated particularly well.
  • both the height of the liquid column in the downcomers of the MD and / or the LP evaporator and the respective flue gas temperature are monitored, wherein a possible overload state of the two pressure levels based on the two associated parameters fill level and flue gas temperature derived at the installation of the heating surfaces becomes.
  • both the spatially varying heating profile and possibly a different choice of material and temperature design for the various evaporator circuits are expediently taken into account.
  • Another, more drastic security measure may be to initiate a power reduction or an emergency shutdown of the gas turbine or, for. B. by pressing a bypass valve, passing the flue gas leaving the gas turbine at least partially on the heat recovery steam generator.
  • the object mentioned above is achieved by a gas and steam turbine plant, in which a level measuring device for measuring the height of the fluid column formed by the flow medium in the connected to the steam drum downcomers signal output side with a monitoring and control device for the gas and Steam turbine plant is connected.
  • the monitoring and control device is further connected on the signal input side to a temperature measuring device monitoring the temperature of the flue gas in the region of the riser tubes and configured to introduce a safety measure in an operating condition with a below the connection to the steam drum liquid level in the downpipes, as soon as temperature measured by the temperature measuring device exceeds a predetermined limit.
  • the advantages achieved by the invention are, in particular, that it is made possible by the consistent design of the system architecture and the associated hedging and monitoring systems, in a gas and steam turbine plant with a heat recovery steam generator, if necessary, based on the natural circulation principle evaporator system, in particular the MD and / or the LP evaporator system to operate safely at a water level far below the currently set minimum water level or even to drive the heating surfaces dry without having to stop the operation of the heat recovery steam generator or the gas turbine.
  • an adjustment of flexible minimum water levels in the respective evaporator circulation depending on certain modes without loss of security is possible.
  • the inventive concept allows a more cost-effective design and construction of production costs usually particularly costly components of the evaporator system, since in particular the MD and LP steam drums can be made more compact than previously necessary. This is especially in the context of the above-mentioned operation "Sleeping Mode" in the absence of Niederbuchumleitstation for the LP evaporator of relevance, since the otherwise required for carrying out this mode drum enlargement now be correspondingly lower or even eliminated altogether.
  • the control engineering effort to comply with the Kondensatvorowskir- and economizer inlet temperatures in oil operation is lower than before.
  • the concept presented here can also be used in gas and steam turbine plants with evaporator stages based on the forced circulation principle.
  • the gas and steam turbine 1 according to FIG. 1 includes a gas turbine plant 1a and a steam turbine plant 1b.
  • the gas turbine plant 1a comprises a gas turbine 2 with a coupled air compressor 4 and a combustion chamber 6 upstream of the gas turbine 2 in which fuel B is burned while supplying compressed air from the air compressor 4 to the working medium or fuel gas A for the gas turbine 2.
  • the gas turbine 2 and the air compressor 4 and a generator 8 are seated on a common turbine shaft 10.
  • the steam turbine installation 1 b comprises a steam turbine 12 with a coupled generator 14 and a condenser 18 connected downstream of the steam turbine 12 and a waste heat steam generator 20 in a water circuit 16 designed as a water-steam circuit.
  • the steam turbine 12 has a first pressure stage or a high-pressure component 12 a and a second pressure stage or a medium-pressure part 12b and a third pressure stage or a low-pressure part 12c, which drive the generator 14 via a common turbine shaft 22.
  • an exhaust pipe 24 to the heat recovery steam generator 20 is connected on the input side.
  • the expanded flue gas R from the gas turbine 2 leaves the heat recovery steam generator 20 on the output side in the direction of a fireplace, not shown.
  • the heat recovery steam generator 20 comprises, as heating surfaces, a condensate preheater 26, which is fed on the input side with condensate K from the condenser 18 via a condensate line 28, into which a condensate pump 30 is connected.
  • the condensate preheater 26 is guided on the output side to the suction side of a feedwater pump 34.
  • a bypass line 36 For bypassing the condensate preheater 26 as required, it is bridged with a bypass line 36 into which a motor-actuated valve 38 is connected.
  • the feedwater pump 34 is formed in the embodiment as a high-pressure feed pump with medium pressure extraction. It brings the condensate K to a pressure level suitable for a high-pressure stage 40 of the fluid circuit 16 assigned to the high-pressure part 12 a of the steam turbine 12.
  • the guided through the feedwater pump condensate K, which is referred to as the feed water S on the pressure side of the feedwater pump 34 is supplied to a feedwater heater 42 with medium pressure. This is the output side connected to a medium-pressure steam drum 44.
  • the condensate preheater 26 is connected on the output side via a motor-actuatable valve 46 to a low-pressure steam drum 48.
  • the medium-pressure steam drum 44 is connected to a medium pressure evaporator 50 arranged in the heat recovery steam generator 20 to form a medium pressure evaporator circulation 52.
  • the evaporator circuit 52 includes a number of in FIG. 1 indicated only schematically, outside of the heated flue gas R flow channel of the heat recovery steam generator 20 extending downcomers 54 which are connected at their upper end respectively to the bottom of the steam drum 44 and open at its lower end in a distributor collector not shown here.
  • a medium-pressure superheater 58 is connected to the medium-pressure steam drum 44 and is connected on the output side to an exhaust steam line 62 connecting the high-pressure part 12a on the output side to an intermediate superheater 60.
  • the reheater 60 is connected on the output side via a steam line 64, into which a motor-actuatable valve 66 is connected, to the central-pressure part 12b of the steam turbine 12.
  • High-pressure side the feedwater pump 34 via a first high-pressure economizer 68 and a feed water side downstream and within the heat recovery steam generator 20 upstream flue gas second high pressure economizer 70 is guided to a high pressure steam drum 72.
  • the high pressure steam drum 72 is in turn connected to a high pressure evaporator 74 disposed in the waste heat steam generator 20 to form an evaporator circuit 80 comprising a number of downcomers 76 and risers 78.
  • the high-pressure steam drum 72 is connected to a high-pressure superheater 82 arranged in the heat recovery steam generator 20, which is connected on the output side to the high-pressure part 12a of the steam turbine 12 via a live steam line 84 to a motor-actuated valve 86.
  • the first high-pressure economizer 68 is also bridged with a bypass line 88, into which in turn a motor-operated valve 90 is connected.
  • the low-pressure evaporator circuit 94 Analogous to the high-pressure evaporator circuit 80 and the medium-pressure evaporator circuit 52, the low-pressure evaporator circuit 94 consists of a number of connected to the steam drum 48 downcomers 102 and a number of these downstream of the flow side risers 104 together. On the output side, the low-pressure superheater 98 is connected to the inlet of the low-pressure part 12 c of the steam turbine 12 via a steam line 106 into which a motor-actuated valve 108 is connected.
  • the live steam line 84 connecting the high-pressure superheater 82 to the high-pressure part 12a is connected directly to the condenser 18 via a steam line 110 into which a motor-actuated valve 112 is connected.
