EP1193373A1 - Méthode pour opérer une installation à turbines à gaz et à vapeur et installation correspondante - Google Patents

Méthode pour opérer une installation à turbines à gaz et à vapeur et installation correspondante Download PDF

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Publication number
EP1193373A1
EP1193373A1 EP00121502A EP00121502A EP1193373A1 EP 1193373 A1 EP1193373 A1 EP 1193373A1 EP 00121502 A EP00121502 A EP 00121502A EP 00121502 A EP00121502 A EP 00121502A EP 1193373 A1 EP1193373 A1 EP 1193373A1
Authority
EP
European Patent Office
Prior art keywords
gas
steam
water
pressure
condensate
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Withdrawn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
EP00121502A
Other languages
German (de)
English (en)
Inventor
Erich Schmid
Werner Schwarzott
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 EP00121502A priority Critical patent/EP1193373A1/fr
Priority to TW090118999A priority patent/TW541392B/zh
Priority to DE50106221T priority patent/DE50106221D1/de
Priority to US10/381,847 priority patent/US6874322B2/en
Priority to PCT/EP2001/010749 priority patent/WO2002027154A1/fr
Priority to EP01978376A priority patent/EP1320665B1/fr
Priority to ES01978376T priority patent/ES2240527T3/es
Publication of EP1193373A1 publication Critical patent/EP1193373A1/fr
Withdrawn legal-status Critical Current

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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
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01F—MIXING, e.g. DISSOLVING, EMULSIFYING OR DISPERSING
    • B01F23/00—Mixing according to the phases to be mixed, e.g. dispersing or emulsifying
    • B01F23/40—Mixing liquids with liquids; Emulsifying
    • B01F23/45—Mixing liquids with liquids; Emulsifying using flow mixing
    • B01F23/451—Mixing liquids with liquids; Emulsifying using flow mixing by injecting one liquid into another
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01F—MIXING, e.g. DISSOLVING, EMULSIFYING OR DISPERSING
    • B01F23/00—Mixing according to the phases to be mixed, e.g. dispersing or emulsifying
    • B01F23/40—Mixing liquids with liquids; Emulsifying
    • B01F23/49—Mixing systems, i.e. flow charts or diagrams
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01F—MIXING, e.g. DISSOLVING, EMULSIFYING OR DISPERSING
    • B01F25/00—Flow mixers; Mixers for falling materials, e.g. solid particles
    • B01F25/30—Injector mixers
    • B01F25/31—Injector mixers in conduits or tubes through which the main component flows
    • B01F25/313—Injector mixers in conduits or tubes through which the main component flows wherein additional components are introduced in the centre of the conduit
    • B01F25/3132—Injector mixers in conduits or tubes through which the main component flows wherein additional components are introduced in the centre of the conduit by using two or more injector devices
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01F—MIXING, e.g. DISSOLVING, EMULSIFYING OR DISPERSING
    • B01F35/00—Accessories for mixers; Auxiliary operations or auxiliary devices; Parts or details of general application
    • B01F35/71—Feed mechanisms
    • B01F35/717—Feed mechanisms characterised by the means for feeding the components to the mixer
    • B01F35/71805—Feed mechanisms characterised by the means for feeding the components to the mixer using valves, gates, orifices or openings

