EP1303684A1 - Verfahren zum betreiben einer gas- und dampfturbinenanlage sowie entsprechende anlage - Google Patents
Verfahren zum betreiben einer gas- und dampfturbinenanlage sowie entsprechende anlageInfo
- Publication number
- EP1303684A1 EP1303684A1 EP01967162A EP01967162A EP1303684A1 EP 1303684 A1 EP1303684 A1 EP 1303684A1 EP 01967162 A EP01967162 A EP 01967162A EP 01967162 A EP01967162 A EP 01967162A EP 1303684 A1 EP1303684 A1 EP 1303684A1
- Authority
- EP
- European Patent Office
- Prior art keywords
- gas
- pressure
- steam
- water
- 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
Links
- 238000000034 method Methods 0.000 title claims abstract description 18
- 238000009434 installation Methods 0.000 title abstract description 6
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 62
- 239000000203 mixture Substances 0.000 claims abstract description 13
- 238000002156 mixing Methods 0.000 claims abstract description 11
- 239000007789 gas Substances 0.000 claims description 55
- 238000010438 heat treatment Methods 0.000 claims description 21
- 238000011084 recovery Methods 0.000 claims description 14
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 claims description 13
- 239000003546 flue gas Substances 0.000 claims description 12
- 239000002918 waste heat Substances 0.000 claims description 9
- 238000009835 boiling Methods 0.000 claims description 3
- 230000008859 change Effects 0.000 claims description 3
- 239000008400 supply water Substances 0.000 abstract 3
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 6
- 239000000446 fuel Substances 0.000 description 4
- ANVAOWXLWRTKGA-NTXLUARGSA-N (6'R)-beta,epsilon-carotene Chemical compound CC=1CCCC(C)(C)C=1\C=C\C(\C)=C\C=C\C(\C)=C\C=C\C=C(/C)\C=C\C=C(/C)\C=C\[C@H]1C(C)=CCCC1(C)C ANVAOWXLWRTKGA-NTXLUARGSA-N 0.000 description 3
- 238000002485 combustion reaction Methods 0.000 description 3
- 239000012530 fluid Substances 0.000 description 3
- 239000003345 natural gas Substances 0.000 description 3
- 238000007872 degassing Methods 0.000 description 2
- 238000000605 extraction Methods 0.000 description 2
- 239000008236 heating water Substances 0.000 description 2
- 230000009467 reduction Effects 0.000 description 2
- AWGBKZRMLNVLAF-UHFFFAOYSA-N 3,5-dibromo-n,2-dihydroxybenzamide Chemical compound ONC(=O)C1=CC(Br)=CC(Br)=C1O AWGBKZRMLNVLAF-UHFFFAOYSA-N 0.000 description 1
- 230000015556 catabolic process Effects 0.000 description 1
- 238000001816 cooling Methods 0.000 description 1
- 238000006731 degradation reaction Methods 0.000 description 1
- 230000001419 dependent effect Effects 0.000 description 1
- 239000002737 fuel gas Substances 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 238000011144 upstream manufacturing Methods 0.000 description 1
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
Definitions
- the invention relates to a method for operating a gas and steam turbine system, in which the flue gas emerging from a gas turbine which can be operated with both gas and oil is passed via a heat recovery steam generator, the heating surfaces of which are one of a number of in the water-steam cycle Steam turbine having pressure stages are connected, with preheated condensate being heated in the waste heat steam generator as feed water under high pressure in comparison to this and being fed as steam to the steam turbine.
- the heat contained in the expanded working fluid or flue gas from the gas turbine is used to generate steam for the steam turbine connected to a water-steam circuit.
- the heat transfer takes place in a waste heat steam generator or boiler downstream of the gas turbine, in which heating surfaces are arranged in the form of tubes or tube bundles. These in turn are connected to the steam turbine water-steam cycle.
- the water-steam cycle usually comprises several, for example two or three, pressure stages, a preheater and an evaporator and a superheater being provided as heating surfaces in each pressure stage.
- Such a gas and steam turbine plant is known, for example, from EP 0 523 467 B1.
- the total amount of water in the water-steam cycle is dimensioned such that the flue gas leaving the heat recovery steam generator is cooled to a temperature of approx. 70 ° C to 100 ° C due to the heat transfer.
- it is also desirable that the temperatures of the feed water conducted in the individual heating surfaces and under different pressure are as close as possible to the temperature profile of the flue gas cooling down along the heat recovery steam generator as a result of the heat exchange.
