EP0588392A1 - GuD-Kraftanlage mit befeuchtetem Erdgas - Google Patents

GuD-Kraftanlage mit befeuchtetem Erdgas Download PDF

Info

Publication number
EP0588392A1
EP0588392A1 EP93201893A EP93201893A EP0588392A1 EP 0588392 A1 EP0588392 A1 EP 0588392A1 EP 93201893 A EP93201893 A EP 93201893A EP 93201893 A EP93201893 A EP 93201893A EP 0588392 A1 EP0588392 A1 EP 0588392A1
Authority
EP
European Patent Office
Prior art keywords
unit
moistening
installation
steam
natural gas
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Withdrawn
Application number
EP93201893A
Other languages
English (en)
French (fr)
Inventor
Johannes Laurentius Raas
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.)
Kema NV
Original Assignee
Kema NV
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 Kema NV filed Critical Kema NV
Publication of EP0588392A1 publication Critical patent/EP0588392A1/de
Withdrawn legal-status Critical Current

Links

Images

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
    • F01K21/00—Steam engine plants not otherwise provided for
    • F01K21/04—Steam engine plants not otherwise provided for using mixtures of steam and gas; Plants generating or heating steam by bringing water or steam into direct contact with hot gas
    • F01K21/047—Steam engine plants not otherwise provided for using mixtures of steam and gas; Plants generating or heating steam by bringing water or steam into direct contact with hot gas having at least one combustion gas turbine
    • 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 present invention relates to a STEG installation for generating electricity and/or heat using moistened natural gas.
  • An important method of lowering the NO x emission is lowering the flame temperature in the combustion chambers of the gas turbine.
  • the amount of surplus heat in the economizer unit in the case of a KV-STEG installation is lower because more steam is generated in the evaporator unit.
  • the residual heat from the economizer is thus used to heat the synthesis gas.
  • the present invention has for its object to improve the efficiency in a STEG installation, to lower the NO x emission, but above all to enable provision of a much smaller installation relative to a KV-STEG installation.
  • the improvement in efficiency is substantially equal to the work which can be obtained by the expansion of medium pressure steam of for instance about 20 bar to low pressure steam.
  • the efficiency improvement amounts to approximately 1.5% point.
  • the water/natural gas ratio amounts to roughly 0.8, a lowering of the NO x emission of 70% can be achieved with the application of conventional diffusion burners.
  • Pre-mix burners that are difficult to adjust do not therefore have to be used in combination with the gas turbine. It is even possible to use gas turbines of older type with conventional burners, which combinations cannot attain the currently applicable values for NO x emission.
  • the moistening water comes directly from the economizer unit.
  • the moistening unit comprises a recirculation circuit for moistening water.
  • Supplementary water and extra heat can be added to this recirculation circuit, for which purpose the recirculation circuit preferably comprises a recirculation heat exchanger for the heat exchange with water coming from the economizer unit.
  • the moistening unit comprises a control unit for controlling the recirculation ratio in the recirculation circuit.
  • the residual heat of the water can be used for heating the moistened natural gas for adding to the combustion unit.
  • the natural gas is herein superheated, 10-40°C, in order to avoid condensation in a gas pipe to the diffusion burner of the combustion unit.
  • the moistening unit comprises a control unit for controlling the ratio between moistened natural gas and the water supply to the gas preheater, and that the moistening unit comprises a control unit for controlling the ratio of the recirculation flow and the water supplied to the recirculation heat exchanger.
  • the water coming from the economizer unit that is not supplied to the moistening unit according to the invention can still be used for generating low pressure steam. It is hereby recommended that the economizer unit is connected on the steam side to a degassing unit via a low pressure steam unit.
  • the amount of heat which can be extracted from the flue gas by the economizer unit becomes greater as the ratio between the heat which is used for super- and re-heating and the heat which is used for evaporation becomes greater.
  • This ratio becomes greater when an additional, independent heat source is present which produces steam for this purpose.
  • Such a heat source is for example a refuse burning installation.
  • the STEG installation according to the invention can therefore be employed to very great advantage in combination with such an additional, independent heat source.
  • figure 1 shows a flow diagram of a STEG installation according to the invention.
  • Figure 1 shows a STEG installation 1 according to the invention in which natural gas 2 is combusted with air 3 with formation of flue gas 4 in addition to electricity and/or heat respectively generated with the turbines and/or extracted from the liquid or gas flows.