Definitions

  • the invention relates to a method for operating a gas and steam turbine plant, which consists of both escaping with gas as well as oil operated gas turbine Flue gas is passed through a heat recovery steam generator whose heating surfaces in the water-steam cycle one one Number of steam turbine having pressure stages switched are, with preheated condensate in the heat recovery steam generator than compared to this feed water under high pressure heated and fed as steam to the steam turbine becomes.
  • the In a gas and steam turbine plant, the is relaxed Work equipment or flue gas contained in the gas turbine Heat to generate steam for use in a water-steam cycle switched steam turbine used.
  • the heat transfer takes place in a downstream of the gas turbine Heat recovery steam generator or boiler, in which heating surfaces in Form of tubes or tube bundles are arranged. This in turn are connected to the steam turbine water-steam cycle.
  • the water-steam cycle usually includes several, for example two or three, pressure levels, in each pressure stage as a heating surface and an evaporator and a superheater are provided.
  • a Such gas and steam turbine plant is, for example, out EP 0 523 467 B1.
  • the total amount of water in the water-steam cycle is dimensioned such that that leaving the heat recovery steam generator Flue gas due to heat transfer to a temperature is cooled from about 70 ° C to 100 ° C. this means especially that the heating surfaces exposed to the hot flue gas and pressure drums intended for water-steam separation are designed for full load or rated operation, at which currently achieves an efficiency of around 55% to 60% becomes.
  • the goal here is the temperature difference between that led over the individual heating surfaces Feed water and flue gas in every area of the To keep the heat recovery steam generator as low as possible.
  • a condensate preheater to warm up condensed water provided from the steam turbine.
  • the gas turbine of such a gas and steam turbine plant can be designed for operation with different fuels his. If the gas turbine is designed for heating oil and natural gas, heating oil is only used as fuel for the gas turbine for one short operating time, for example for 100 to 500h / a, than so-called backup to natural gas provided.
  • the gas and steam turbine plant usually primarily for natural gas operation the gas turbine designed and optimized. In order to with heating oil operation, especially when changing from gas operation on the oil operation, a sufficiently high entry temperature of the condensate flowing into the heat recovery steam generator ensure the necessary heat can be applied to different Way can be removed from the heat recovery steam generator itself.
  • One way is to completely preheat the condensate or partially to bypass and the condensate in one in the Water-steam cycle switched feed water tank heating by adding low pressure steam.
  • the method requires a large volume at low steam pressures and possibly multi-stage heating steam system in the Feed water tank, which is common for large heating ranges Degassing taking place in the feed water tank can endanger.
  • the invention has for its object a method for Operating a gas and steam turbine plant of the above Specify the way that at the same time low equipment and operating expenses in an effective way and in terms of system efficiency a convenient way of switching from Gas operation on oil operation of the gas turbine under cover wide temperature range of the inlet temperature of the in ensures the condensate flowing in the heat recovery steam generator. Furthermore, one should carry out the method particularly suitable gas and steam turbine plant specified become.
  • the object is achieved according to the invention by the features of claim 1. It is provided that that is under high pressure compared to the condensate and having a high temperature compared to the condensate Feed water via a pipe to the cold condensate is heat exchanger-free and is therefore mixed directly by when changing from gas to oil, a partial flow of heated feed water injected into the cold condensate and so that it is mixed.
  • the invention is based on the consideration that on one additional heat exchanger, which is the water-steam cycle withdrawn heated feed water or hot water before its pressure is reduced to the temperature level of the condensate system should cool, can be dispensed with if by injecting the hot water into the cold condensate targeted evaporation of the hot water and a subsequent one
  • the water-steam mixture that forms is condensed. This can cause the generation of steam, i. H. a Vapor formation can be allowed through the use of the additional Heat exchanger prevented after the pressure reduction shall be.
  • the removal depends essentially on the required Heating heat for the condensate and which system efficiency in the oil operation of the Gas turbine should at least be maintained.
  • the heated feed water or hot water is expedient in a two-printing system, i.e. H. in a two-pressure system from a high-pressure drum and a three-pressure system or in a three-pressure system from the high-pressure drum and / or from a medium pressure drum as Feed water partial flow removed.
