US20070003897A1 - Burner, gas turbine combustor, burner cooling method, and burner modifying method - Google Patents

Burner, gas turbine combustor, burner cooling method, and burner modifying method Download PDF

Info

Publication number
US20070003897A1
US20070003897A1 US11/473,062 US47306206A US2007003897A1 US 20070003897 A1 US20070003897 A1 US 20070003897A1 US 47306206 A US47306206 A US 47306206A US 2007003897 A1 US2007003897 A1 US 2007003897A1
Authority
US
United States
Prior art keywords
fuel
nozzle
startup
combustion chamber
fuel nozzle
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.)
Abandoned
Application number
US11/473,062
Other languages
English (en)
Inventor
Hiromi Koizumi
Hiroshi Inoue
Toshifumi Sasao
Isao Takehara
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.)
Hitachi Ltd
Original Assignee
Hitachi Ltd
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 Hitachi Ltd filed Critical Hitachi Ltd
Assigned to HITACHI, LTD. reassignment HITACHI, LTD. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: TAKEHARA, ISAO, INOUE, HIROSHI, KOIZUMI, HIROMI, SASAO, TOSHIFUMI
Publication of US20070003897A1 publication Critical patent/US20070003897A1/en
Priority to US13/627,565 priority Critical patent/US20130019584A1/en
Abandoned legal-status Critical Current

Links

Images

Classifications

    • 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
    • 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
    • F23R3/02—Continuous combustion chambers using liquid or gaseous fuel characterised by the air-flow or gas-flow configuration
    • F23R3/04—Air inlet arrangements
    • 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
    • F23R3/283—Attaching or cooling of fuel injecting means including supports for fuel injectors, stems, or lances
    • 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
    • F23R3/286—Continuous combustion chambers using liquid or gaseous fuel characterised by the fuel supply having fuel-air premixing devices
    • 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
    • F23R3/34—Feeding into different combustion zones
    • F23R3/343—Pilot flames, i.e. fuel nozzles or injectors using only a very small proportion of the total fuel to insure continuous combustion
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23K—FEEDING FUEL TO COMBUSTION APPARATUS
    • F23K2400/00—Pretreatment and supply of gaseous fuel
    • F23K2400/10—Pretreatment
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23L—SUPPLYING AIR OR NON-COMBUSTIBLE LIQUIDS OR GASES TO COMBUSTION APPARATUS IN GENERAL ; VALVES OR DAMPERS SPECIALLY ADAPTED FOR CONTROLLING AIR SUPPLY OR DRAUGHT IN COMBUSTION APPARATUS; INDUCING DRAUGHT IN COMBUSTION APPARATUS; TOPS FOR CHIMNEYS OR VENTILATING SHAFTS; TERMINALS FOR FLUES
    • F23L2900/00—Special arrangements for supplying or treating air or oxidant for combustion; Injecting inert gas, water or steam into the combustion chamber
    • F23L2900/07002—Injecting inert gas, other than steam or evaporated water, into the combustion chambers
    • 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
    • F23R2900/00—Special features of, or arrangements for continuous combustion chambers; Combustion processes therefor
    • F23R2900/00002—Gas turbine combustors adapted for fuels having low heating value [LHV]
    • 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
    • F23R2900/00—Special features of, or arrangements for continuous combustion chambers; Combustion processes therefor
    • F23R2900/00016—Retrofitting in general, e.g. to respect new regulations on pollution
    • 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
    • F23R2900/00—Special features of, or arrangements for continuous combustion chambers; Combustion processes therefor
    • F23R2900/03041—Effusion cooled combustion chamber walls or domes

