EP2126291A2 - Procédé permettant de faire fonctionner une installation de turbine à gaz et à vapeur et installation de turbine à gaz et à vapeur conçue à cette fin - Google Patents

Procédé permettant de faire fonctionner une installation de turbine à gaz et à vapeur et installation de turbine à gaz et à vapeur conçue à cette fin

Info

Publication number
EP2126291A2
EP2126291A2 EP08828009A EP08828009A EP2126291A2 EP 2126291 A2 EP2126291 A2 EP 2126291A2 EP 08828009 A EP08828009 A EP 08828009A EP 08828009 A EP08828009 A EP 08828009A EP 2126291 A2 EP2126291 A2 EP 2126291A2
Authority
EP
European Patent Office
Prior art keywords
steam
gas
downpipes
evaporator
flue gas
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.)
Granted
Application number
EP08828009A
Other languages
German (de)
English (en)
Other versions
EP2126291B1 (fr
Inventor
Jan BRÜCKNER
Rudolf Hess
Erich Schmid
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 EP08828009.4A priority Critical patent/EP2126291B1/fr
Publication of EP2126291A2 publication Critical patent/EP2126291A2/fr
Application granted granted Critical
Publication of EP2126291B1 publication Critical patent/EP2126291B1/fr
Not-in-force legal-status Critical Current
Anticipated expiration legal-status Critical