  • a two-printing system i.e. H. in a two-pressure system from a high-pressure drum and a three-pressure system or in a three-pressure system from the high-pressure drum and / or from a medium pressure drum as Feed water partial flow removed.
  • the removal of the partial flow also at the outlet of the high-pressure economizer or the medium pressure economizer.
  • the pressure of the low-pressure system can also be used be raised to remove heat contained in the flue gas the low-pressure system downstream of the flue gas side
  • the water-steam cycle is in a suitable place withdrawn heated feed water in the form of a feed water partial flow without warming up beforehand, i.e. without heat exchange the cold condensate in an additional heat exchanger is added.
  • the system comprises a mixing device, about the cold condensate as a heating surface in the Heat recovery steam generator arranged condensate preheater supplied is.
  • a mixing device In the interior of the mixing device, via which Condensate flows, at least one spray head is arranged, via a hot water pipe from the water-steam cycle withdrawn heated feed water or hot water is feedable.
  • the first thing to avoid is in the hot water pipe under pressure, i.e. the partial flow of heated feed water by opening one Fitting upstream of the or each spray head for flow brought.
  • the result is a preferably spring-loaded Valve cone of a valve provided in the spray head Differential pressure between the partial flow and the over the The valve cone lifts the condensate from the mixing device Valve seat off, allowing water through different holes or valve channels to a number of spray nozzles.
  • the Flow through the narrow valve channels and spray nozzles leads to an increasing pressure reduction.
  • the advantages achieved with the invention are in particular in that one required when operating the gas turbine in oil and increased compared to gas operation of the gas turbine Water inlet temperature in the heat recovery steam generator too without additional heat exchanger or external condensate preheater by spraying from below high without heat exchanger Pressurized feed water into the cold condensate with special simple means is adjustable. It can by suitable design from within a provided Spray heads arranged one below the Boiling temperature of the preheated or preheated condensate lying mixing temperature of the with the cold condensate partial flow mixed with oil operation on particularly simple and be made effectively.
  • the capacity reserves can also be used in this way the high pressure feed water pump can be used because usually due to oil operation compared to gas operation a lower gas turbine output also lower Flow rates are required.
  • the circuitry in a particularly effective way extended operating range standardization is also possible.
  • the investment costs are particularly low.
  • the gas and steam turbine system 1 comprises a gas turbine system 1a and a steam turbine system 1b.
  • the gas turbine system 1 a comprises a gas turbine 2 with a coupling Air compressor 4 and one of the gas turbine 2 upstream Combustion chamber 6, which is connected to a fresh air line 8 of the Air compressor 4 is connected.
  • a fuel line 10 opens out, via which the combustion chamber 6 optionally gas or oil can be supplied as fuel B. This becomes compressed with the supply of compressed air L or Fuel gas burned for the gas turbine 2.
  • the gas turbine 2 and the air compressor 4 and a generator 12 sit on one common turbine shaft 14.
  • the steam turbine system 1b also includes a steam turbine 20 coupled generator 22 and in a water-steam cycle 24 one of the steam turbine 20 downstream capacitor 26 and a heat recovery steam generator 30.
  • the steam turbine 20 has a first pressure stage or a high pressure part 20a and a second pressure stage or a medium pressure part 20b and a third pressure stage or a low pressure part 20c on the generator via a common turbine shaft 32 22 drive.
  • Exhaust line 34 For supplying working fluid relaxed in the gas turbine 2 or flue gas AM in the heat recovery steam generator 30 is one Exhaust line 34 to an input 30a of the heat recovery steam generator 30 connected. That is along the heat recovery steam generator 30 as a result of indirect heat exchange with in the water-steam cycle 24 guided condensate K and feed water S cooling flue gas AM from the gas turbine 2 leaves the heat recovery steam generator 30 via its exit 30b in the direction of a fireplace, not shown.
  • the heat recovery steam generator 30 comprises one as heating surfaces Condensate preheater 36, the input side via a condensate line 38, into which a condensate pump 40 is connected, is fed with condensate K from the condenser 26.
  • the Condensate preheater 36 is on the outlet side to the suction side Feed water pump 42 out.
  • a mixing device 44 with a tubular hot water mixer 46 switched.
  • the feed water pump 42 is included as a high pressure feed pump Medium pressure extraction trained. It brings the condensate K to one for the high pressure part 20 a of the steam turbine 20 assigned high pressure stage 50 of the water-steam circuit 24 suitable pressure level from about 120 bar to 150 bar. About the The condensate K is removed by means of the feed water pump 42 to one for the medium pressure part 20b of the Steam turbine 20 associated medium pressure stage 70 suitable Pressure level from about 40 bar to 60 bar.