- the aim here is to keep the temperature difference between the feed water conducted over the individual heating surfaces and the flue gas as low as possible in each area of the heat recovery steam generator.
- a condensate preheater is additionally provided in the waste heat steam generator for heating condensed water from the steam turbine.
- the gas turbine of such a gas and steam turbine system can be designed for operation with different fuels. If the gas turbine is designed for heating oil and natural gas, heating oil is only intended as fuel for the gas turbine for a short operating time, for example for 100 to 500H / a, as a so-called backup to natural gas.
- the gas and steam turbine system is usually designed and optimized primarily for natural gas operation of the gas turbine. In order to ensure a sufficiently high inlet temperature of the condensate flowing into the heat recovery steam generator when heating oil operation, in particular when changing from gas operation to oil operation, the necessary heat can be removed from the heat recovery steam generator itself in various ways.
- the condensate temperature in the feed water tank is usually kept in a temperature range between 130 ° C and 160 ° C.
- Preheating of the condensate is generally provided via a preheater fed with low-pressure steam or hot water from an economizer, so that the warm-up span of the condensate in the feed water tank is kept as small as possible.
- Hot water withdrawal from the high-pressure economizer is required in particular for two- or three-pressure systems in order to provide sufficient heat.
- DE 197 36 889 C1 discloses a method which can be carried out with little outlay in terms of equipment and operation compared to the methods described, which involves a shift in exhaust gas heat in the direction of the condensate preheating as a result of degradation in the low pressure range and ner installation of water-side economizer bypasses.
- this method also reaches the limits of implementation for certain requirements.
- the invention is therefore based on the object of specifying a method for operating a gas and steam turbine installation of the above-mentioned type which, while at the same time requiring little equipment and operation, effectively and economically switching from gas operation to oil operation of the gas turbine guaranteed covering a wide temperature range of the inlet temperature of the condensate flowing into the heat recovery steam generator. Furthermore, a gas and steam turbine plant which is particularly suitable for carrying out the method is to be specified.
- the object is achieved according to the invention by the features of claim 1.
- the feed water is under high pressure and has a high temperature in comparison to the condensate, expediently via an additional pipeline to the cold condensate without heat exchanger and thus directly is added.
- the heated feed water or hot water is 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 the first partial stream.
- the first partial stream 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. It is essential that the heated feed water taken from the water-steam cycle at a suitable point in the form of a partial flow Mixture of feed water partial flows of different temperatures without prior heating, ie without heat exchange in an additional heat exchanger, to which the cold condensate is added.
- the invention is based on the consideration that, on an additional heat exchanger, the heated feed water or heating water removed from the water-steam circuit cools to the temperature level of the condensate system before its pressure is reduced, in order to thereby generate the steam after the Preventing pressure reduction can be dispensed with if the heated feed water is mixed with such a partial flow of feed water with likewise high pressure but comparatively low temperature before the pressure drops that the resulting mixing temperature is below the boiling point in the condensate system.
- heated feed water can be taken 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 system efficiency that should at least be maintained when the gas turbine operates as a backup oil only.
- the object is achieved according to the invention by the features of claim 6.
- the system comprises a supply line for the heated feed water, which is led to the condensate preheater, with a mixing point for supplying the comparatively cool feed water.
- the advantages achieved by the invention are, in particular, that a water inlet temperature in the waste heat steam generator which is required when the gas turbine is operated in oil and which is higher than in the gas operation of the gas turbine, even without additional heat exchanger or external condensate preheater by direct, ie heat exchanger-free admixing of a temperature set to a suitable mixing temperature , heated and pressurized feed water to the cold condensate can be adjusted with particularly simple means.
- the capacity reserves of the high-pressure feed water pump can also be exploited in this way, since usually smaller amounts of oil are required for oil operation compared to gas operation due to a lower gas turbine output. 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.
- an exhaust gas line 34 is connected to an inlet 30a of the heat recovery steam generator 30. That runs along the heat recovery The generator 30 as a result of indirect heat exchange with condensate K and feed water S which cools the flue gas AM from the gas turbine 2 and leaves the waste heat 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 40 via a condensate line 38 into which a condensate pump 40 is connected.