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Classifications

    • 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 at least one of the pressure stages has an evaporator circulation with a steam drum, with a number of downpipes connected to the steam drum and with a number of downcomers connected downstream, also connected to the steam drum and heated by the flue gas in the heat recovery steam generator risers.
  • the invention further relates to a gas and steam turbine plant designed for such an operating method.
  • a furnace may be integrated to either raise the temperature of the flue gas above the level present at its exit from the gas turbine, or to maintain steam production in the heat recovery steam boiler when the gas turbine is decoupled or shut down (so-called oil operation) ).
  • 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.
  • a steam drum arranged above the flue gas flow channel of the heat recovery steam generator which is sometimes also referred to as "top drum" serves as a reservoir for the condensate or feed water, which may be supplied by the condensate or feed water pump and possibly preheated by a condensate preheater or an economizer
  • a portion of the water supply continuously sinks down through unheated downcomers connected to the bottom or bottom of the steam drum via an intermediate manifold, sometimes referred to as a "bottom drum is called, the sunken water is distributed to a number of parallel and connected to heating surfaces, distributed by the heat contained in the flue gas and / or heated by the radiant heat generated by an additional burner of the heat recovery steam riser, in de NEN 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 Schottsammlungfest within the of the Sur
  • 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 which is 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 to 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 ND drum and an unintentionally 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 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 material technology and material development for evaporator heating tubes contrary to the hitherto represented in the professional world interpretation of a gas and steam turbine plant both in technical is also feasible in practice under the given economic boundary conditions, in which, at least temporarily, during special operating conditions, a partial or complete drying operation of an evaporator circuit, ie a drop in the liquid level in the downpipes below the level of the steam drum, is tolerable.
  • the arranged in the flow channel of the heat recovery steam riser or the heating surfaces formed from them should be designed in terms of their temperature resistance to the usually occurring during system operation flue gas temperatures in the region of their installation position For example, 300 0 C in a MD evaporator or 200 0 C in a LP evaporator.
  • the hitherto always existing cooling by the fluid normally carried in the pipes should therefore no longer be included in the temperature design for a possible dry operation.
  • the temperature limit is partly over 400 0 C and their use can be justified in economic terms.
  • the hitherto customary monitoring and safeguarding concept for such a combined cycle power plant and in particular for those evaporator circuits in which a temporary dry running is considered consistently to the previous design principles changed thermal loads and threats to the structural integrity the evaporator components are adapted.
  • a measured variable should first be recorded which reliably provides information about an incipient dry operation as well as about its "extent". For this reason, in accordance with the concept presented here, the measurement of the fill level of the liquid column formed by the liquid flow medium within the downpipes of the evaporator circuit is provided above and beyond the hitherto customary level measurement in the steam drum.
  • the measuring device not only provides information as to whether the liquid level drops 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. te monitored within the downpipe and dissolving metrologically.
  • 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.
  • mean throughput monitors the heating temperature acting from outside on the riser pipes and triggers a safety reaction when exceeding a critically regarded value.
  • 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 predefined as a function of the liquid level in the downpipes determined by measurement, so that the cooling influence of the remaining quantity of the flow medium passing through the downstream riser pipes is adequately determined when deciding the type and time of initiation Safety measures can be taken into account.
  • a first, relatively mild safety measure preferably consists in opening a bypass line of a condensate preheater or upstream feed water preheater upstream of the evaporator circuit, in order to generally exceed the flow rate during various load change states, in particular when the gas and steam turbine system is started up or shut down permissible flue gas temperatures in front of the relevant evaporators. 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 (at
  • a condensate preheater downstream MD Eco- nomizer for the feed water of the MD evaporator and an MD economizer downstream HD economizer for the feed water of the HD stage leads to 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 Cl 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 is already withdrawn in the inlet region of the heat recovery steam generator comparatively much heat.
  • the temperature load in the area of the MD and ND heating surfaces which is already moderate in comparison with 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 downpipes of the MD and / or the LP evaporator and the respective flue gas temperature are monitored, with a possible overload state of one of the two pressure levels on the basis of the two associated parameters fill level and flue gas temperature on Installation location of the heating surfaces is derived.
  • both the spatially varying heating profile and possibly a different material selection 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 with 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 state with a liquid level in the downpipes below the connection to the steam drum, as soon as the temperature measured by the temperature measuring device exceeds a predetermined limit.
  • the inventive concept enables a more cost-effective design and construction of components of the evaporator system that are usually particularly expensive in terms of production costs, since in particular the MD and LP steam drums can be made more compact than hitherto necessary.
  • This is of particular relevance in the context of the mode of operation "Sleeping Mode" explained above with the elimination of the low-pressure diverter station for the LP evaporator, since the drum magnification otherwise required for carrying out this mode of operation can now be correspondingly smaller or even completely eliminated the control engineering effort to maintain the Kondensatvorowskir- and economizer inlet temperatures in oil operation less 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.
  • FIG 1 shows a gas and steam turbine plant