  • the steam line 110 serving as high-pressure bypass is connected in the flow direction of the live steam F upstream of the valve 86 to the main steam line 84.
  • the gas and steam turbine plant 1 is designed such that the level of liquid fluid in the downpipes 54, 102 of the medium-pressure evaporator circuit 52 and the low pressure Evaporator circuit 94 may at least temporarily drop below the level of the connection to the respective steam drum 44, 48, if necessary, up to a complete dry operation of the evaporator circuit 52 and 94, respectively.
  • the tube wall material of the downpipes 54, 102 downstream of the flow side, by contact with the flue gas R convectively heated risers 56, 104 are each selected with respect to its temperature resistance such that its temperature limit above that in this area the heat recovery steam generator 20 is normally present or maximum expected temperature of the flue gas R.
  • the riser pipes 56 of the medium-pressure evaporator 50 are designed for a continuous temperature resistance of about 400 ° C.
  • the medium-pressure steam drum 44 and the low-pressure steam drum 48 can be built very compact, since the date each to compensate for different steam production rates and to ensure a continuous feeding of the risers 56, 104 with fluid vortexe liquid volume may be relatively small.
  • the gas and steam turbine plant 1 with a specific equipped for monitoring and control of such operating conditions designed monitoring and control system.
  • the medium-pressure evaporator circulation 52 and the low-pressure evaporator circulation 94 are monitored independently of one another in a manner to be described below.
  • the monitoring of the low pressure evaporator circuit 94 is done as follows: In addition to the hitherto customary monitoring of the water level in the low pressure steam drum 48, in FIG. 2 indicated schematically by the double arrow 114, is now a level monitoring provided, which also includes the connected to the low-pressure steam drum 48 downpipes 102, here indicated schematically by the double arrow 116.
  • a fill level measuring device not shown here so measures the reference to the lowest point of the downpipes 102 height of the water column during the normal operation of the gas and steam turbine plant 1 extends into the steam drum 48, while special situations now but also - as described above - can fall below the height level of the upper downpipe connections.
  • the fill level can also be provided to refer the fill level to the downcomer connections, that is to say to the lowest point of the steam drum 48, and to indicate, for example, an overlying level with a positive sign, an underlying level with a negative sign. So if z. For example, if the height of the downcomers 102 is two meters, a level of "minus 1.9 meters" would indicate a potentially imminent complete dry operation.
  • the so measured level of liquid flow medium in the downpipes 102 of the low-pressure evaporator circuit 94 is transmitted to a central evaluation unit, not shown here, a monitoring and control device for the combined cycle power plant 1.
  • a further input variable for the monitoring is the temperature T 1 of the flue gas R prevailing in the region of the riser tubes 104, which in accordance with FIG. 2 by a seen in the flow direction of the flue gas R just before the risers 104 in the heat recovery steam generator 20 arranged, here only schematically indicated temperature measuring device 118 and its temperature sensor is detected.
  • the monitoring and control device is configured or programmed to initiate a safety measure at least in an operating condition with a liquid level in the downcomers 102 below the connection to the steam drum 48 as soon as the temperature T 1 measured by the temperature measurement device 118 reaches a predetermined limit exceeds.
  • This limit value can be predetermined in particular depending on the liquid level in the downpipes 102.
  • the temperature input limit for the risers 104 of the low-pressure evaporator circuit 94 at 300 C may be set at about half height with water-filled downpipes 102, a first limit at 290 ° C, in the first in the bypass line 36 of the Kondensatvor lockerrs 26 lying valve 38 is opened.
  • this first limit is suitably set correspondingly lower, z. At about 270 ° C.
  • the opening of the valve 38 causes the condensate K on the suction side of the feedwater pump 34 has a mixing temperature T M , which adjusts due to the at least partial recirculation of the condensate preheater 26.
  • This mixed temperature T M is smaller than the condensate temperature T K "with completely flowed, ie not flow around condensate 26.
  • a mixing temperature T M which is smaller than the temperature T K " des During operation of the steam turbine 12 the condensate preheater 26 leaving condensate K.
  • the temperature load for the risers 104 of the low-pressure stage 100 is greatly reduced and at the same time the water level in the low-pressure steam drum 48 and in the downpipes connected to it 102 increases again, so that potentially dangerous operating conditions due to the temporary dry operation of the low pressure evaporator circulation 94 can be actively and effectively counteracted if necessary.
  • the temperature T 1 of the flue gas R in the region of the low-pressure evaporator 96 continue to increase and a second limit of z. B. 320 ° C in half filled with water downpipes 102 or z. B. exceed 300 ° C in dry operation, then initiates the monitoring and control device for the combined cycle power plant 1 further security measures, eg. B. an emergency shutdown of the gas turbine plant 1a.
  • a level measuring device for measuring the height of the fluid column formed by the flow medium in the connected to the steam drum 44 downcomers 54 and on the other hand arranged in the flue gas duct just before the risers 56 temperature measuring device 126 for measuring the in Area of the riser pipes 56 prevailing flue gas temperature T 2 provided.
  • a monitoring and control device connected to the temperature and level sensors is configured to initiate a safety measure in an operating condition with a liquid level in the downcomers 54 below the connection to the medium-pressure steam drum 44 as soon as the measured by the temperature measuring device 126, the flue gas temperature T 2 exceeds a predetermined limit.
  • a first safety measure may be to open the valve 38 in the bypass line 36 for the condensate preheater 26.
  • the valve 90 may be opened in the bypass line 88 for the first high-pressure economizer 68, so that comparatively cooler feed water S is supplied to the second high-pressure economizer 70.
  • the second high pressure economizer 70 therefore removes the pressure in this area of the heat recovery steam generator 20 flowing flue gas R compared to the operation with closed bypass valves 38, 90 in addition heat that the flue gas side downstream medium-pressure heating surfaces and the risers 56 is no longer available.
  • a second, more drastic security measure can in turn consist in an emergency shutdown of the gas turbine plant 1a.
  • Such a bypass operation which is provided in particular when starting or stopping the steam turbine 12 and at a steam turbine short circuit, leads to a diversion of the generated live steam F, bypassing the steam turbine 12 directly into the condenser 18.
  • the valve 86 is closed and the valve 112th open.
  • the condensate preheater 26 is at least partially flowed around by opening the valve 38 located in the bypass line 36.
  • valve 90 is opened in the bypass line 88, so that due to the above-described heat shifts in the heat recovery steam generator 20, the production of low-pressure steam and optionally also throttled by medium-pressure steam or even brought to a complete halt.
  • high-pressure steam or live steam F is generated, which is, however, introduced directly into the condenser 18 via the vapor line 12 bypassing steam line 110.
EP07002014A 2007-01-30 2007-01-30 Verfahren zum Betreiben einer Gas- und Dampfturbinenanlage sowie dafür ausgelegte Gas- und Dampfturbinenanlage Withdrawn EP2034137A1 (de)

