EP3133343A1 - Gasturbine mit verdünntem flüssigbrennstoff - Google Patents

Gasturbine mit verdünntem flüssigbrennstoff Download PDF

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Publication number
EP3133343A1
EP3133343A1 EP15181350.8A EP15181350A EP3133343A1 EP 3133343 A1 EP3133343 A1 EP 3133343A1 EP 15181350 A EP15181350 A EP 15181350A EP 3133343 A1 EP3133343 A1 EP 3133343A1
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EP
European Patent Office
Prior art keywords
liquid fuel
line
gas turbine
fuel
pressure
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Withdrawn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
EP15181350.8A
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English (en)
French (fr)
Inventor
Adnan Eroglu
Jürgen Hoffmann
Michele Pesce
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.)
General Electric Technology GmbH
Original Assignee
General Electric Technology GmbH
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 General Electric Technology GmbH filed Critical General Electric Technology GmbH
Priority to EP15181350.8A priority Critical patent/EP3133343A1/de
Publication of EP3133343A1 publication Critical patent/EP3133343A1/de
Withdrawn legal-status Critical Current

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    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23R—GENERATING COMBUSTION PRODUCTS OF HIGH PRESSURE OR HIGH VELOCITY, e.g. GAS-TURBINE COMBUSTION CHAMBERS
    • F23R3/00—Continuous combustion chambers using liquid or gaseous fuel
    • F23R3/28—Continuous combustion chambers using liquid or gaseous fuel characterised by the fuel supply
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23D—BURNERS
    • F23D11/00—Burners using a direct spraying action of liquid droplets or vaporised liquid into the combustion space
    • F23D11/10—Burners using a direct spraying action of liquid droplets or vaporised liquid into the combustion space the spraying being induced by a gaseous medium, e.g. water vapour
    • F23D11/16—Burners using a direct spraying action of liquid droplets or vaporised liquid into the combustion space the spraying being induced by a gaseous medium, e.g. water vapour in which an emulsion of water and fuel is sprayed
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23K—FEEDING FUEL TO COMBUSTION APPARATUS
    • F23K5/00—Feeding or distributing other fuel to combustion apparatus
    • F23K5/02—Liquid fuel
    • F23K5/08—Preparation of fuel
    • F23K5/10—Mixing with other fluids
    • F23K5/12—Preparing emulsions
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23K—FEEDING FUEL TO COMBUSTION APPARATUS
    • F23K2300/00—Pretreatment and supply of liquid fuel
    • F23K2300/20—Supply line arrangements
    • F23K2300/204—Preheating