  • the feed water S is also partially with medium pressure via a non-return flap 71 and a downstream one Valve 72 a feed water preheater or medium pressure economizer 73 fed. This is on the output side via a valve 74 connected to a medium pressure drum 75. Analogous is part of the low pressure part 20c of the steam turbine 20 assigned low pressure level 90 of the water-steam cycle 24 of the condensate preheater 36 on the output side Valve 91 connected to a low pressure drum 92.
  • the medium pressure drum 75 is in the heat recovery steam generator 30 arranged medium pressure evaporator 76 for formation a water-steam circuit 77 connected. On the steam side is on the medium pressure drum 75 is connected to a reheater 78, the output side (hot ZÜ) to an input 79 of the medium pressure part 20b is guided and in the input side (cold ZÜ) one with an outlet 80 of the high pressure part 20a of the steam turbine 20 connected exhaust steam line 81 is.
  • the feed water pump 42 is on the high-pressure side via two valves 55, 56 and the first high-pressure economizer 51 and the downstream of this and on the feed water side of the heat recovery steam generator 30 upstream on the flue gas side second high-pressure economizer 52 and one if necessary provided further valve 57 to the high pressure drum 54 guided.
  • This is in turn with one in the heat recovery steam generator 30 arranged high pressure evaporator 58 to form a Water-steam circulation 59 connected.
  • For removing live steam F is the high pressure drum 54 to one in the heat recovery steam generator 30 arranged high pressure superheater 60 connected, the output side with an inlet 61 of the high pressure part 20a of the steam turbine 20 is connected.
  • a steam line 95 connected to an inlet 96 of the low pressure part 20c.
  • An outlet 99 of the low pressure part 20c is via a steam line 100 connected to the capacitor 26.
  • the gas turbine 2 of the gas and steam turbine system 1 is both can be operated with natural gas as well as with heating oil as fuel B.
  • the temperature TS of the partial flow is tS when it is withdrawn as heated feed water S 'from the high pressure drum 54, for example 320 ° C.
  • FIG. 2 shows a preferred embodiment of the mixing device 44 or the hot water mixer 46.
  • This instructs one the condensate line 38 connected inlet 111 for feeding the cold condensate K into the mixing device 44 and an outlet opening 112 through which the mixing device 44 connected to the condensate preheater 36 on the input side is.
  • the tubular heating water mixer 46 of the mixing device 44 is thus switched on in the condensate line 38.
  • In the interior 104 of the mixing device 44 are in Embodiment three spray heads 105 arranged. Depending on necessary amount of heating water and the temperature can do more or fewer such spray heads 105 within the hot water mixer 46 may be provided.
  • FIG. 3 is the respective spray head 105 via an installation flange 113 Welding end 114 into the interior through a flange opening 115 104 of the hot water mixer 46 out and in each desired position held.
  • the spray head 105 is executed self-opening and has a valve seat 116 and a valve cone 117 formed valve.
  • the valve cone 117 is a due to the spring force Sealing spring assembly 118 in the closed position of the valve led against the valve seat 116.
  • Hot water or heated feed water S ' i.e. the set Partial stream tS by opening one or each spray head 105 upstream shut-off valve 119 (FIG 2) for flow brought.
  • the valve cone 117 that is thereby spring-loaded
  • the existing differential pressure automatically lifts it from the valve seat 116 from. This causes what is referred to below as hot water HW to flow heated feed water S 'over one in the area of the valve seat 117 provided annulus 120 and thereby connected bores or valve channels 121 to a number of spray nozzles 122.
  • hot water HW to flow heated feed water S 'over one in the area of the valve seat 117 provided annulus 120 and thereby connected bores or valve channels 121 to a number of spray nozzles 122.
  • Four to six spray nozzles 122 distributed around the circumference of the spray head 105 arranged.
  • the flow of hot water HW through the narrow holes or valve channels 121 and spray nozzles 122 leads to an increasing Pressure reduction. If the boiling conditions are exceeded in the area of the spray nozzles 122 part of the hot water HW evaporates and the resulting mixture is finely distributed. In addition, the remaining hot water HW by evaporation cooled. Heated by the injection of the partial flow ts Feed water S 'or hot water HW and the effective Mixing with which the spray heads 105 in the interior 104 the cold condensate K surrounding the measuring device 44 resulting small vapor bubbles condense again and together brought to a mixing temperature with the hot water HW, those below the boiling temperature at this pressure lies.
  • the spray heads 105 are each via a supply or intermediate line 123 with the hot water pipe 101 on the outflow side the shut-off valve 119 connected. So depending on Number of spray heads 105 provided or required a corresponding number of intermediate lines 123 to the Hot water line 101 can be connected. This is both the constructive as well as the manufacturing or assembly technology Effort for the respective design of the mixing device 44.46 particularly low.

