EP0783619A1 - Procede permettant de faire fonctionner une installation a turbines a gaz et a vapeur, et installation fonctionnant selon ce procede - Google Patents

Procede permettant de faire fonctionner une installation a turbines a gaz et a vapeur, et installation fonctionnant selon ce procede

Info

Publication number
EP0783619A1
EP0783619A1 EP95931137A EP95931137A EP0783619A1 EP 0783619 A1 EP0783619 A1 EP 0783619A1 EP 95931137 A EP95931137 A EP 95931137A EP 95931137 A EP95931137 A EP 95931137A EP 0783619 A1 EP0783619 A1 EP 0783619A1
Authority
EP
European Patent Office
Prior art keywords
steam
gas
turbine
steam generator
partial flow
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
EP95931137A
Other languages
German (de)
English (en)
Other versions
EP0783619B1 (fr
Inventor
Hermann Brückner
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 EP97117410A priority Critical patent/EP0822320B1/fr
Publication of EP0783619A1 publication Critical patent/EP0783619A1/fr
Application granted granted Critical
Publication of EP0783619B1 publication Critical patent/EP0783619B1/fr
Anticipated expiration legal-status Critical
Expired - Lifetime legal-status Critical Current

Links

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
    • 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
    • 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
    • F01K23/103—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 afterburner in exhaust boiler