Definitions

  • the disclosure refers a gas turbine with liquid fuel and CO2 dilution of the liquid fuel.
  • the invention additionally refers to a method for operating such a gas turbine.
  • This invention relates generally to gas turbine engines, and more specifically to methods and apparatus for operating a gas turbine with liquid fuel.
  • Gas turbines are used to drive generators for power generation and among other to drive compressors and to power oil and gas production facilities.
  • liquid fuel such as fuel oil is available to power the gas turbines.
  • NOx water is typically used for emission control during fuel oil operation. This requires a separate NOx water system.
  • space and support infrastructure for such a NOx water system are limited and expensive.
  • emission limit values and overall emission permits are becoming more stringent also for off shore installations.
  • State-of-the-art combustion systems are designed to operate with water injection to reduce NOx emissions.
  • the purity requirements on NOx water are very high and it is difficult and costly to provide NOx water treatment systems in remote areas where water is rare or offshore installations.
  • water injection reduces the efficiency of gas turbine plants.
  • the object of the present disclosure is to provide a gas turbine and a method for operating a gas turbine, which enables stable, safe, efficient, and clean operation with liquid fuel without the need of water injection to mitigate NOx emissions.
  • a gas turbine has a compressor, a turbine, and a combustor.
  • the combustor typically comprises a burner for admitting a liquid fuel into the compressed air leaving the compressor and which enter the combustor as combustor inlet gas during operation.
  • a gas turbine has a fuel distribution system for supplying liquid fuel to the burner.
  • the fuel distribution system comprises a liquid fuel line and a CO2 line which is connected to the liquid fuel line for admixing CO2 into the liquid fuel before the mixture is injected into the burner.
  • Such a gas turbine allows admixing of CO2 for dilution of the liquid fuel and the injection of a CO2 liquid fuel mixture into the combustor.
  • the viscosity of the diluted liquid fuel is reduced thereby facilitating the creation of a fine spay during injection.
  • the presence of the CO2 delays the combustion reaction. Both effects reduce local peak temperatures and thereby reduce the production of thermal NOx.
  • the ratio of CO2 mass flow to fuel mass flow can for example be in the range of 0.1 to 2.5, or in the range of 0.2 to 1.5.
  • a liquid fuel control valve is arranged in the liquid fuel line and the CO2 line for admixing CO2 to the liquid fuel is connected to the liquid fuel line upstream of the liquid fuel control valve.
  • the liquid control valve typically creates flow inhomogeneities which facilitate mixing of the CO2 with the liquid fuel.
  • a liquid fuel control valve is arranged in the liquid fuel line and the CO2 line is connected to the liquid fuel line downstream of the liquid fuel control valve.
  • the CO2 line is connected to the liquid fuel line downstream of the liquid fuel control valve.
  • a separate control means such as a control valve can be provided to control the CO2 mass flow, respectively the CO2 volume flow.
  • the CO2 line can for example be joined to the liquid fuel line with a T-connection. To reduce pressure losses a y-shaped joint can be advantageous. Further, for example an annular arrangement in which CO2 is feed in a center pipe surrounded by a liquid fuel flow can be used. Alternatively an annular arrangement with liquid fuel feeding in a center pipe surrounded by a CO2 flow can be used.
  • a liquid fuel pump pressurizing the liquid fuel is provided in the liquid fuel line and a fuel preheater is arranged upstream of the liquid fuel pump.
  • the CO2 line is connected to the liquid fuel line downstream of the liquid fuel pump.
  • the liquid fuel pump pressurizes the liquid fuel to an injection pressure which is typically above the critical pressure of CO2.
  • the pressure in the fuel distribution system downstream of the CO2 admixing can be kept above the critical pressure of CO2 thus reducing the volume flow of CO2.
  • the reduced volume flow reduces the required size of the piping.
  • the temperature of the CO2 can be either below or above the critical temperature of CO2 or at the critical temperature of CO2.
  • the CO2 has a pressure higher than the critical pressure.
  • liquid phase or supercritical CO2 can be mixed to liquid fuel, such as oil, much easier than in the gas phase.
  • the liquid or supercritical phase of CO2 facilitates the mixing and dilution of the liquid fuel.
  • a larger CO2 to oil ratio can easily be achieved than by admixing gaseous CO2.
  • the fuel distribution system additionally comprises a NOx water line connected to the fuel line for admixing NOx water to the liquid fuel.