  • the STEG installation 1 comprises a combustion unit 5 for combusting a mixture of moistened natural gas and air.
  • the combustion unit 5 connects onto a heating unit 6, an evaporator unit 7 and an economizer unit 8, to which feedwater is supplied from a degasser 9.
  • the STEG installation 1 is characterized by a moistening unit 10 for moistening natural gas 2 for supplying to combustion unit 5.
  • the STEG unit comprises a number of turbines for generating electricity with steam.
  • the combustion unit 5 comprises an inlet 14 for air which supplies the air via a compressor 11 to a diffusion burner 12 which is also provided with an inlet 13 for moistened natural gas coming from moistening unit 10.
  • An outlet 15 of burner 12 is connected to a gas turbine 16 which at full load produces flue gas with a temperature of 500 to 600°C.
  • the flue gas is discharged via a flue gas duct 17 to the heating unit 6.
  • the heating unit 6 comprises a superheater 18 and a reheater 19.
  • high pressure steam is superheated to approximately 541°C and fed via the pipe 20 to a steam turbine 21.
  • the steam expands to medium pressure level and is fed via the pipe 22 to the re-heater 19, in which the medium pressure steam is reheated to approximately 541°C and supplied via a pipe 23 to a steam turbine 24 which delivers low pressure steam via a pipe 25.
  • the evaporator unit 7 comprises an evaporator 26 with which saturated steam is generated which is supplied to superheater 18 via a pipe 27.
  • the feed pipe 28 of evaporator 26 is connected to the economizer unit 8 in which feedwater under high pressure coming from the degassing unit 9 supplied via the pipe 29 is pre-heated in an economizer 30 to several degrees under the evaporation temperature (for example 319°C). This difference in temperature can be controlled by regulating the amount of feedwater supplied via the pipe 29.
  • Surplus feedwater is fed via a pipe 31 and a heat exchanger 32 to an expansion tank 33.
  • a top pipe 34 supplies medium pressure steam which is superheated in the heat exchanger 32 and fed via pipe 35 to pipe 22.
  • a bottom pipe 36 from the expansion tank 33 carries medium pressure feedwater with a temperature of about 240°C.
  • This feedwater can, if necessary, be used for generating low pressure steam in an expansion tank 37 and can be drained via a pipe 38 from where the low pressure steam can be supplied as desired to a degasser boiler 39 or to the steam turbine 40.
  • a lower pipe 41 of the expansion tank 37 leads water for degassing to the degasser boiler 39.
  • the feedwater coming indirectly out of the economizer unit 8 is fed via a pipe 42 to the moistening unit 10.
  • the moistening unit 10 comprises a moistening column 43 with a natural gas inlet 44 on the bottom side.
  • the moistened natural gas leaves the moistening column via the pipe 45 and is preheated in a gas pre-heater 46 which connects onto the inlet 13.
  • the moistened natural gas is pre-heated with a portion of the water coming out of the economiser unit that is supplied via the pipe 42 and the branch pipe 47.
  • the moistening column 43 further comprises a circuit pipe 48 for water with which the natural gas 2 is moistened.
  • the circuit pipe 48 comprises a heat exchanger 49 with which the water present in the circuit can be heated with water supplied from the economizer unit 8 via pipe 42 and pipe 61.
  • the moistening water is for instance heated from a temperature of about 105°C to a temperature of about 210°C, wherein the economizer water cools from 240°C to about 118°C.
  • the economizer water can be drained via pipe 50 and pipe 51 which debouches into a collection pipe 52 which is connected to the degasser boiler 39. From pipe 50 extra economizer water can be supplied to the circuit pipe 48 via the supplementary supply line 53. It is optionally possible to supply fresh water to the circuit pipe 48 via a non-shown supplementary supply line.
  • the STEG installation 1 comprises a heat exchanger 54 which connects onto the turbine 40 and in which steam under vacuum is condensed.
  • An outlet 55 is connected to a supplementary pipe 56 for demineralised water. This feedwater is brought to pressure with a pump 57 and, after pre-heating in a low pressure heat exchanger 58, supplied to the collection pipe 52.
  • the moistening unit 10 comprises a control unit 59 with which the recirculation over the moistening column 43 can be varied so that the so-called Wobbe index can be held constant.
  • the ratio between the amount of hot water supplied to the gas pre-heater 46 and the amount of moistened natural gas can be kept constant.
  • the ratio between the recirculation flow in the circuit pipe 48 and the amount of water supplied via the pipe 61 can also be regulated. This means that, subject to the optimal moistening of the natural gas, only a part of the lower circuit of the expansion tank 33 is supplied to expansion tank 37 for generating low pressure steam.
  • optimal use of the hot water from the economizer unit 8 in the moistening unit 10 for moistening the natural gas Obtained herewith is not only a considerable reduction in the NO x emission but also an increase in efficiency of approximately 1.5% point.