Definitions

  • the invention relates to a method for operating a gas and steam turbine system, in which the oxygen-containing exhaust gas from the gas turbine is used to generate steam.
  • the invention is further directed to a gas and steam turbine plant operating according to this method.
  • the combined process with a downstream fossil-fired steam generator is suitable for retrofitting an existing steam turbine system with a gas turbine system.
  • the upstream gas turbine is intended to serve the purpose of increasing efficiency and performance in the sense of a so-called topping process.
  • Such a thermal power plant with a combined gas-steam process is known for example from DE-OS 14 26 443.
  • the outputs of the steam turbine and the gas turbine and of the fired steam generator are dependent on one another, so that they must be coordinated with one another when designing such a system. This applies not only to the retrofitting of an existing steam turbine plant, but also to a new plant.
  • the tuning is usually carried out in such a way that the oxygen demand of the fired steam generator can be covered by the exhaust gases from the gas turbine during nominal load operation.
  • gas turbines with only a few different output sizes, for example with 50 MW, 150 MW or 200 MW, are manufactured and offered, so that their adaptation to the output of the steam turbine and that of the steam generator is extremely difficult.
  • the gas turbine therefore delivers either too large or too small an exhaust gas quantity in the full-load range in comparison to the quantity of exhaust gas required as combustion air for the fired steam generator. If the amount of exhaust gas is too small, the system can only achieve low efficiency in the full load range, which then becomes better in the partial load range.
  • an excessive amount of exhaust gas from the gas turbine can lead to the fact that in the case of a combined process in which the excess exhaust gases from the gas turbine are passed a combustion chamber of the fired steam generator to a boiler or feed water preheater (economizer) due to the excessive heat input, undesirably gets into the evaporation. Or if the amount of exhaust gas in the partial load range is too large, the power of the gas turbine must be reduced at an early stage. However, with increasing reduction in the power of the gas turbine, the efficiency of the system decreases in the part-load range. In other words, the overall efficiency achieved is only limited in both cases. In particular when retrofitting an existing steam turbine system, an increase in output from the gas turbine must therefore be dispensed with if the The exhaust gas heat of the gas turbine cannot be fully used or an acceptable part-load behavior cannot be achieved.
  • the combination process with a downstream heat recovery steam generator is particularly suitable for retrofitting an existing gas turbine system.
  • a number of gas turbines with a corresponding number of heat recovery steam generators are usually switched to a common steam turbine. Since the steam generation in this combination process is limited to pure heat recovery, the overall efficiency of the system is also only limited.
  • the invention is therefore based on the object of specifying a method for operating a gas and steam turbine installation, in which the use of a gas turbine which can be freely selected from a large number of gas turbines of different output sizes is possible with a particularly high overall efficiency of the installation. In a gas and steam turbine plant, this is to be achieved with particularly simple means.
  • this object is achieved according to the invention in that a first partial flow of the exhaust gas from the gas turbine is used for the combustion of a fossil fuel for steam generation, and in that a second partial flow of the exhaust gas from the gas turbine is used for the heat recovery steam generator. is used. Both steam generation by combustion of the fossil fuel and waste heat generation take place in a common water-steam circuit of the steam turbine.
  • the invention is based on the consideration that by combining the pure use of waste heat and the use as combustion air, a division of these types of use of the exhaust gas from the gas turbine can be optimally coordinated with regard to the overall efficiency of the plant, regardless of its size.
  • feed water of the water-steam cycle which is under high pressure, is advantageously preheated in partial streams, the preheating of a first partial stream of the feed water being carried out by means of flue gas produced during the combustion of the fossil fuel.
  • a second partial flow of the feed water is preheated by means of the second partial flow of the exhaust gas from the gas turbine flowing through the heat recovery steam generator.
  • a third partial flow of the feed water is preheated by means of bleed steam from the steam turbine.
  • the three partial flows of the feed water are expediently preheated in several stages, the preheating of the first partial flow and the third partial flow taking place in a common second preheating stage by means of the flue gas generated during the combustion of the fossil fuel.
  • a large range of fuels can advantageously be used in the fired steam generator.
  • oil, gas, coal or special fuels such as garbage, wood or waste oil can be used as fossil fuel.
  • a cold air stream can expediently be mixed with the first partial stream of the exhaust gas from the gas turbine, which serves as combustion air.
  • the still oxygen-containing exhaust gas from the gas turbine with, for example, 15% oxygen content serves as the sole combustion air for the fossil fuels to be burned in the fired steam generator, the fired steam generator being expediently only charged with the amount of exhaust gas required for combustion.
  • a possibly provided flue gas cleaning system therefore only has to be designed for the first partial flow of the exhaust gas from the gas turbine and not for the total quantity of exhaust gas, this first partial flow of the exhaust gas serving as combustion air from the gas turbine together with that in the Combustion of the fossil fuel flue gas is cleaned.
  • the object is achieved according to the invention with a fossil-fired steam generator connected to a water-steam circuit of the steam turbine, to which a waste heat steam generator is connected in parallel on the water / steam side, both the fired steam generator via a first partial flow line and the waste heat steam generator via a second Partial flow line of the gas turbine are connected downstream on the exhaust gas side.