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  • Chemical & Material Sciences (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Engineering & Computer Science (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Engine Equipment That Uses Special Cycles (AREA)
  • Investigating, Analyzing Materials By Fluorescence Or Luminescence (AREA)
EP00121502A 2000-09-29 2000-09-29 Méthode pour opérer une installation à turbines à gaz et à vapeur et installation correspondante Withdrawn EP1193373A1 (fr)

Priority Applications (7)

Application Number Priority Date Filing Date Title
EP00121502A EP1193373A1 (fr) 2000-09-29 2000-09-29 Méthode pour opérer une installation à turbines à gaz et à vapeur et installation correspondante
TW090118999A TW541392B (en) 2000-09-29 2001-08-03 Method to operate a gas-and steam-turbine-device and the corresponding device
DE50106221T DE50106221D1 (de) 2000-09-29 2001-09-17 Verfahren zum betreiben einer gas- und dampfturbinenanlage sowie entsprechende anlage
US10/381,847 US6874322B2 (en) 2000-09-29 2001-09-17 Method for operating a gas and steam turbine system and a corresponding system
PCT/EP2001/010749 WO2002027154A1 (fr) 2000-09-29 2001-09-17 Procede pour l'exploitation d'une installation de turbines a vapeur et a gaz et installation correspondante
EP01978376A EP1320665B1 (fr) 2000-09-29 2001-09-17 Procede pour l'exploitation d'une installation de turbines a vapeur et a gaz et installation correspondante
ES01978376T ES2240527T3 (es) 2000-09-29 2001-09-17 Procedimiento para el acondicionamiento de una planta de turbinas de gas y de vapor asi como una planta correspondiente.

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
EP00121502A EP1193373A1 (fr) 2000-09-29 2000-09-29 Méthode pour opérer une installation à turbines à gaz et à vapeur et installation correspondante

Publications (1)

Publication Number Publication Date
EP1193373A1 true EP1193373A1 (fr) 2002-04-03

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Family Applications (2)

Application Number Title Priority Date Filing Date
EP00121502A Withdrawn EP1193373A1 (fr) 2000-09-29 2000-09-29 Méthode pour opérer une installation à turbines à gaz et à vapeur et installation correspondante
EP01978376A Expired - Lifetime EP1320665B1 (fr) 2000-09-29 2001-09-17 Procede pour l'exploitation d'une installation de turbines a vapeur et a gaz et installation correspondante

Family Applications After (1)

Application Number Title Priority Date Filing Date
EP01978376A Expired - Lifetime EP1320665B1 (fr) 2000-09-29 2001-09-17 Procede pour l'exploitation d'une installation de turbines a vapeur et a gaz et installation correspondante

Country Status (6)

Country Link
US (1) US6874322B2 (fr)
EP (2) EP1193373A1 (fr)
DE (1) DE50106221D1 (fr)
ES (1) ES2240527T3 (fr)
TW (1) TW541392B (fr)
WO (1) WO2002027154A1 (fr)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2010042400A2 (fr) 2008-10-09 2010-04-15 Alstom Technology Ltd Sphere de mélange de systeme de demarrage

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US8321498B2 (en) * 2005-03-01 2012-11-27 Oracle International Corporation Policy interface description framework
US7934383B2 (en) * 2007-01-04 2011-05-03 Siemens Energy, Inc. Power generation system incorporating multiple Rankine cycles
US8596073B2 (en) * 2008-07-18 2013-12-03 General Electric Company Heat pipe for removing thermal energy from exhaust gas
US8186152B2 (en) * 2008-07-23 2012-05-29 General Electric Company Apparatus and method for cooling turbomachine exhaust gas
US8359824B2 (en) * 2008-07-29 2013-01-29 General Electric Company Heat recovery steam generator for a combined cycle power plant
US8157512B2 (en) * 2008-07-29 2012-04-17 General Electric Company Heat pipe intercooler for a turbomachine
US8425223B2 (en) * 2008-07-29 2013-04-23 General Electric Company Apparatus, system and method for heating fuel gas using gas turbine exhaust
US20100064655A1 (en) * 2008-09-16 2010-03-18 General Electric Company System and method for managing turbine exhaust gas temperature
US8240149B2 (en) * 2009-05-06 2012-08-14 General Electric Company Organic rankine cycle system and method
US9696027B2 (en) * 2009-12-21 2017-07-04 General Electric Technology Gmbh Economizer water recirculation system for boiler exit gas temperature control in supercritical pressure boilers
US9003763B2 (en) * 2012-10-04 2015-04-14 Lightsail Energy, Inc. Compressed air energy system integrated with gas turbine
US10180086B2 (en) * 2013-09-26 2019-01-15 Nooter/Eriksen, Inc. Heat exchanging system and method for a heat recovery steam generator
US10337357B2 (en) * 2017-01-31 2019-07-02 General Electric Company Steam turbine preheating system with a steam generator