Definitions

  • the present invention relates to a burner using mixed fuel containing at least one of hydrogen and carbon monoxide, and also relates to a gas turbine combustor, a burner cooling method, and a burner modifying method.
  • mixed fuel multi-component mixed gas fuel containing hydrogen, carbon monoxide, etc.
  • LNG liquefied natural gas
  • A-heavy oil Such mixed fuel has a higher flame temperature than LNG.
  • hydrogen has a wider flammable range and a faster burning velocity and is easy to burn.
  • LNG is burned primarily by employing a premixed combustion system.
  • the mixed fuel is burned by employing the premixed combustion system, flashback is apt to occur due to change of combustion characteristics caused by change of fuel composition and the presence of hydrogen and/or carbon oxide in the mixed fuel. It is therefore difficult to burn the mixed fuel by employing the premixed combustion system.
  • the mixed fuel is generally burned by a burner employing a diffusive combustion system in which fuel and air are separately injected into a combustion chamber (see, e.g., Patent Document 1: JP,A 2004-3730).
  • the mixed fuel containing hydrogen even when the mixed fuel is burned in a manner of diffusive combustion, due care has to be paid to safety at the time of ignition in a gas turbine. It is hence desired that another kind of fuel, e.g., light oil, be used at the startup of the gas turbine.
  • another kind of fuel e.g., light oil
  • the operating mode is shifted from a mode using fuel for the startup to a gas combustion mode using only the mixed fuel after the steps of startup, acceleration and application of load.
  • gas combustion mode means the operating mode in which only the mixed fuel is supplied to a combustor.
  • An object of the present invention is to provide a burner, a gas turbine combustor, a burner cooling method, and a burner modifying method, which can hold metal temperature at a nozzle surface within a proper range and can increase reliability even when mixed fuel containing at least one of hydrogen and carbon monoxide is used as fuel.
  • the present invention provides a burner for injecting mixed fuel containing at least one of hydrogen and carbon monoxide into a combustion chamber of a gas turbine combustor, wherein the burner comprises a fuel nozzle for startup from which fuel for startup is injected into the combustion chamber; a mixed fuel nozzle disposed around the fuel nozzle for startup and injecting the mixed fuel; an air swirler disposed at a downstream end of the mixed fuel nozzle positioned in the combustion chamber and having a plurality of flow passages through which a part of compressed air from a compressor is injected into the combustion chamber to hold a flame, the mixed fuel nozzle having injection ports disposed in the inner peripheral side of the flow passages of the air swirler; and cooling holes formed in a nozzle surface positioned to face the combustion chamber and introducing a part of the mixed fuel injected from the mixed fuel nozzle into the combustion chamber, to thereby reduce flame temperature near the nozzle surface.
  • the fuel nozzle for startup comprises a liquid fuel nozzle for injecting liquid fuel for the startup of the gas turbine, and an atomizing air nozzle disposed around the liquid fuel nozzle and injecting atomizing air to atomize the liquid fuel.
  • the fuel nozzle for startup is disposed at a center of a combustion liner forming the combustion chamber in the radial direction.
  • the burner further comprises an inert gas supply system for supplying inert gas to the fuel nozzle for startup, wherein the inert gas from the inert gas supply system is supplied to the fuel nozzle for startup such that the inert gas is injected to the vicinity of the nozzle surface from the fuel nozzle for startup during a gas combustion mode using only the mixed fuel.
  • the mixed fuel is any of coke oven gas, blast furnace gas, LD gas, coal, and heavy oil gasification gas.
  • the present invention provides a gas turbine combustor for burning mixed fuel containing at least one of hydrogen and carbon monoxide
  • the combustor comprises an outer casing serving as a pressure vessel; a combustion liner disposed inside the outer casing and forming a combustion chamber therein; a burner for forming a flame in the combustion chamber within the combustion liner; and a transition piece for introducing, to a burner, the burned gas generated with the formation of the flame by the burner, the burner comprising a fuel nozzle for startup from which fuel for startup is injected into the combustion chamber; a mixed fuel nozzle disposed around the fuel nozzle for startup and injecting the mixed fuel; an air swirler disposed at a downstream end of the mixed fuel nozzle positioned in the combustion chamber and having a plurality of flow passages through which a part of compressed air from a compressor is injected into the combustion chamber to hold a flame, the mixed fuel nozzle having injection ports disposed in the inner peripheral side of the flow passages of the air swirl
  • the present invention provides a method of cooling a burner employing a diffusive combustion system and injecting mixed fuel containing at least one of hydrogen and carbon monoxide into a combustion chamber of a gas turbine combustor, wherein the method comprises the steps of forming cooling holes in a nozzle surface positioned to face the combustion chamber such that a part of the mixed fuel is injected through the cooling holes; and injecting the part of the mixed fuel into the combustion chamber through the cooling holes, to thereby reduce flame temperature near the nozzle surface and suppress a rise of metal temperature at the nozzle surface.
  • the present invention provides a burner for injecting mixed fuel containing at least one of hydrogen and carbon monoxide into a combustion chamber of a gas turbine combustor, wherein the burner comprises a fuel nozzle for startup which comprises a liquid fuel nozzle for injecting liquid fuel for the startup of the gas turbine, and an atomizing air nozzle disposed around the liquid fuel nozzle and injecting atomizing air to atomize the liquid fuel; a mixed fuel nozzle disposed around the fuel nozzle for startup and injecting the mixed fuel; an air swirler disposed at a downstream end of the mixed fuel nozzle positioned in the combustion chamber and injecting a part of compressed air from a compressor into the combustion chamber to hold a flame; and an inert gas supply system for supplying inert gas to the fuel nozzle for startup, the inert gas from the inert gas supply system being supplied to the fuel nozzle for startup such that the inert gas is injected to the vicinity of a nozzle surface from the fuel nozzle for startup during