  • the NOx water system allows alternative or combined use of CO2 or NOx water depending on the availability of water, respectively CO2.
  • a fuel distribution system for supplying liquid fuel to the burner comprises the steps of admixing CO2 to the liquid fuel, forming a mixture of the liquid fuel and the CO2 and of injecting the mixture into the burner.
  • the CO2 is admixed to the liquid fuel upstream of a liquid fuel control valve.
  • the CO2 is admixed to the liquid fuel downstream of a liquid fuel control valve.
  • CO2 admixing can also be done at fuel injection lines just upstream of individual burners.
  • CO2 can also be feed into the liquid fuel supply system downstream of each fuel control valve.
  • the CO2 is admixed to the liquid fuel in one of a T-connection, a Y-connection, a concentric pipe connection, and a venturi nozzle.
  • the liquid fuel is preheated in a fuel preheater, then pressurized by a liquid fuel pump for pressurizing the liquid fuel, and then pressurized CO2 is admixed to the pressurized liquid fuel for dilution.
  • the liquid fuel can for example be pressurized to a pressure between the critical pressure of CO2 and 200 bars.
  • Preheating reduces the viscosity of the liquid fuel. For example when using heavy fuel oils or even crude oils a preheating is required before the fuel can be pressurized in a pump.
  • the preheated pressurized oil can be diluted by admixing of CO2 and then injected as a fine spray for example via swirl nozzles or any conventional liquid fuel nozzle.
  • Fuel can also be preheated using low grade heat or waste heat to improve the efficiency of the gas turbine or a combined cycle plant with such a gas turbine.
  • Mixing of the liquid fuel with the CO2 can take place at temperatures below the critical temperature of CO2 or above critical temperature. It can also take place with one flow, e.g. the liquid fuel, above and one flow, e.g. the CO2, below the critical temperature of CO2.
  • the CO2 can be supplied with a temperature below the critical temperature to reduce volume flow of CO2. Admixing cool liquid CO2 can lead to mixing temperature below the critical temperature thus keeping the total volume flow of the mixture low.
  • the temperature of the mixture can also be increased above the critical temperature of CO2 upon admixing leading to an increase in volume flow during admixing.
  • This increase can for example be used to in a venturi type admixer to boost the liquid fuel pressure.
  • the temperature of liquid fuel and CO2 can also be above critical temperature for both flows before mixing.
  • NOx water is admixed to the liquid fuel in addition to CO2 or during periods when no CO2 is available.
  • NOx water can be admixed for reduction of the NOx emissions as well as for power augmentation.
  • the mixture of liquid fuel and CO2 is injected into the combustor with a pressure higher than or equal to the critical pressure of CO2 wherein the combustion pressure inside the combustor is lower than the critical pressure of CO2.
  • the pressure drop leads to a strong increase of the CO2 volume flow which enhances the creation of small droplets during injection.
  • the pressure of the CO2 can be higher than the CO2 critical pressure (about 73.9 bar) and can be for example in the range 73.9-90 bar or preferably 73.9-80 bar and more preferably 73.9-77 bar;
  • the combustion pressure i.e. the pressure within the burner into which the mixture of fuel and CO2 is injected
  • the combustion pressure i.e. the pressure within the burner into which the mixture of fuel and CO2 is injected
  • the mixture of liquid fuel and CO2 is injected into the combustor with pressure higher than the critical pressure and a temperature below the critical temperature of CO2, and wherein the combustion pressure is lower than the critical pressure of CO2.
  • the injection leads to flash evaporization of the CO2 during injection into the combustor. Due to the flash evaporisation the mixture of liquid fuel and CO2 is burst into very small droplets. As a result a fine spray of liquid fuel in a CO2 enriched gas is created which allows good mixing with the compressed gas supplied to the combustion chamber by the compressor.
  • the CO2 further delays the ignition time so that peak temperatures are reduced and thermal NOx emissions are minimized.
  • the droplets can be about one order of magnitude smaller than droplets obtained by injection of the liquid fuel without flashing CO2.
  • the droplet size can be reduced from an order of 20 ⁇ m to 2 ⁇ m.
  • the CO2 is expended from a pressure higher than the critical pressure of CO2 to a pressure below the critical pressure of CO2 during admixing into the liquid fuel for boosting the pressure of the liquid fuel. This can for example be done in a venturi nozzle.