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US3702619A (en) * 1971-01-28 1972-11-14 Shell Oil Co In-line mixing apparatus for gases
EP0281151A2 (fr) * 1987-03-05 1988-09-07 Babcock-Hitachi Kabushiki Kaisha Systéme de récupération
US4869595A (en) * 1983-08-01 1989-09-26 James M. Montgomery, Consulting Engineers, Inc. Hydraulic diffusion flash mixing
EP0523467B1 (fr) 1991-07-17 1996-02-28 Siemens Aktiengesellschaft Procédé pour opérer une installation à turbines à gaz et à vapeur et installation pour la mise en oeuvre du procédé
DE19512466C1 (de) * 1995-04-03 1996-08-22 Siemens Ag Verfahren zum Betreiben eines Abhitzedampferzeugers sowie danach arbeitender Abhitzedampferzeuger
DE19736889C1 (de) 1997-08-25 1999-02-11 Siemens Ag Verfahren zum Betreiben einer Gas- und Dampfturbinenanlage und Gas- und Dampfturbinenanlage zur Durchführung des Verfahrens

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US3756023A (en) * 1971-12-01 1973-09-04 Westinghouse Electric Corp Heat recovery steam generator employing means for preventing economizer steaming
DE3804605A1 (de) * 1988-02-12 1989-08-24 Siemens Ag Verfahren und anlage zur abhitzedampferzeugung
EP0582898A1 (fr) * 1992-08-10 1994-02-16 Siemens Aktiengesellschaft Méthode de fonctionnement d'un système à turbines à vapeur et à gaz et système pour la mise en oeuvre de la méthode
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Publication number Priority date Publication date Assignee Title
US3702619A (en) * 1971-01-28 1972-11-14 Shell Oil Co In-line mixing apparatus for gases
US4869595A (en) * 1983-08-01 1989-09-26 James M. Montgomery, Consulting Engineers, Inc. Hydraulic diffusion flash mixing
EP0281151A2 (fr) * 1987-03-05 1988-09-07 Babcock-Hitachi Kabushiki Kaisha Systéme de récupération
EP0523467B1 (fr) 1991-07-17 1996-02-28 Siemens Aktiengesellschaft Procédé pour opérer une installation à turbines à gaz et à vapeur et installation pour la mise en oeuvre du procédé
DE19512466C1 (de) * 1995-04-03 1996-08-22 Siemens Ag Verfahren zum Betreiben eines Abhitzedampferzeugers sowie danach arbeitender Abhitzedampferzeuger
DE19736889C1 (de) 1997-08-25 1999-02-11 Siemens Ag Verfahren zum Betreiben einer Gas- und Dampfturbinenanlage und Gas- und Dampfturbinenanlage zur Durchführung des Verfahrens

Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2010042400A2 (fr) 2008-10-09 2010-04-15 Alstom Technology Ltd Sphere de mélange de systeme de demarrage
WO2010042400A3 (fr) * 2008-10-09 2011-01-27 Alstom Technology Ltd Sphere de mélange de systeme de demarrage
CN102177315A (zh) * 2008-10-09 2011-09-07 阿尔斯托姆科技有限公司 启动系统混合球
US8230686B2 (en) 2008-10-09 2012-07-31 Banas John M Start-up system mixing sphere
CN102177315B (zh) * 2008-10-09 2014-12-24 阿尔斯托姆科技有限公司 启动系统混合球

Also Published As

Publication number Publication date
WO2002027154A1 (fr) 2002-04-04
EP1320665B1 (fr) 2005-05-11
US6874322B2 (en) 2005-04-05
US20040011049A1 (en) 2004-01-22
EP1320665A1 (fr) 2003-06-25
ES2240527T3 (es) 2005-10-16
DE50106221D1 (de) 2005-06-16
TW541392B (en) 2003-07-11

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