  • the fired steam generator is followed by a flue gas cleaning system on the flue gas side. Since the flue gas cleaning system only has to be designed for the first partial flow of the exhaust gas from the gas turbine and for the quantity of flue gas generated in the fossil-fired steam generator, there are no problems with a new system or when retrofitting an old system with regard to a necessary limitation of the size of the cleaning system due to lack of space. An undesirable reduction in steam Generator power in the case of a cleaning system to be retrofitted, which due to the space available on site is only sufficient for a limited exhaust gas volume, is therefore not necessary.
  • the fired steam generator is preceded by a series connection of two flue gas-heated high-pressure preheaters on the water / steam side.
  • the entire feed water supplied to the fired steam generator is preheated in a first high-pressure preheater or boiler economizer, while in a second high-pressure preheater or boiler part economizer connected downstream of the boiler economizer, only the first partial flow of the feed water is preheated.
  • the steam turbine process can be constructed from one or more pressure stages.
  • a two-pressure system with intermediate superheating and condensate preheating is expediently provided.
  • the waste heat steam generator comprises a condensate preheater and a medium-pressure heating surface connected upstream of this on the flue gas side with an intermediate superheater and, advantageously, high-pressure heating surfaces arranged at least partially in parallel with this on the flue gas side and parallelly connected on the water / steam side.
  • the intermediate superheater arranged in the waste heat steam generator is connected in parallel with a further intermediate superheater of the fired steam generator, which is expediently provided.
  • the advantages achieved by the invention are, in particular, that by combining a fired steam generator and a waste heat steam generator with simultaneous distribution of the exhaust gas from the gas turbine in the steam generators, partial streams supplied not only in the fired steam generator, a large fuel spectrum, eg coal, heavy oil, weak gases or special fuels such as garbage, wood or Waste oil, can be used. Rather, with a decreasing boiler output of the fired steam generator due to a fuel conversion from, for example, oil to coal or due to a conversion to a low-nitrogen oxide firing, a particularly high steam turbine output and thus a higher system efficiency due to the additional steam generator output can nevertheless be achieved the heat recovery steam generator are maintained.
  • FIG. 1 shows a circuit diagram of a combined gas and steam turbine system with the gas turbine connected downstream of both a fossil-fired steam generator and a waste heat steam generator.
  • the gas and steam turbine system 1 comprises a gas turbine system with a gas turbine 2 with a coupled air compressor 3 and a combustion chamber 4 connected upstream of the gas turbine 2 and connected to a fresh air line 5 of the air supply. poet 3 is connected.
  • a fuel or fuel gas line 6 opens into the combustion chamber 4 of the gas turbine 2.
  • the gas turbine 2 and the air compressor 3 as well as a generator 7 sit on a common shaft 8.
  • the gas and steam turbine system 1 further comprises a steam turbine system with a steam turbine 10 with a coupled generator 11 and, in a water-steam circuit 12, a condenser 13 downstream of the steam turbine 10 and a fired steam generator 14 and a waste heat steam generator 15.
  • the steam turbine 10 consists of a high-pressure part 10a and a medium-pressure part 10b and a low-pressure part 10c, which drive the generator 11 via a common shaft 16.
  • a first partial flow line 18 is connected to an inlet 14a of the fired steam generator 14 in order to supply working fluid or exhaust gas A relaxed in the gas turbine 2 to the fired steam generator 14.
  • a first partial flow t 1 of the exhaust gas A from the gas turbine 2 with an oxygen content of approx. 15%, which is conducted via the partial flow line 18, serves as combustion air during the combustion of a gaseous, liquid or solid fuel B.
  • fuel line 20 connected to an inlet 14b of the fired steam generator 14 leads into the fired steam generator 14.
  • a control flap 22 connected to the partial flow line 18 is provided for setting the first partial flow t ⁇ .
  • Partial flow t ⁇ of the exhaust gas A from the gas turbine 2 leave the fired steam generator 14 via a flue gas line 24 and after cleaning it in a cleaning system 26 in the direction of a chimney (not shown).
  • the flue gas cleaning system 26 comprises a flue gas desulfurization device and a denitrification device (DeNO x system) and a dedusting device in a manner not shown.
  • a second partial flow line 28 with a control flap 29 is connected to an inlet 15a of the waste heat steam generator 15.
  • the partial stream t2 of the relaxed exhaust gas A from the gas turbine 2 leaves the heat recovery steam generator 15 via its outlet 15b in the direction of the chimney.
  • a third partial flow line or bypass line 30 with a flap 32 is used - e.g. when starting up and shutting down the system 1 - the exhaust gas A required neither for the fired steam generator 14 nor for the waste heat steam generator 15 is led out of the gas turbine 2.
  • this bypass line 30 serves, however, to discharge the exhaust gas A from the gas turbine 2 when it is operated alone in the so-called single-cycle mode.
  • a fresh air line 34 into which a blower 36 and a steam-heated heat exchanger 38 and a flap 40 are connected, opens into the partial flow line t ⁇ _.
  • cold fresh air KL can be mixed into partial stream t 1 of exhaust gas A from gas turbine 2 via this fresh air line 34.
  • the heat recovery steam generator 15 comprises, as heating surfaces, a preheater 42, between the inlet and outlet of which a circulation pump 44 is connected.
  • the preheater 42 is connected on the input side to the output of a condensate preheater 46 which is connected on the input side to the condenser 13 via a condensate pump 48.
  • the condensate preheater 46 is heated with steam via a bleed line 50 connected to the low-pressure part 10c of the steam turbine 10.
  • the waste heat steam generator 15 further comprises, as heating surfaces, a medium-pressure preheater or economizer 62 and a medium-pressure evaporator 64 and a medium-pressure superheater 66, the output side of which is connected to a steam line 68 connected to the high-pressure part 10a of the steam turbine 10 and to a branch ⁇ superheater 70 is connected.
  • the medium-pressure heating surfaces 62, 64, 66 are connected via the reheater 70 to a steam line 72 opening into the medium-pressure part 10b of the steam turbine 10.