Priority Applications (7)

Application Number Priority Date Filing Date Title
EP07002014A EP2034137A1 (de) 2007-01-30 2007-01-30 Verfahren zum Betreiben einer Gas- und Dampfturbinenanlage sowie dafür ausgelegte Gas- und Dampfturbinenanlage
PL08828009.4T PL2126291T3 (pl) 2007-01-30 2008-01-28 Sposób eksploatacji instalacji z turbiną gazową i parową oraz przeznaczona do tego instalacja z turbiną gazową i parową
EP08828009.4A EP2126291B1 (de) 2007-01-30 2008-01-28 Verfahren zum betreiben einer gas- und dampfturbinenanlage sowie dafür ausgelegte gas- und dampfturbinenanlage
PCT/EP2008/050954 WO2009024358A2 (de) 2007-01-30 2008-01-28 Verfahren zum betreiben einer gas- und dampfturbinenanlage sowie dafür ausgelegte gas- und dampfturbinenanlage
RU2009132482/06A RU2467250C2 (ru) 2007-01-30 2008-01-28 Способ эксплуатации газопаровой турбинной установки и предназначенная для этого газопаровая турбинная установка
CN2008800034956A CN101595279B (zh) 2007-01-30 2008-01-28 燃气和蒸汽轮机设备及其运行方法
US12/524,872 US9429045B2 (en) 2007-01-30 2008-01-28 Method for operating a gas and steam turbine plant and monitoring a liquid level in a plurality of downpipes