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)
EP93201893A 1992-07-13 1993-06-29 GuD-Kraftanlage mit befeuchtetem Erdgas Withdrawn EP0588392A1 (de)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
NL9201256 1992-07-13
NL9201256A NL9201256A (nl) 1992-07-13 1992-07-13 Steg-inrichting voor het opwekken van elektriciteit met bevochtigd aardgas.

Publications (1)

Publication Number Publication Date
EP0588392A1 true EP0588392A1 (de) 1994-03-23

Family

ID=19861051

Family Applications (1)

Application Number Title Priority Date Filing Date
EP93201893A Withdrawn EP0588392A1 (de) 1992-07-13 1993-06-29 GuD-Kraftanlage mit befeuchtetem Erdgas

Country Status (2)

Country Link
EP (1) EP0588392A1 (de)
NL (1) NL9201256A (de)

Cited By (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO1995000747A1 (de) * 1993-06-24 1995-01-05 Siemens Aktiengesellschaft Verfahren zum betreiben einer gas- und dampfturbinenanlage sowie danach arbeitende gud-anlage
WO1996031685A1 (de) * 1995-04-03 1996-10-10 Siemens Aktiengesellschaft Verfahren zum betreiben eines abhitzedampferzeugers sowie danach arbeitender abhitzedampferzeuger
EP0767290A1 (de) * 1995-10-02 1997-04-09 Asea Brown Boveri Ag Verfahren zum Betrieb einer Kraftwerksanlage
EP1065347A2 (de) * 1999-07-01 2001-01-03 General Electric Company Methode und Vorrichtung zur Befeuchtung und Heizung von Brenngas
EP0931911A3 (de) * 1998-01-19 2002-02-06 Kabushiki Kaisha Toshiba Kraftanlage mit kombiniertem Kreislauf
EP1199445A1 (de) * 2000-10-17 2002-04-24 Siemens Aktiengesellschaft Vorrichtung und Verfahren zur Brennstoffvorwärmung in kombinierten Gas- und Dampfturbinenanlagen
WO2002048509A1 (en) * 2000-11-29 2002-06-20 Alstom (Switzerland) Ltd A turbine arrangement and a method of operating a turbine arrangement
WO2006133656A2 (en) * 2005-06-15 2006-12-21 Siemens Industrial Turbomachinery, S.R.O. Emissionless cycle with steam generator and heat transformer
CN103477034A (zh) * 2012-01-13 2013-12-25 阿尔斯通技术有限公司 超临界热回收蒸汽发生器的再热器和超临界蒸发器布置
RU2586802C2 (ru) * 2011-03-24 2016-06-10 Дженерал Электрик Компани Энергоустановка комбинированного цикла (варианты)

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
DE4409811C1 (de) * 1994-03-22 1995-05-18 Siemens Ag Verfahren zum Betreiben eines Abhitzedampferzeugers sowie danach arbeitender Abhitzedampferzeuger