  • first combustor so called EV burner as known for example from the EP 0 321 809 or AEV burners as known for example from the DE195 47 913 can for example be used.
  • a BEV burner comprising a swirl chamber as described in the European Patent application EP12189388.7 , which is incorporated by reference, can be used.
  • a flamesheet combustor as described in US6935116 B2 or US7237384 B2 , which are incorporated by reference, can be used as first combustor.
  • the disclosure relates to gas turbine with one combustor as well as for gas turbines with sequential combustion.
  • a gas turbine with more than one fuel oil control valve for like for example in a gas turbine with sequential combustion the CO2 can also be feed into the liquid fuel supply system downstream of each fuel control valve.
  • Fig. 1 shows in a schematic representation the essential elements of a gas turbine power plant according to the invention.
  • the gas turbine 1 comprises a compressor 3 in which intake air 2 is compressed to form compressed air 11 for combustion. This is fed to a combustor.
  • a mixture of liquid fuel and CO2 (carbon dioxide) is injected into the compressed air 11 in a burner 9 and the mixture of fuel, CO2 and air is combusted in the combustion chamber 4.
  • the hot combustion gases 13 are then expanded in a turbine 5.
  • the useful energy which is generated in the turbine 5 is then transmitted to a consumer by the shaft 6.
  • the consumer can be a generator 12 which converts the mechanical energy into electric energy.
  • the hot exhaust gases 7 which issue from the turbine 5, for optimum utilization of the energy still contained therein, are typically used in a heat recovery steam generator (HRSG) for generating steam for a water-steam cycle (not shown).
  • HRSG heat recovery steam generator
  • the gas turbine 1 can further comprise a cooling system for the turbine 5 and combustor 8, which is also not shown as it is not subject of the invention.
  • the fuel is supplied to the burner 9 by fuel distribution system 27.
  • the fuel distribution system comprises a liquid fuel line 25 with a liquid fuel control valve, a CO2 line 24 with a CO2 control valve 21, and an optional NOx water line 26 with an optional NOx water control valve 23.
  • the liquid fuel line 25, the CO2 line 24, and the optional NOx water line 26 are connected to each other downstream of the respective control valves to a diluted fuel line 28 which is connected to the burners 9 of the gas turbine 1.
  • the CO2 line 24 is also connected to a source of CO2 having a pressure higher than the critical pressure.
  • the diluted fuel line 28 can comprise a ring shaped section encircling an arrangement of combustors 8 from which lines branch to each burner 9.
  • Fig. 2 is based on Fig. 1 . It differs from the example of Fig. 1 in that the CO2 line 24 is connected to the liquid fuel line 25 upstream of the liquid fuel control valve 22.
  • the CO2 is admixed to the liquid fuel with the help of a venturi nozzle 32 which is arranged in the liquid fuel line 25 upstream of the liquid fuel control valve 22.
  • the CO2 line is connected to the inlet of the venturi nozzle 32 for the driving fluid.
  • the CO2 can be used to boost the liquid fuel pressure.
  • the optional NOx water line 26 is connected to the diluted fuel line 28 which connects the liquid fuel control valve 22 to burners 9.
  • Fig. 2 shows a gas turbine 1 used as a mechanical drive which is connected to an industrial compressor 16, such as for example a pipeline compressor.
  • Fig. 3 is also based on Fig. 1 . It differs from example of Fig. 1 in that the optimal NOx water line is not shown.
  • a liquid fuel preheater 30 and a liquid fuel pump 31 are arranged along the liquid fuel line 25 upstream of the liquid fuel control valve 22.
  • a CO2 compressor 14 followed by a CO2 heater 15 is arranged in the CO2 line 24 upstream of the CO2 control valve 21.
  • Figs. 4a to 4c show different connecting types for connecting the CO2 line 24 to the liquid fuel line 25.
  • the Fig 4a shows an example in which the CO2 line 24 is connected to the liquid fuel line 25 in a T-arrangement.
  • the Fig 4b shows an example in which the CO2 line 24 and the liquid fuel line 25 join in a y arrangement where the diluted fuel line 28 is the foot of the y. In this arrangement the pressure drop is reduced.
  • a static mixer 29 is arranged in the diluted fuel line 28.
  • the Fig 4b shows an example in which the CO2 line 24 and the liquid fuel line 25 are arranged concentrically to minimize the pressure drop of the liquid fuel.
  • the CO2 line 24 penetrates the liquid fuel line 25 from a side wall and turns in a right angle into the flow direction of the liquid fuel.
  • Flame Sheet, EV, AEV or BEV burners can be used for can as well as for annular architectures.
EP15181350.8A 2015-08-18 2015-08-18 Gasturbine mit verdünntem flüssigbrennstoff Withdrawn EP3133343A1 (de)