  • the medium-pressure heating surfaces 62, 64, 66 and the intermediate superheater 70 and the medium-pressure part 10b of the steam turbine 10 thus form a medium-pressure stage of the water-steam circuit 12.
  • the heat recovery steam generator 15 further comprises two high-pressure evaporators or economizers 74 and 75 connected in series as heating surfaces, as well as a high-pressure evaporator 76 and a high-pressure superheater 78.
  • the high-pressure superheater 78 is on the output side via a Steam line 80 is connected to the inlet of the high pressure part 10a of the steam turbine 10.
  • the medium-pressure economizer 62 and the high-pressure economizer 74, 75 are arranged within the heat recovery steam generator 15 in the region of the same exhaust gas temperature
  • the high-pressure evaporator 76 and the high-pressure superheater 78 are in the flow direction of the partial stream t2 of the exhaust gas A from the gas turbine 2 before the series connection of the medium-pressure evaporator 64 and the medium-pressure superheater 66, the intermediate superheater 70 and the high-pressure superheater 78 being arranged in the region of the same exhaust gas temperature.
  • the feed water tank 60 is connected to the fired steam generator 14 via a high-pressure pump 82 and a heat exchanger arrangement with a series connection of three preheaters 84, 86, 88.
  • the feed water tank 60 is also connected to the medium-pressure economizer 62 via a medium-pressure pump 90.
  • a partial flow line 92a is connected to a feed water line 92 leading into the fired steam generator 14, which is connected via a boiler part economizer 94 between the preheaters 86 and 88 to the feed water line 92. This is also connected to the high-pressure economizer 74 via a further partial flow line 92b.
  • the boiler part converter 94 and the preheater or boiler economizer 88 are switched into the flue gas line 24 of the fired steam generator 14.
  • the fired steam generator 14 is connected to the input of the high pressure part 10a of the steam turbine 10 via a high-pressure superheater 96, to which the steam line 80 is connected on the output side.
  • An intermediate superheater 70 arranged in parallel in the heat recovery steam generator 15 is connected on the inlet side via the steam line 68 to the outlet of the high pressure part 10a and on the outlet side to the medium pressure part 10b of the steam turbine 10.
  • the preheaters 84 and 86 are heated via steam lines 100 and 102 by means of bleed steam from the medium pressure part 10b and the high pressure part 10a of the steam turbine 10.
  • a fuel B ' is supplied to the combustion chamber 4 of the gas turbine 2 in a manner not shown in detail via the fuel line 6.
  • the fuel B ' is burned in the combustion chamber 4 with compressed fresh air L from the air compressor 3.
  • the hot combustion gas V formed during the combustion is conducted into the gas turbine 2 via a gas line 6a. There it relaxes and drives the gas turbine 2, which in turn drives the air compressor 3 and the generator 7. That from the gas turbine 2 Hot exhaust gas A is passed in the first partial flow t ⁇ _ via the partial flow line 18 as combustion air into the fired steam generator 14.
  • the second partial flow t2 of the hot exhaust gas A from the gas turbine 2 is conducted via the partial flow line 28 and through the heat recovery steam generator 15.
  • the hot flue gas R which arises from the gas turbine 2 during the combustion of the fossil fuel B while supplying the partial flow t ⁇ of the exhaust gas A serves there to generate steam and then leaves the fired steam turbine 14 via the flue gas line 24 in the direction of the flue gas cleaning device location 26, wherein it was first cooled in the boiler economizer 88 and then in the boiler part economizer 94 by heat exchange with feed water from the feed water container 60.
  • the feed water is preheated in three partial flows S] _ to S3.
  • a first partial flow S 1 of the feed water under high pressure which is adjustable by means of a valve 104 connected to the partial flow line 92 a, is passed through the boiler part economizer 94 and by means of the flue gas R and the partial flow t] _ of the exhaust gas A of the gas turbine 2 preheated.
  • the preheating of the feed water both for the fired steam generator 14 and for the waste heat steam generator 15 thus takes place in several stages.
  • a two-stage preheating of the feed water partial stream S2 takes place within the heat recovery steam generator 15 in the water / steam side interconnected high-pressure economizers 74 and 75.
  • the feed water for the fired steam generator 15 is preheated in three stages.
  • the third partial flow S3, preheated in two stages in the preheaters 84 and 86, is then preheated in the common third stage together with the partial flow S ⁇ preheated in the boiler part economizer 94 in the boiler economizer 88.
  • This multi-stage preheating of the feed water in three partial streams S 3 to S 3 enables a particularly advantageous distribution or division of the feed water between the two steam generators 14 and 15, so that undesired evaporation within their gas-heated preheaters 74, 75 and 88, respectively, 94 due to an increased heat input from the partial flows t] _ and t2 of the exhaust gas A from the gas turbine 2 and from the flue gas R is practically avoided even when a particularly powerful gas turbine 2 is used.
  • the steam generated in the heat recovery steam generator 15 in the high pressure evaporator 76 and superheated in the high pressure superheater 78 is conducted together with the steam generated in the fired steam generator 14 and superheated in the superheater 96 into the high pressure part 10a of the steam turbine 10.
  • the steam partially expanded in the high pressure part 10a is partly overheated again in the superheater 70 arranged in the waste heat steam generator 15 and partly in the intermediate superheater 98 of the fired steam generator 14 and then fed to the medium pressure part 10b of the steam turbine 10.
  • the steam which is further released in the medium pressure part 10b is used partly for heating the feed water in the feed water tank 60 and partly for preheating the feed water partial flow S3 passed through the preheater 84, and partly directly into the low pressure part 10c of the steam turbine 10.
  • the steam released in the low-pressure part 10c is used via the bleed lines 50 to 54 for preheating condensate K fed into the feed water tank 60.
  • the steam emerging from the low-pressure part 10c is condensed in the condenser 13 and in as condensate K via the condensate pump 48 and the preheaters 46, 56 and 58 in promoted the feed water tank 60.
  • the water-steam circuit 12 that is common to the fired steam generator 14 and the waste heat steam generator 15 is thus closed.