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
DE2005656A1 (de) * 1970-02-07 1971-08-19 Metallgesellschat Ag Offene Gasturbinenanlage
EP0036998A2 (de) * 1980-03-28 1981-10-07 Kraftwerk Union Aktiengesellschaft Gasturbine mit durch Dampfeinspritzung verringerter Stickoxydemission
WO1983001812A1 (en) * 1981-11-19 1983-05-26 Gen Electric Sliding pressure flash tank
EP0081996A2 (de) * 1981-12-10 1983-06-22 Mitsubishi Gas Chemical Company, Inc. Gasturbinenprozess mit Wärmerückgewinnung
EP0086504A2 (de) * 1982-02-16 1983-08-24 Shell Internationale Researchmaatschappij B.V. Verfahren zum Erzeugen von mechnischer Kraft
EP0207620A2 (de) * 1985-06-04 1987-01-07 Imperial Chemical Industries Plc Wärmerückgewinnung

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
DE2005656A1 (de) * 1970-02-07 1971-08-19 Metallgesellschat Ag Offene Gasturbinenanlage
EP0036998A2 (de) * 1980-03-28 1981-10-07 Kraftwerk Union Aktiengesellschaft Gasturbine mit durch Dampfeinspritzung verringerter Stickoxydemission
WO1983001812A1 (en) * 1981-11-19 1983-05-26 Gen Electric Sliding pressure flash tank
EP0081996A2 (de) * 1981-12-10 1983-06-22 Mitsubishi Gas Chemical Company, Inc. Gasturbinenprozess mit Wärmerückgewinnung
EP0086504A2 (de) * 1982-02-16 1983-08-24 Shell Internationale Researchmaatschappij B.V. Verfahren zum Erzeugen von mechnischer Kraft
EP0207620A2 (de) * 1985-06-04 1987-01-07 Imperial Chemical Industries Plc Wärmerückgewinnung

Cited By (21)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO1995000747A1 (de) * 1993-06-24 1995-01-05 Siemens Aktiengesellschaft Verfahren zum betreiben einer gas- und dampfturbinenanlage sowie danach arbeitende gud-anlage
WO1996031685A1 (de) * 1995-04-03 1996-10-10 Siemens Aktiengesellschaft Verfahren zum betreiben eines abhitzedampferzeugers sowie danach arbeitender abhitzedampferzeuger
US6041588A (en) * 1995-04-03 2000-03-28 Siemens Aktiengesellschaft Gas and steam turbine system and operating method
EP0767290A1 (de) * 1995-10-02 1997-04-09 Asea Brown Boveri Ag Verfahren zum Betrieb einer Kraftwerksanlage
EP0931911A3 (de) * 1998-01-19 2002-02-06 Kabushiki Kaisha Toshiba Kraftanlage mit kombiniertem Kreislauf
EP1065347A3 (de) * 1999-07-01 2003-03-05 General Electric Company Methode und Vorrichtung zur Befeuchtung und Heizung von Brenngas
EP1065347A2 (de) * 1999-07-01 2001-01-03 General Electric Company Methode und Vorrichtung zur Befeuchtung und Heizung von Brenngas
JP2001020757A (ja) * 1999-07-01 2001-01-23 General Electric Co <Ge> 燃料ガスを加湿加熱する方法及び装置
CN1325770C (zh) * 2000-10-17 2007-07-11 西门子公司 组合式燃气和蒸汽轮机设备中用于预热燃料的装置和方法
WO2002033225A1 (de) * 2000-10-17 2002-04-25 Siemens Aktiengesellschaft Vorrichtung und verfahren zur brennstoffvorwärmung in kombinierten gas- und dampfturbinenanlagen
US6920760B2 (en) 2000-10-17 2005-07-26 Siemens Aktiengesellschaft Device and method for preheating combustibles in combined gas and steam turbine installations
EP1199445A1 (de) * 2000-10-17 2002-04-24 Siemens Aktiengesellschaft Vorrichtung und Verfahren zur Brennstoffvorwärmung in kombinierten Gas- und Dampfturbinenanlagen
WO2002048509A1 (en) * 2000-11-29 2002-06-20 Alstom (Switzerland) Ltd A turbine arrangement and a method of operating a turbine arrangement
US6877320B2 (en) 2000-11-29 2005-04-12 Alstom Technology Ltd Turbine arrangement and a method of operating a turbine arrangement
WO2006133656A2 (en) * 2005-06-15 2006-12-21 Siemens Industrial Turbomachinery, S.R.O. Emissionless cycle with steam generator and heat transformer
WO2006133656A3 (en) * 2005-06-15 2007-05-24 Siemens Ind Turbomachinery S R Emissionless cycle with steam generator and heat transformer
RU2586802C2 (ru) * 2011-03-24 2016-06-10 Дженерал Электрик Компани Энергоустановка комбинированного цикла (варианты)
US9404393B2 (en) 2011-03-24 2016-08-02 General Electric Company Combined cycle power plant
CN103477034A (zh) * 2012-01-13 2013-12-25 阿尔斯通技术有限公司 超临界热回收蒸汽发生器的再热器和超临界蒸发器布置
CN103477034B (zh) * 2012-01-13 2015-08-12 阿尔斯通技术有限公司 超临界热回收蒸汽发生器的再热器和超临界蒸发器布置
US9429044B2 (en) 2012-01-13 2016-08-30 Alstom Technology Ltd Supercritical heat recovery steam generator reheater and supercritical evaporator arrangement

