EP1320665A1 - Procede pour l'exploitation d'une installation de turbines a vapeur et a gaz et installation correspondante - Google Patents

Procede pour l'exploitation d'une installation de turbines a vapeur et a gaz et installation correspondante

Info

Publication number
EP1320665A1
EP1320665A1 EP01978376A EP01978376A EP1320665A1 EP 1320665 A1 EP1320665 A1 EP 1320665A1 EP 01978376 A EP01978376 A EP 01978376A EP 01978376 A EP01978376 A EP 01978376A EP 1320665 A1 EP1320665 A1 EP 1320665A1
Authority
EP
European Patent Office
Prior art keywords
cfl
gas
pressure
steam
steam turbine
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
EP01978376A
Other languages
German (de)
English (en)
Other versions
EP1320665B1 (fr
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 EP01978376A priority Critical patent/EP1320665B1/fr
Publication of EP1320665A1 publication Critical patent/EP1320665A1/fr
Application granted granted Critical
Publication of EP1320665B1 publication Critical patent/EP1320665B1/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
    • 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
    • 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
    • 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
    • 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

  • heated feed water can be drawn from the medium-pressure system, from the high-pressure system or from both systems.
  • the removal essentially depends on the heat required for heating up the condensate and on the plant efficiency that should at least be maintained when the gas turbine is operated as a backup oil operation only.
  • the heated feed water or hot water is expediently in a two-pressure system, i.e. H.' in a two-pressure system from a high-pressure drum and in 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.
  • the partial flow can also be withdrawn at the outlet of the high-pressure economizer or the medium-pressure economizer.
  • the pressure of the low-pressure system can also be raised in order to shift the heat contained in the flue gas from the low-pressure system to the condensate preheater downstream of the flue gas side. It is essential that the heated feed water in the form of a feed water partial stream removed from the water-steam cycle at a suitable point without prior heating, i.e. is added to the cold condensate without heat exchange in an additional heat exchanger.
  • Inlet temperature is required. Standardization is also possible as a result of the operating range being expanded in a particularly effective manner in terms of circuitry. Furthermore, the investment costs are particularly low.
  • FIG. 1 schematically shows a gas and steam turbine system designed for a change of operation from gas to oil with a hot water mixing device
  • FIG. 2 shows the mixing device according to FIG. 1 on a larger scale with a number of spray heads
  • FIG. 3 shows a detail III from FIG. 2 on a larger scale with a spray head having a valve.
  • the gas and steam turbine system 1 comprises a gas turbine system 1 a and a steam turbine system 1 b.
  • the gas turbine system 1 a comprises a gas turbine 2 with a coupled air compressor 4 and a combustion chamber 6 connected upstream of the gas turbine 2 and which is connected to a fresh air line 8 of the air compressor 4.
  • a fuel line 10 opens into the combustion chamber 6 and can be used to supply gas or oil as the fuel B to the combustion chamber 6. This is burned with the supply of compressed air L to the working fluid or fuel gas for the gas turbine 2.
  • the gas turbine 2 and the air compressor 4 and a generator 12 sit on a common turbine shaft 14.
  • the steam turbine system 1b comprises a steam turbine 20 with a coupled generator 22 and, in a water-steam circuit 24, a condenser 26 connected downstream of the steam turbine 20 and a waste heat 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, which drive the generator 22 via a common turbine shaft 32.
  • An exhaust pipe 34 is connected to an inlet 30a of the heat recovery steam generator 30 in order to supply working fluid or flue gas AM relaxed in the gas turbine 2 to the heat recovery steam generator 30.
  • the flue gas AM from the gas turbine 2 which cools down along the heat recovery steam generator 30 as a result of indirect heat exchange with condensate K and feed water S conducted in the water-steam circuit 24, leaves the heat recovery steam generator 30 via its outlet 30b in the direction of a chimney (not shown).
  • the heat recovery steam generator 30 comprises, as heating surfaces, a condensate preheater 36 which is fed with condensate K from the condenser 26 via a condensate line 38 into which a condensate pump 40 is connected.
  • the condensate preheater 36 is guided on the outlet side to the suction side of a feed water pump 42.
  • a mixing device 44 with a tubular hot water mixer 46 is connected into the condensate line 38.
  • the feed water pump 42 is designed as a high-pressure feed pump with medium pressure extraction. It brings the condensate K to a pressure level of approximately 120 bar to 150 bar, which is suitable for a high pressure stage 50 of the water-steam circuit 24 assigned to the high pressure part 20a of the steam turbine 20. About the The medium pressure is removed from the condensate K by means of the feed water pump 42 to a pressure level of approximately 40 bar to 60 bar suitable for a medium pressure stage 70 assigned to the medium pressure part 20b of the steam turbine 20.
  • the condensate K which is fed via the feed water pump 42 and is referred to as feed water S on the pressure side of the feed water pump 42, is partly fed at high pressure to a first high-pressure economizer 51 or feed-water preheater and via this to a second high-pressure economizer 52. This is connected on the output side to a high-pressure drum 54 via a valve 57.
  • the feed water S is also partially fed to a feed water preheater or medium pressure economizer 73 at a medium pressure via a non-return flap 71 and a valve 72 connected downstream of this. On the output side, this is connected to a medium-pressure drum 75 via a valve 74.
  • the condensate preheater 36 is connected on the output side to a low-pressure drum 92 via a valve 91.
  • the medium pressure drum 75 is connected to a medium pressure evaporator 76 arranged in the heat recovery steam generator 30 in order to form a water-steam circulation 77.
  • an intermediate superheater 78 is connected to the medium-pressure drum 75, which is led on the outlet side (hot CLOSE) to an inlet 79 of the medium-pressure section 20b and in the inlet-side (cold CLOSE) one with an outlet 80 of the high-pressure section 20a of the steam turbine 20 connected steam line 81 is guided.
  • the feed water pump 42 is connected via two valves 55, 56 as well as via the first high-pressure economizer 51 and the downstream downstream of the feed water side and inside the waste heat steam generator 30 on the flue gas side o O IV) rv> P 1 c ⁇ o C ⁇ o C ⁇ o c ⁇ o rt ⁇ NSP o £ rt P- P ⁇
  • a valve 102 with an upstream check valve is used via a partial flow or hot water line 101
  • adjustable partial flow tS of heated feed water S ' is fed to the mixing device 44, 46 and in the interior thereof
  • the partial flow tS of heated feed water S ' is preferably taken from the high-pressure drum 54 on the water side via a valve 106.
  • the heated feed water S ⁇ can be taken as an adjustable partial flow tS via a valve 107 from the first high-pressure economizer 51 or via a valve 108 from the second high-pressure economizer 52.
  • an adjustable partial flow tS can also be taken from the medium-pressure economizer 73 on the output side via a valve 109 or the medium-pressure drum 75 on the water side via a valve 110 heated feed water S ⁇ .
  • the admixture of the partial flow tS to the condensate K by injecting the heated feed water S conducted via the hot water line 101 into the cold condensate K leads to a targeted evaporation and subsequent condensation of the water-steam mixture formed in the mixing device 44, 46.
  • the temperature TS of the partial flow tS when it is removed as heated feed water S from the high-pressure drum 54 is, for example, 320 ° C.