- the feed water pump 42 is formed as a high-pressure feed pump with medium pressure extraction on the outside . 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. Via the medium pressure extraction, the condensate K is raised 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 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 co co M IV) I- 1
- DJ H- Hi O ⁇ DJ N ⁇ -3 er IV
- H- uq P oa ⁇ d H- C ⁇ rt is ⁇ 3 I- 1 Ti oo P ⁇ J • ⁇ H 2 H (- ⁇
- an adjustable first partial flow ti can also be taken from the medium-pressure economizer 73 on the output side via a valve 112 or the medium-pressure drum 75 on the water side via a valve 113 heated feed water S ⁇ .
- the first partial flow ti of heated feed water S ⁇ is mixed with a second partial flow t 2 of comparatively cool feed water S at the admixing point 103.
- the second partial flow t 2 conducted via the partial flow line 102 is adjustable by means of the valve 101.
- the partial flow mixture t i 2 formed in this way is mixed into the cold condensate K via the mixing point 106.
- the temperature T s - of the first partial stream ti when it is removed as heated feed water S from the high-pressure drum 54 is, for example, 320 ° C.
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)
- Control Of Steam Boilers And Waste-Gas Boilers (AREA)
Abstract
Description
Claims
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| EP01967162A EP1303684B1 (de) | 2000-07-25 | 2001-07-12 | Verfahren zum betreiben einer gas- und dampfturbinenanlage sowie entsprechende anlage |
Applications Claiming Priority (4)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| EP00115909 | 2000-07-25 | ||
| EP00115909 | 2000-07-25 | ||
| PCT/EP2001/008079 WO2002008577A1 (de) | 2000-07-25 | 2001-07-12 | Verfahren zum betreiben einer gas- und dampfturbinenanlage sowie entsprechende anlage |
| EP01967162A EP1303684B1 (de) | 2000-07-25 | 2001-07-12 | Verfahren zum betreiben einer gas- und dampfturbinenanlage sowie entsprechende anlage |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| EP1303684A1 true EP1303684A1 (de) | 2003-04-23 |
| EP1303684B1 EP1303684B1 (de) | 2005-05-11 |
Family
ID=8169340
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| EP01967162A Expired - Lifetime EP1303684B1 (de) | 2000-07-25 | 2001-07-12 | Verfahren zum betreiben einer gas- und dampfturbinenanlage sowie entsprechende anlage |
Country Status (9)
| Country | Link |
|---|---|
| US (1) | US6823674B2 (de) |
| EP (1) | EP1303684B1 (de) |
| JP (1) | JP3679094B2 (de) |
| CN (1) | CN1313714C (de) |
| BR (1) | BR0112691A (de) |
| DE (1) | DE50106214D1 (de) |
| ES (1) | ES2240512T3 (de) |
| TW (1) | TW541393B (de) |
| WO (1) | WO2002008577A1 (de) |
Families Citing this family (13)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| EP1413554A1 (de) * | 2002-10-23 | 2004-04-28 | Siemens Aktiengesellschaft | Gas- und Dampfkraftwerk zur Wasserentsalzung |
| JP2005312284A (ja) * | 2005-01-12 | 2005-11-04 | Masakazu Ushijima | 電流共振型放電管用インバータ回路 |
| EP1736638A1 (de) * | 2005-06-21 | 2006-12-27 | Siemens Aktiengesellschaft | Verfahren zum Hochfahren einer Gas- und Dampfturbinenanlage |
| US8112997B2 (en) * | 2008-04-28 | 2012-02-14 | Siemens Energy, Inc. | Condensate polisher circuit |
| EP2224164A1 (de) * | 2008-11-13 | 2010-09-01 | Siemens Aktiengesellschaft | Verfahren zum Betreiben eines Abhitzedampferzeugers |
| US8069667B2 (en) * | 2009-02-06 | 2011-12-06 | Siemens Energy, Inc. | Deaerator apparatus in a superatmospheric condenser system |
| US8007729B2 (en) * | 2009-03-20 | 2011-08-30 | Uop Llc | Apparatus for feed preheating with flue gas cooler |