Landscapes

  • 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)

Abstract

Procédé permettant de faire fonctionner une installation à turbines à gaz et à vapeur (1), dans lequel les gaz d'échappement (A) provenant de la turbine à gaz (2) sont utilisés pour la production de vapeur. En vue de pouvoir sélectionner facilement un modèle de turbine à gaz, indépendamment de ses performances et de manière à réduire les pertes en gaz d'échappement, qu'il s'agisse d'une installation nouvelle ou du rééquipement d'une installation déjà existante, le procédé selon l'invention est caractérisé en ce qu'un premier courant partiel (t1) de gaz d'échappement (A) provenant de la turbine à gaz (2) est utilisé comme air de combustion pour la combustion d'un combustible fossile (B) et en ce qu'un deuxième courant partiel (t2) de gaz d'échappement (A) provenant de la turbine à gaz (2) est utilisé pour la production de vapeur par la chaleur perdue. A cet effet, pour la production de vapeur, une combinaison d'un générateur de vapeur à combustible fossile (14) et d'un générateur de vapeur par la chaleur perdue (15) est connectée en aval de la turbine à gaz (2), côté gaz d'échappement, via une conduite d'écoulement partiel (respectivement (18) et (28)), la production de vapeur s'effectuant par combustion du combustible fossile (B), et la production de vapeur par la chaleur perdue s'effectuant dans un circuit commun eau-vapeur (12) de la turbine à vapeur (10).
EP95931137A 1994-09-27 1995-09-14 Procede permettant de faire fonctionner une installation a turbines a gaz et a vapeur Expired - Lifetime EP0783619B1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
EP97117410A EP0822320B1 (fr) 1994-09-27 1995-09-14 Installation à turbines à gaz et à vapeur

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
DE4434526A DE4434526C1 (de) 1994-09-27 1994-09-27 Verfahren zum Betreiben einer Gas- und Dampfturbinenanlage sowie danach arbeitende Anlage
DE4434526 1994-09-27
PCT/DE1995/001263 WO1996010124A1 (fr) 1994-09-27 1995-09-14 Procede permettant de faire fonctionner une installation a turbines a gaz et a vapeur, et installation fonctionnant selon ce procede

Related Child Applications (1)

Application Number Title Priority Date Filing Date
EP97117410A Division EP0822320B1 (fr) 1994-09-27 1995-09-14 Installation à turbines à gaz et à vapeur

Publications (2)

Publication Number Publication Date
EP0783619A1 true EP0783619A1 (fr) 1997-07-16
EP0783619B1 EP0783619B1 (fr) 1998-06-03

Family

ID=6529324

Family Applications (2)

Application Number Title Priority Date Filing Date
EP97117410A Expired - Lifetime EP0822320B1 (fr) 1994-09-27 1995-09-14 Installation à turbines à gaz et à vapeur
EP95931137A Expired - Lifetime EP0783619B1 (fr) 1994-09-27 1995-09-14 Procede permettant de faire fonctionner une installation a turbines a gaz et a vapeur