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
EP07002014A EP2034137A1 (de) 2007-01-30 2007-01-30 Verfahren zum Betreiben einer Gas- und Dampfturbinenanlage sowie dafür ausgelegte Gas- und Dampfturbinenanlage

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EP2034137A1 true EP2034137A1 (de) 2009-03-11

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EP07002014A Withdrawn EP2034137A1 (de) 2007-01-30 2007-01-30 Verfahren zum Betreiben einer Gas- und Dampfturbinenanlage sowie dafür ausgelegte Gas- und Dampfturbinenanlage
EP08828009.4A Not-in-force EP2126291B1 (de) 2007-01-30 2008-01-28 Verfahren zum betreiben einer gas- und dampfturbinenanlage sowie dafür ausgelegte gas- und dampfturbinenanlage

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EP08828009.4A Not-in-force EP2126291B1 (de) 2007-01-30 2008-01-28 Verfahren zum betreiben einer gas- und dampfturbinenanlage sowie dafür ausgelegte gas- und dampfturbinenanlage

Country Status (6)

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US (1) US9429045B2 (ru)
EP (2) EP2034137A1 (ru)
CN (1) CN101595279B (ru)
PL (1) PL2126291T3 (ru)
RU (1) RU2467250C2 (ru)
WO (1) WO2009024358A2 (ru)

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DE102010040623A1 (de) * 2010-09-13 2012-03-15 Siemens Aktiengesellschaft Verfahren zur Regelung einer kurzfristigen Leistungserhöhung einer Dampfturbine
DE102010040624A1 (de) * 2010-09-13 2012-03-15 Siemens Aktiengesellschaft Abhitzedampferzeuger
EP2884059A1 (en) * 2013-12-11 2015-06-17 Honeywell spol s.r.o. Multistage HRSG control in combined cycle unit

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US8065815B2 (en) * 2006-10-10 2011-11-29 Rdp Technologies, Inc. Apparatus, method and system for treating sewage sludge
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DE102010028720A1 (de) * 2010-05-07 2011-11-10 Siemens Aktiengesellschaft Verfahren zum Betreiben eines Dampferzeugers
DE102010042458A1 (de) * 2010-10-14 2012-04-19 Siemens Aktiengesellschaft Verfahren zum Betreiben einer kombinierten Gas- und Dampfturbinenanlage sowie zur Durchführung des Verfahrens hergerichtete Gas- und Dampfturbinenanlage und entsprechende Regelvorrichtung
DE102013003386B4 (de) 2013-03-01 2020-08-13 Nippon Steel & Sumikin Engineering Co., Ltd. Verfahren und Vorrichtung zum Betreiben eines Dampferzeugers in einer Verbrennungsanlage
DE102013211376B4 (de) * 2013-06-18 2015-07-16 Siemens Aktiengesellschaft Verfahren und Vorrichtung zur Regelung der Eindüsung von Wasser in den Rauchgaskanal einer Gas- und Dampfturbinenanlage
AU2014347767B2 (en) * 2013-11-07 2018-08-02 Sasol Technology Proprietary Limited Method and plant for co-generation of heat and power
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US9429045B2 (en) 2016-08-30
PL2126291T3 (pl) 2016-09-30
CN101595279B (zh) 2012-11-28
WO2009024358A2 (de) 2009-02-26
RU2009132482A (ru) 2011-03-10
RU2467250C2 (ru) 2012-11-20
CN101595279A (zh) 2009-12-02
EP2126291A2 (de) 2009-12-02
EP2126291B1 (de) 2016-03-16
US20100089024A1 (en) 2010-04-15

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