| CN103759247B (zh) * | 2014-01-29 | 2016-03-30 | 国家电网公司 | 燃机余热锅炉汽包水位全程自动控制系统及方法 |
| JP6516993B2 (ja) * | 2014-09-26 | 2019-05-22 | 三菱日立パワーシステムズ株式会社 | コンバインドサイクルプラント並びにボイラの蒸気冷却方法 |
| EP3374604A1 (de) * | 2015-12-22 | 2018-09-19 | Siemens Energy, Inc. | Stapelenergiesteuerung in kombikraftwerk |
| US11085336B2 (en) | 2018-12-21 | 2021-08-10 | General Electric Company | Method for operating a combined cycle power plant and corresponding combined cycle power plant |
| US11199113B2 (en) | 2018-12-21 | 2021-12-14 | General Electric Company | Combined cycle power plant and method for operating the combined cycle power plant |
| US10851990B2 (en) | 2019-03-05 | 2020-12-01 | General Electric Company | System and method to improve combined cycle plant power generation capacity via heat recovery energy control |
Family Cites Families (14)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US3756023A (en) * | 1971-12-01 | 1973-09-04 | Westinghouse Electric Corp | Heat recovery steam generator employing means for preventing economizer steaming |
| CH621187A5 (de) * | 1977-06-16 | 1981-01-15 | Bbc Brown Boveri & Cie | |
| CH623888A5 (de) * | 1977-10-04 | 1981-06-30 | Bbc Brown Boveri & Cie | |
| US4799461A (en) * | 1987-03-05 | 1989-01-24 | Babcock Hitachi Kabushiki Kaisha | Waste heat recovery boiler |
| JP2554101B2 (ja) | 1987-09-28 | 1996-11-13 | 三菱重工業株式会社 | 排ガスボイラ |
| DE3804605A1 (de) * | 1988-02-12 | 1989-08-24 | Siemens Ag | Verfahren und anlage zur abhitzedampferzeugung |
| US4932204A (en) * | 1989-04-03 | 1990-06-12 | Westinghouse Electric Corp. | Efficiency combined cycle power plant |
| DE59205446D1 (de) | 1991-07-17 | 1996-04-04 | Siemens Ag | Verfahren zum Betreiben einer Gas- und Dampfturbinenanlage und Anlage zur Durchführung des Verfahrens |
| EP0582898A1 (de) * | 1992-08-10 | 1994-02-16 | Siemens Aktiengesellschaft | Verfahren zum Betreiben einer Gas- und Dampfturbinenanlage sowie danach arbeitende Gud-Anlage |
| DE4321081A1 (de) * | 1993-06-24 | 1995-01-05 | Siemens Ag | Verfahren zum Betreiben einer Gas- und Dampfturbinenanlage sowie danach arbeitende GuD-Anlage |
| 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 |
| 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 |
| WO1999057421A1 (de) * | 1998-05-06 | 1999-11-11 | Siemens Aktiengesellschaft | Gas- und dampfturbinenanlage |
-
2001
- 2001-05-25 TW TW090112627A patent/TW541393B/zh active
- 2001-07-12 DE DE50106214T patent/DE50106214D1/de not_active Expired - Lifetime
- 2001-07-12 CN CNB018128904A patent/CN1313714C/zh not_active Expired - Fee Related
- 2001-07-12 BR BR0112691-1A patent/BR0112691A/pt not_active IP Right Cessation
- 2001-07-12 WO PCT/EP2001/008079 patent/WO2002008577A1/de not_active Ceased
- 2001-07-12 EP EP01967162A patent/EP1303684B1/de not_active Expired - Lifetime
- 2001-07-12 JP JP2002514042A patent/JP3679094B2/ja not_active Expired - Fee Related
- 2001-07-12 US US10/333,626 patent/US6823674B2/en not_active Expired - Fee Related
- 2001-07-12 ES ES01967162T patent/ES2240512T3/es not_active Expired - Lifetime
Non-Patent Citations (1)
| Title |
|---|
| See references of WO0208577A1 * |
Also Published As
| Publication number | Publication date |
|---|---|
| US6823674B2 (en) | 2004-11-30 |
| JP2004504538A (ja) | 2004-02-12 |
| BR0112691A (pt) | 2003-06-24 |
| US20040025510A1 (en) | 2004-02-12 |
| TW541393B (en) | 2003-07-11 |
| JP3679094B2 (ja) | 2005-08-03 |
| EP1303684B1 (de) | 2005-05-11 |
| ES2240512T3 (es) | 2005-10-16 |
| CN1443270A (zh) | 2003-09-17 |
| CN1313714C (zh) | 2007-05-02 |
| WO2002008577A1 (de) | 2002-01-31 |
| DE50106214D1 (de) | 2005-06-16 |
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