Family Applications Before (1)

Application Number Title Priority Date Filing Date
EP97117410A Expired - Lifetime EP0822320B1 (fr) 1994-09-27 1995-09-14 Installation à turbines à gaz et à vapeur

Country Status (7)

Country Link
US (1) US5887418A (fr)
EP (2) EP0822320B1 (fr)
JP (1) JPH10506165A (fr)
KR (1) KR100385372B1 (fr)
CN (1) CN1067137C (fr)
DE (3) DE4434526C1 (fr)
WO (1) WO1996010124A1 (fr)

Families Citing this family (31)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
DE19542917A1 (de) * 1994-12-21 1996-06-27 Abb Management Ag Kombianlage mit konventionellem Wasser/Dampf-Kreislauf
DE19541914A1 (de) * 1995-11-10 1997-05-15 Asea Brown Boveri Kühlluftkühler für Kraftwerksanlagen
DE19619470C1 (de) * 1996-05-14 1997-09-25 Siemens Ag Gas- und Dampfturbinenanlage sowie Verfahren zu deren Betrieb
DE19626011A1 (de) * 1996-06-28 1998-01-02 Lentjes Kraftwerkstechnik Kombinierte Gas-Dampf-Kraftanlage und Prozeß
DE19720789B4 (de) * 1997-05-17 2006-04-27 Alstom Verfahren und Vorrichtung zur Erzeugung von Dampf
US6065280A (en) * 1998-04-08 2000-05-23 General Electric Co. Method of heating gas turbine fuel in a combined cycle power plant using multi-component flow mixtures
NL1009467C2 (nl) * 1998-06-22 1999-12-27 Stork Eng & Contractors Bv Warmte-krachtinstallatie, en werkwijze voor het bedrijven daarvan.
US6202782B1 (en) * 1999-05-03 2001-03-20 Takefumi Hatanaka Vehicle driving method and hybrid vehicle propulsion system
DE10001997A1 (de) * 2000-01-19 2001-07-26 Alstom Power Schweiz Ag Baden Verbund-Kraftwerk sowie Verfahren zum Betrieb eines solchen Verbund-Kraftwerkes
SE0004931D0 (sv) * 2000-12-29 2000-12-29 Addpower Ab Sätt att konvertera värme i varma rökgaser
US7073337B2 (en) * 2003-05-30 2006-07-11 General Electric Company Combined power generation and desalinization apparatus and related method
CN1948720B (zh) * 2006-10-31 2011-08-10 章祖文 永磁传动低温多级涡轮发电机
US7628609B2 (en) * 2006-12-29 2009-12-08 Electrolux Home Products, Inc. Hub and spoke burner with flame stability
JP4939511B2 (ja) * 2008-10-29 2012-05-30 三菱重工業株式会社 石炭ガス化複合発電設備
ITBS20090224A1 (it) * 2009-12-16 2011-06-17 Turboden Srl Sistema e metodo per la produzione di energia elettrica a partire da sorgenti termiche a temperatura variabile
DE102011013325A1 (de) * 2011-03-08 2012-09-13 Rwe Technology Gmbh Kraftwerk sowie Verfahren zum Betreiben eines Kraftwerks
US9074494B2 (en) 2011-10-21 2015-07-07 General Electric Company System and apparatus for controlling temperature in a heat recovery steam generator
DE202011107312U1 (de) * 2011-11-02 2012-02-29 Gammel Engineering Gmbh Abgasnacherhitzungs-Vorrichtung
US8955322B2 (en) * 2012-03-05 2015-02-17 Ormat Technologies Inc. Apparatus and method for increasing power plant efficiency at partial loads
CN103047047B (zh) * 2013-01-24 2015-12-02 矫明义 发动机废气动力装置及使用方法
FR3005143A1 (fr) * 2013-04-25 2014-10-31 Pyraine Installation thermique de production d'electricite par combustion
DE102013208002A1 (de) * 2013-05-02 2014-11-06 Siemens Aktiengesellschaft Thermische Wasseraufbereitung bei STIG Kraftwerkskonzepten
GB2519129A (en) * 2013-10-10 2015-04-15 Ide Technologies Ltd Pumping Apparatus
ES2927226T3 (es) * 2014-06-04 2022-11-03 Pintail Power Llc Planta de energía híbrida solar gestionable
JP6317652B2 (ja) * 2014-09-12 2018-04-25 株式会社東芝 プラント制御装置及びコンバインドサイクル発電プラント
EP3262284B1 (fr) * 2015-02-24 2019-01-02 Siemens Aktiengesellschaft Centrale électrique à cycle combiné comportant une turbine à vapeur supercritique
EP3371421B1 (fr) 2015-11-05 2023-02-15 Pintail Power LLC Centrales électriques à cycle combiné et stockage acheminable
US10337357B2 (en) 2017-01-31 2019-07-02 General Electric Company Steam turbine preheating system with a steam generator
US10174639B2 (en) * 2017-01-31 2019-01-08 General Electric Company Steam turbine preheating system
US10670334B2 (en) * 2017-12-01 2020-06-02 Dilip Kumar De Highly cost effective technology for capture of industrial emissions without reagent for clean energy and clean environment applications
CN108679587A (zh) * 2018-05-11 2018-10-19 中国成达工程有限公司 一种燃气透平乏气并串级热量回收系统