Landscapes

  • 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)

Abstract

L'invention concerne un procédé pour l'exploitation d'une installation de turbines à vapeur et à gaz (1) comprenant une turbine à gaz (2) exploitable aussi bien au gaz qu'à l'huile. Selon l'invention, lors du passage de l'exploitation au gaz à l'exploitation à l'huile, un flux partiel (tS) d'eau d'alimentation chauffée (S') est injecté dans le condensat froid (K) afin de préchauffer le condensat. A cet effet, l'installation (1) comprend un dispositif de mélange (44, 46) dans lequel se trouve au moins une tête de pulvérisation (105) raccordée à une conduite d'eau chaude (101) et servant à amener le flux partiel (tS).
EP01978376A 2000-09-29 2001-09-17 Procede pour l'exploitation d'une installation de turbines a vapeur et a gaz et installation correspondante Expired - Lifetime EP1320665B1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
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

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
EP00121502 2000-09-29
EP00121502A EP1193373A1 (fr) 2000-09-29 2000-09-29 Méthode pour opérer une installation à turbines à gaz et à vapeur et installation correspondante
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

Publications (2)

Publication Number Publication Date
EP1320665A1 true EP1320665A1 (fr) 2003-06-25
EP1320665B1 EP1320665B1 (fr) 2005-05-11

Family

ID=8169992

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 Before (1)

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

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)

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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
US8157512B2 (en) * 2008-07-29 2012-04-17 General Electric Company Heat pipe intercooler for a turbomachine
US8359824B2 (en) * 2008-07-29 2013-01-29 General Electric Company Heat recovery steam generator for a combined cycle power plant
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
US8230686B2 (en) * 2008-10-09 2012-07-31 Banas John M Start-up system mixing sphere
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
MX369977B (es) * 2013-09-26 2019-11-27 Nooter/Eriksen Inc Sistema y metodo de intercambio de calor para un generador de vapor de recuperacion de calor.
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
US3756023A (en) * 1971-12-01 1973-09-04 Westinghouse Electric Corp Heat recovery steam generator employing means for preventing economizer steaming
US4869595A (en) * 1983-08-01 1989-09-26 James M. Montgomery, Consulting Engineers, Inc. Hydraulic diffusion flash mixing
US4799461A (en) * 1987-03-05 1989-01-24 Babcock Hitachi Kabushiki Kaisha Waste heat recovery boiler
DE3804605A1 (de) * 1988-02-12 1989-08-24 Siemens Ag Verfahren und anlage zur abhitzedampferzeugung
ES2083627T3 (es) 1991-07-17 1996-04-16 Siemens Ag Procedimiento para la operacion de una instalacion de turbina de gas y vapor e instalacion para la realizacion del procedimiento.
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
DE4333439C1 (de) * 1993-09-30 1995-02-02 Siemens Ag Vorrichtung zur Kühlmittelkühlung einer gekühlten Gasturbine einer Gas- und Dampfturbinenanlage
DE19512466C1 (de) * 1995-04-03 1996-08-22 Siemens Ag Verfahren zum Betreiben eines Abhitzedampferzeugers sowie danach arbeitender Abhitzedampferzeuger
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Also Published As

Publication number Publication date
EP1193373A1 (fr) 2002-04-03
TW541392B (en) 2003-07-11
ES2240527T3 (es) 2005-10-16
WO2002027154A1 (fr) 2002-04-04
DE50106221D1 (de) 2005-06-16
US6874322B2 (en) 2005-04-05
US20040011049A1 (en) 2004-01-22
EP1320665B1 (fr) 2005-05-11

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