Priority Applications (1)

Application Number Priority Date Filing Date Title
EP15181350.8A EP3133343A1 (de) 2015-08-18 2015-08-18 Gasturbine mit verdünntem flüssigbrennstoff

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
EP15181350.8A EP3133343A1 (de) 2015-08-18 2015-08-18 Gasturbine mit verdünntem flüssigbrennstoff

Publications (1)

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EP3133343A1 true EP3133343A1 (de) 2017-02-22

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EP15181350.8A Withdrawn EP3133343A1 (de) 2015-08-18 2015-08-18 Gasturbine mit verdünntem flüssigbrennstoff

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Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR3105985A1 (fr) * 2020-01-03 2021-07-09 Safran Aircraft Engines Circuit multipoint d’injecteur amélioré

Citations (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0321809A1 (de) 1987-12-21 1989-06-28 BBC Brown Boveri AG Verfahren für die Verbrennung von flüssigem Brennstoff in einem Brenner
US5170727A (en) * 1991-03-29 1992-12-15 Union Carbide Chemicals & Plastics Technology Corporation Supercritical fluids as diluents in combustion of liquid fuels and waste materials
DE19547913A1 (de) 1995-12-21 1997-06-26 Abb Research Ltd Brenner für einen Wärmeerzeuger
US6293525B1 (en) * 1998-06-15 2001-09-25 Irwin Ginsburgh Economical apparatus for producing improved combustion and safety-enhanced fuel
EP1314689A2 (de) * 2001-11-21 2003-05-28 Lurgi AG Verfahren zur Herstellung von Synthesegas
US6935116B2 (en) 2003-04-28 2005-08-30 Power Systems Mfg., Llc Flamesheet combustor
US7237384B2 (en) 2005-01-26 2007-07-03 Peter Stuttaford Counter swirl shear mixer
JP5180805B2 (ja) * 2008-12-22 2013-04-10 三菱重工業株式会社 ガスタービンシステム
EP2587160A2 (de) * 2011-10-24 2013-05-01 General Electric Company System zur Turbinenbrennkammerbrennstoffmischung

Patent Citations (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0321809A1 (de) 1987-12-21 1989-06-28 BBC Brown Boveri AG Verfahren für die Verbrennung von flüssigem Brennstoff in einem Brenner
US5170727A (en) * 1991-03-29 1992-12-15 Union Carbide Chemicals & Plastics Technology Corporation Supercritical fluids as diluents in combustion of liquid fuels and waste materials
DE19547913A1 (de) 1995-12-21 1997-06-26 Abb Research Ltd Brenner für einen Wärmeerzeuger
US6293525B1 (en) * 1998-06-15 2001-09-25 Irwin Ginsburgh Economical apparatus for producing improved combustion and safety-enhanced fuel
EP1314689A2 (de) * 2001-11-21 2003-05-28 Lurgi AG Verfahren zur Herstellung von Synthesegas
US6935116B2 (en) 2003-04-28 2005-08-30 Power Systems Mfg., Llc Flamesheet combustor
US7237384B2 (en) 2005-01-26 2007-07-03 Peter Stuttaford Counter swirl shear mixer
JP5180805B2 (ja) * 2008-12-22 2013-04-10 三菱重工業株式会社 ガスタービンシステム
EP2587160A2 (de) * 2011-10-24 2013-05-01 General Electric Company System zur Turbinenbrennkammerbrennstoffmischung

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR3105985A1 (fr) * 2020-01-03 2021-07-09 Safran Aircraft Engines Circuit multipoint d’injecteur amélioré

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