Family Cites Families (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR1312469A (fr) * 1961-10-03 1962-12-21 Babcock & Wilcox France Perfectionnements aux installations de production d'énergie à cycle mixte vapeur et gaz
DE1426443B2 (de) * 1962-09-21 1971-09-09 Waermekraftanlage
DE1426890A1 (de) * 1963-08-30 1969-06-12 Aeg Kanis Turbinen Kraftwerk mit Muellverbrennung
DE3815536C1 (en) * 1988-05-06 1989-07-20 Wolff Walsrode Ag, 3030 Walsrode, De Heating and power station and method for generating heat energy in the form of steam and generating electrical energy
US4852344A (en) * 1988-06-06 1989-08-01 Energy Economics & Development, Inc. Waste disposal method and apparatus
DE4029991A1 (de) * 1990-09-21 1992-03-26 Siemens Ag Kombinierte gas- und dampfturbinenanlage
JPH04362207A (ja) * 1991-06-10 1992-12-15 Toshiba Corp 汽力発電設備のリパワリングシステム
DE4126036A1 (de) * 1991-08-06 1993-02-11 Siemens Ag Gas- und dampfturbinenkraftwerk mit einem solar beheizten dampferzeuger
US5628183A (en) * 1994-10-12 1997-05-13 Rice; Ivan G. Split stream boiler for combined cycle power plants

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
See references of WO9610124A1 *

Also Published As

Publication number Publication date
DE59502433D1 (de) 1998-07-09
CN1067137C (zh) 2001-06-13
DE59508574D1 (de) 2000-08-17
US5887418A (en) 1999-03-30
EP0822320B1 (fr) 2000-07-12
EP0822320A1 (fr) 1998-02-04
JPH10506165A (ja) 1998-06-16
WO1996010124A1 (fr) 1996-04-04
KR100385372B1 (ko) 2003-08-19
EP0783619B1 (fr) 1998-06-03
CN1155318A (zh) 1997-07-23
KR970706444A (ko) 1997-11-03
DE4434526C1 (de) 1996-04-04