  • FIG 2 a detail of FIG 1, wherein in the interest of better visibility of essential components of the gas and steam turbine plant some details have been omitted from Figure 1 or shown in graphically slightly modified form.
  • the gas and steam turbine plant 1 according to FIG. 1 comprises a gas turbine plant Ia and a steam turbine plant Ib.
  • the gas turbine plant Ia comprises a gas turbine 2 with 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 sit on a common turbine shaft 10.
  • the steam turbine plant Ib comprises a steam turbine 12 with a coupled generator 14 and in a formed as a water-steam circuit fluid circuit 16 a steam turbine 12 downstream of the condenser 18 and a
  • the steam turbine 12 has a first pressure stage or a high-pressure part 12a 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.
  • 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. 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 section 40 of the fluid circuit 16 assigned to the high pressure section 12a 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 comprises a number of only schematically indicated in FIG 1, outside of the heated flue gas R flow channel of the heat recovery steam generator 20 down- fenden downspouts 54, which are connected at their upper end respectively to the bottom of the steam drum 44 and at its lower end in lead a distributor collector not shown here.
  • a multiplicity of riser pipes 56 bundled with waste heat steam generator 20 are fed with liquid fluid, in this case water, from the steam drum 44 or from the downpipes 54, which partially evaporates when flowing through the riser pipes 56 , while up rises and enters the steam drum 44 again as a water-steam mixture.
  • liquid fluid in this case water
  • a medium-pressure superheater 58 is connected to the medium-pressure steam drum 44 and, on the output side, is connected to an exhaust steam line 62 connecting the high-pressure part 12a on the output side to a reheater 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.
  • the feedwater pump 34 is led to a high pressure steam drum 72 via a first high pressure economizer 68 and a second high pressure economizer 70 upstream of the feed water side and downstream of the waste heat steam generator 20 on the flue gas side.
  • the high pressure steam drum 72 is in turn connected to a high pressure evaporator 74 disposed in the heat recovery 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 is made of a Number of downpipes 102 connected to the steam drum 48 and a number of riser tubes 104 downstream of the latter.
  • 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 a 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 combined cycle power plant 1 is designed such that the level of liquid fluid in the downpipes 54, 102 of the medium pressure evaporator circuit 52 and of 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 or 94.
  • the tube wall material of the downpipes 54, 102 downstream of the downcomers, convectively heated by contact with the flue gas R risers 56, 104 is selected in each case with respect to its temperature resistance such that its temperature limit above the in this Be rich of the heat recovery steam generator 20 normally present or maximum expected temperature of the flue gas R is.
  • the temperature of the flue gas R in the region of the medium-pressure evaporator 50 under ordinary circumstances about 300 0 C, in the region of the low-pressure evaporator 96 around 200 0 C.
  • the risers 56 of the medium-pressure evaporator 50 to a continuous temperature of about 400 0 C and the risers 104 of the low-pressure evaporator 96 are designed for a continuous temperature resistance of about 300 C, so there are usually sufficient safety reserves available to a temporary drying, z. B. during startup or shutdown of the gas and steam turbines plant 1 or during rapid load changes to tolerate.
  • the medium-pressure steam drum 44 and the low-pressure steam drum 48 can thus be made particularly compact, since the volume of liquid held to date with fluid to compensate for different steam production rates and ensure continuous feeding of the risers 56, 104 can be relatively small.
  • the gas and steam turbine plant 1 with a monitoring and control system designed specifically to monitor and control such operating conditions.
  • the gas and steam turbine plant 1 with a monitoring and control system designed specifically to monitor and control such operating conditions.
  • the monitoring of the low-pressure evaporator circuit 94 is as follows: In addition to the hitherto customary monitoring of the water level in the low-pressure steam drum 48, schematically indicated in Figure 2 by the double arrow 114, is now a filling level monitoring is provided, which also includes the downpipes 102 connected to the low-pressure steam drum 48, indicated here schematically by the double arrow 116.
  • a fill-level measuring device (not shown here) thus measures the height of the water column at the lowest point of the downpipes 102, which extends into the steam drum 48 during normal operation of the gas and steam turbine plant 1, but during special situations now also - as described above - can fall below the height level of the upper downpipe connections.
  • the filling level can also be provided to refer the filling level to the downpipe 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 and a level below it 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 Ti of the flue gas R prevailing in the region of the riser tubes 104, which in the exemplary embodiment according to FIG. 2 is arranged by a flow measuring device 118, which is only shown schematically in the flow direction of the flue gas R, just upstream of the riser tubes 104 in the heat recovery steam generator 20 or whose temperature sensor is detected.
  • the monitoring and control device is configured or programmed to initiate a safety measure in the downpipes 102 at least in an operating condition with a liquid level below the connection to the steam drum 48 as soon as the temperature Ti measured by the temperature measuring device 118 exceeds a predetermined limit - below.
  • This limit value can be predetermined in particular depending on the liquid level in the downpipes 102.
  • the temperature 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 0 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. B. at about 270 0 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 ⁇ "with completely flowed, ie not flow around condensate preheater 26.
  • the temperature load for the riser pipes 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 or in the downpipes 102 connected to it is increased again, so that potentially dangerous operating conditions due to the temporary dry operation of the dertik-Verdampferumlaufs 94 can be counteracted active and targeted as needed.
  • a temperature measuring device 126 arranged in the flue gas duct just before the risers 56 for measuring the flue gas temperature T 2 prevailing in the region of the risers 56.
  • 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, the smoke 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 Ia.
  • 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 in the bypass line 88 is opened, so that due to the above-described heat shifts in the heat recovery steam generator 20, the production of low-pressure steam and possibly also of medium-pressure steam throttled or even completely brought to a standstill.
  • 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.