Also Published As

Publication number Publication date
NL9201256A (nl) 1994-02-01

Similar Documents

Publication Publication Date Title
KR100363071B1 (ko) 가스터빈및증기터빈플랜트와그리고가스터빈및증기터빈플랜트를작동시키기위한방법
US7640750B2 (en) Apparatus and method for producing energy at a pulp mill
US7350471B2 (en) Combustion system with recirculation of flue gas
US4479355A (en) Power plant integrating coal-fired steam boiler with air turbine
EP0588392A1 (de) GuD-Kraftanlage mit befeuchtetem Erdgas
EP0793790B1 (de) Verfahren zum betrieb eines kombikraftwerkes
US5175993A (en) Combined gas-turbine and steam-turbine power plant and method for utilization of the thermal energy of the fuel to improve the overall efficiency of the power-plant process
CA2206802C (en) Heavy oil emulsion fuel combustion apparatus
JPH01203802A (ja) 高圧、高温レベルの水蒸気製造システム
US6813888B2 (en) Integration construction between a boiler and a steam turbine and method in preheating of the supply water for a steam turbine and in its control
AU619025B2 (en) Combined gas-turbine and steam-turbine power plant and method for utilization of the thermal energy of the fuel to improve the overall efficiency of the power-plant process
EP1346134B1 (de) Integrierte konstruktion von einem kessel und einer dampfturbine und verfahren zur vorwärmung des speisewassers für eine dampfturbine und zu ihrer steuerung
EP0639254B1 (de) Methode anwendbar bei kleinen kraftanlagen
AU2004325009A1 (en) Device and method for boiler superheat temperature control
CN218409878U (zh) 亚临界煤气发电系统
SU1208406A1 (ru) Парогенерирующа установка
JPS5937521Y2 (ja) ボイラ装置
JP2000205556A (ja) 貫流ボイラ装置の運転方法
KR100902538B1 (ko) 보일러 및 보일러의 버너 개조 방법
GB2100356A (en) Power plant having steam and air turbines
JPH07238805A (ja) ごみ焼却発電設備
WO2002006726A1 (en) Process for heat extraction and power production with heat recovery
JPH06294306A (ja) メタノール焚ガスタービン複合プラントのメタノール蒸発方法
JPH04209904A (ja) 汽力発電設備のリパワリングシステム

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

AK Designated contracting states

Kind code of ref document: A1

Designated state(s): BE DE DK ES FR GB GR IT NL SE

17P Request for examination filed

Effective date: 19940623

17Q First examination report despatched

Effective date: 19950905

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

Free format text: STATUS: THE APPLICATION IS DEEMED TO BE WITHDRAWN

18D Application deemed to be withdrawn

Effective date: 19970211