Similar Documents

Publication Publication Date Title
WO1996010124A1 (fr) Procede permettant de faire fonctionner une installation a turbines a gaz et a vapeur, et installation fonctionnant selon ce procede
EP0523467B1 (fr) Procédé pour opérer une installation à turbines à gaz et à vapeur et installation pour la mise en oeuvre du procédé
EP0778397B1 (fr) Procédé d'opération d'une centrale combinée avec une chaudière de récuperation et un consommateur de vapeur
EP0819209B1 (fr) Procede de fonctionnement d'un generateur de vapeur a recuperation de chaleur, et generateur de vapeur a recuperation de chaleur fonctionnant selon ce procede
EP0591163B1 (fr) Installation combinee a turbines a gaz et a vapeur
DE4312072C2 (de) Dampfkraftwerk mit Vorschaltgasturbine
EP2368021B1 (fr) Générateur de vapeur à récupération de chaleur et procédé pour améliorer le fonctionnement d'un générateur de vapeur à récupération de chaleur
DE10001997A1 (de) Verbund-Kraftwerk sowie Verfahren zum Betrieb eines solchen Verbund-Kraftwerkes
EP0898641B1 (fr) Installation a turbine a gaz et a turbine a vapeur et procede permettant de la faire fonctionner
EP1023526A1 (fr) Systeme de turbine a gaz et a vapeur et procede permettant de faire fonctionner un systeme de ce type
CH678987A5 (fr)
EP1584798B1 (fr) Méthode et appareil pour la production d'électricité et de chaleur
EP0523466B1 (fr) Procédé de fonctionnement d'une installation à turbines à gaz et à vapeur et installation pour la mise en oeuvre du procédé
EP0709561B1 (fr) Centrale électrique
EP0840837B1 (fr) Procede d'exploitation d'une installation de turbines a gaz et a vapeur et installation exploitee selon ce procede
DE19627425A1 (de) Verfahren zum Betrieb einer Hybrid-Solar-Kombianlage sowie eine Hybrid-Solar-Kombianlage
WO2003104629A1 (fr) Groupe de turbines a gaz
EP2556218A1 (fr) Procédé de raccordement rapide d'un générateur de vapeur
DE3815993A1 (de) Zweistoff-turbinenanlage
DE4409811C1 (de) Verfahren zum Betreiben eines Abhitzedampferzeugers sowie danach arbeitender Abhitzedampferzeuger
EP1404947B1 (fr) Procede pour faire fonctionner une installation motrice a vapeur et installation motrice a vapeur pour mettre en oeuvre ce procede
DE19849740A1 (de) Gas- und Dampfturbinenanlage
WO1997007323A1 (fr) Installation a turbine a gaz et a vapeur et procede de fonctionnement de ladite installation ainsi que generateur de vapeur de chaleur perdue pour une telle installation
DE10124492B4 (de) Verfahren zum Betrieb eines Kombikraftwerkes bei unterschiedlichen Netzanforderungen
WO1989003471A1 (fr) Centrale thermique a gaz et a vapeur

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

17P Request for examination filed

Effective date: 19970121

AK Designated contracting states

Kind code of ref document: A1

Designated state(s): CH DE FR GB IT LI NL SE

17Q First examination report despatched

Effective date: 19970922

GRAG Despatch of communication of intention to grant

Free format text: ORIGINAL CODE: EPIDOS AGRA

GRAG Despatch of communication of intention to grant

Free format text: ORIGINAL CODE: EPIDOS AGRA

GRAH Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOS IGRA

GRAH Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOS IGRA

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): CH DE FR GB IT LI NL SE

DX Miscellaneous (deleted)
REG Reference to a national code

Ref country code: CH

Ref legal event code: NV

Representative=s name: SIEMENS SCHWEIZ AG

Ref country code: CH

Ref legal event code: EP

REF Corresponds to:

Ref document number: 59502433

Country of ref document: DE

Date of ref document: 19980709

ET Fr: translation filed
ITF It: translation for a ep patent filed

Owner name: STUDIO JAUMANN P. & C. S.N.C.

GBT Gb: translation of ep patent filed (gb section 77(6)(a)/1977)

Effective date: 19980807

PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

26N No opposition filed
PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: CH

Payment date: 20001214

Year of fee payment: 6

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: SE

Payment date: 20010913

Year of fee payment: 7

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: NL

Payment date: 20010914

Year of fee payment: 7

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: FR

Payment date: 20010928

Year of fee payment: 7

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LI

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20010930

Ref country code: CH

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20010930

REG Reference to a national code

Ref country code: GB

Ref legal event code: IF02

REG Reference to a national code

Ref country code: CH

Ref legal event code: PL

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: SE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20020915

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: NL

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20030401

EUG Se: european patent has lapsed
PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: FR

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20030603

REG Reference to a national code

Ref country code: FR

Ref legal event code: ST

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IT

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES;WARNING: LAPSES OF ITALIAN PATENTS WITH EFFECTIVE DATE BEFORE 2007 MAY HAVE OCCURRED AT ANY TIME BEFORE 2007. THE CORRECT EFFECTIVE DATE MAY BE DIFFERENT FROM THE ONE RECORDED.

Effective date: 20050914

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: GB

Payment date: 20120917

Year of fee payment: 18

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: DE

Payment date: 20121119

Year of fee payment: 18

GBPC Gb: european patent ceased through non-payment of renewal fee

Effective date: 20130914

REG Reference to a national code

Ref country code: DE

Ref legal event code: R119

Ref document number: 59502433

Country of ref document: DE

Effective date: 20140401

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: GB

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20130914

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: DE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20140401