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  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Engine Equipment That Uses Special Cycles (AREA)
  • Control Of Steam Boilers And Waste-Gas Boilers (AREA)

Abstract

La présente invention concerne un procédé permettant de faire fonctionner une installation de turbine à gaz et à vapeur (1). Selon l'invention, le gaz de fumée (R) issu d'une turbine à gaz (2) est guidé à travers un générateur de vapeur à récupération de chaleur (20) et un milieu en circulation utilisé pour entraîner une turbine à vapeur (12) est guidé dans un circuit de milieu en circulation (16) qui comprend un certain nombre d'étages de pression (40, 92, 100). Au moins un des étages de pression (100) présente un circuit d'évaporateur (94) avec un tambour à vapeur (48), comprenant un certain nombre de descentes (102) raccordées au tambour à vapeur (48), ainsi qu'un certain nombre de conduites montantes (104) qui sont placées en aval des descentes (102), qui sont raccordées également au tambour à vapeur (48) et qui sont chauffées par le gaz de fumée (R) dans le générateur de vapeur à récupération de chaleur (20). L'objectif de l'invention est de pouvoir adapter le mode d'exploitation de façon particulièrement flexible à différentes exigences, avec une grande fiabilité et une grande sécurité de fonctionnement, et de pouvoir concevoir de manière particulièrement économique les composants dudit circuit d'évaporateur (94). A cette fin, la hauteur de la colonne de liquide formée par le milieu en circulation dans les descentes (102) raccordées au tambour à vapeur (48) est contrôlée, ce qui permet de détecter et de protéger un fonctionnement à sec temporaire du circuit d'évaporateur (94).
EP08828009.4A 2007-01-30 2008-01-28 Procédé permettant de faire fonctionner une installation de turbine à gaz et à vapeur et installation de turbine à gaz et à vapeur conçue à cette fin Not-in-force EP2126291B1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
EP08828009.4A EP2126291B1 (fr) 2007-01-30 2008-01-28 Procédé permettant de faire fonctionner une installation de turbine à gaz et à vapeur et installation de turbine à gaz et à vapeur conçue à cette fin

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
EP07002014A EP2034137A1 (fr) 2007-01-30 2007-01-30 Procédé d'operation d'une installation à turbine à gaz et à vapeur et installation à turbine à gaz et à vapeur correspondante
PCT/EP2008/050954 WO2009024358A2 (fr) 2007-01-30 2008-01-28 Procédé permettant de faire fonctionner une installation de turbine à gaz et à vapeur et installation de turbine à gaz et à vapeur conçue à cette fin
EP08828009.4A EP2126291B1 (fr) 2007-01-30 2008-01-28 Procédé permettant de faire fonctionner une installation de turbine à gaz et à vapeur et installation de turbine à gaz et à vapeur conçue à cette fin

Publications (2)

Publication Number Publication Date
EP2126291A2 true EP2126291A2 (fr) 2009-12-02
EP2126291B1 EP2126291B1 (fr) 2016-03-16

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EP07002014A Withdrawn EP2034137A1 (fr) 2007-01-30 2007-01-30 Procédé d'operation d'une installation à turbine à gaz et à vapeur et installation à turbine à gaz et à vapeur correspondante
EP08828009.4A Not-in-force EP2126291B1 (fr) 2007-01-30 2008-01-28 Procédé permettant de faire fonctionner une installation de turbine à gaz et à vapeur et installation de turbine à gaz et à vapeur conçue à cette fin

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EP07002014A Withdrawn EP2034137A1 (fr) 2007-01-30 2007-01-30 Procédé d'operation d'une installation à turbine à gaz et à vapeur et installation à turbine à gaz et à vapeur correspondante

Country Status (6)

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

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Publication number Publication date
WO2009024358A3 (fr) 2009-04-23
US9429045B2 (en) 2016-08-30
US20100089024A1 (en) 2010-04-15
WO2009024358A2 (fr) 2009-02-26
CN101595279A (zh) 2009-12-02
EP2126291B1 (fr) 2016-03-16
PL2126291T3 (pl) 2016-09-30
EP2034137A1 (fr) 2009-03-11
RU2467250C2 (ru) 2012-11-20
CN101595279B (zh) 2012-11-28
RU2009132482A (ru) 2011-03-10

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