  • the present invention provides a gas turbine combustor for burning mixed fuel containing at least one of hydrogen and carbon monoxide
  • the combustor comprises an outer casing serving as a pressure vessel; a combustion liner disposed inside the outer casing and forming a combustion chamber therein; a burner for forming a flame in the combustion chamber within the combustion liner; and a transition piece for introducing, to a turbine, burned gas generated with the formation of the flame by the burner, the burner comprising a fuel nozzle for startup which comprises a liquid fuel nozzle for injecting liquid fuel for the startup of the gas turbine, and an atomizing air nozzle disposed around the liquid fuel nozzle and injecting atomizing air to atomize the liquid fuel; a mixed fuel nozzle disposed around the fuel nozzle for startup and injecting the mixed fuel; an air swirler disposed at a downstream end of the mixed fuel nozzle positioned in the combustion chamber and injecting a part of compressed air from a compressor into the combustion chamber to hold
  • the present invention provides a method of cooling a burner employing a diffusive combustion system and injecting mixed fuel containing at least one of hydrogen and carbon monoxide into a combustion chamber of a gas turbine combustor, wherein the method comprises the steps of providing a mixed fuel nozzle for injecting the mixed fuel to be disposed around a fuel nozzle for startup from which fuel for startup is injected into the combustion chamber; and supplying inert gas from an inert gas supply system to the fuel nozzle for startup such that the inert gas is injected to the vicinity of a nozzle surface from the fuel nozzle for startup during a gas combustion mode using only the mixed fuel, thereby reducing flame temperature near the nozzle surface and suppressing a rise of metal temperature at the nozzle surface.
  • the present invention provides a burner for injecting mixed fuel containing at least one of hydrogen and carbon monoxide into a combustion chamber of a gas turbine combustor, wherein the burner comprises a fuel nozzle for startup from which fuel for startup is injected into the combustion chamber; a mixed fuel nozzle disposed around the fuel nozzle for startup and injecting the mixed fuel; an air swirler disposed at a downstream end of the mixed fuel nozzle positioned in the combustion chamber and having a plurality of flow passages through which a part of compressed air from a compressor is injected into the combustion chamber to hold a flame, the mixed fuel nozzle having injection ports disposed in the inner peripheral side of the flow passages of the air swirler; and a unit for purging the fuel residing in the fuel nozzle for startup.
  • the unit for purging the fuel includes a system for supplying a part of the mixed fuel, which is supplied to the mixed fuel nozzle, to the fuel nozzle for startup.
  • the present invention provides a burner for injecting mixed fuel containing at least one of hydrogen and carbon monoxide into a combustion chamber of a gas turbine combustor, wherein the burner comprises a fuel nozzle for startup from which fuel for startup is injected into the combustion chamber; a mixed fuel nozzle disposed around the fuel nozzle for startup and injecting the mixed fuel; a swirler disposed to face the combustion chamber and including an air swirler disposed at a downstream end of the mixed fuel nozzle positioned in the combustion chamber and having a plurality of flow passages through which a part of compressed air from a compressor is injected into the combustion chamber to hold a flame, the mixed fuel nozzle having injection ports disposed in the inner peripheral side of the flow passages of the air swirler; and a unit for reducing flame temperature in the vicinity of the swirler disposed to face the combustion chamber to be lower than the melting point of a swirler material.
  • the present invention provides a method of modifying a burner for injecting mixed fuel containing at least one of hydrogen and carbon monoxide into a combustion chamber of a gas turbine combustor, the burner comprising a fuel nozzle for startup which comprises a liquid fuel nozzle for injecting liquid fuel for the startup of the gas turbine, and an atomizing air nozzle disposed around the liquid fuel nozzle and injecting atomizing air to atomize the liquid fuel; a mixed fuel nozzle disposed around the fuel nozzle for startup and injecting the mixed fuel; and a plurality of flow passages which are formed in a downstream end of the mixed fuel nozzle positioned in the combustion chamber and through which a part of compressed air from a compressor is injected into the combustion chamber to hold a flame, wherein the method includes the step of additionally providing, on the burner, a unit for supplying inert gas to the atomizing air nozzle.
  • the flame temperature can be reduced by increasing a fuel concentration near the nozzle surface, whereby the metal temperature at the nozzle surface can be held within a proper range and reliability can be increased.
  • the metal temperature at the nozzle surface can also be held within the proper range by supplying inert gas to the vicinity of the nozzle surface.
  • FIG. 1 is a schematic view of a gas turbine plant equipped with a burner related to a first embodiment of the present invention
  • FIG. 2 is a partial enlarged side sectional view of the burner related to a first embodiment of the present invention
  • FIG. 3 is a front view, looking from the combustion chamber side, of the burner related to the first embodiment of the present invention
  • FIG. 4 is a partial enlarged side sectional view of a burner related to a second embodiment of the present invention.
  • FIG. 5 is a front view, looking from the combustion chamber side, of the burner related to the second embodiment of the present invention.
  • FIG. 6 is a schematic view of a gas turbine plant equipped with the burner related to the second embodiment of the present invention.
  • FIG. 7 is a graph showing the relationship between a mass flow ratio of fuel (mixed gas of hydrogen, methane and nitrogen) to air and adiabatic flame temperature;
  • FIG. 8 is a graph showing the correlation between supply of atomizing air and inert gas and metal temperature at a nozzle surface after a shift to a gas combustion mode using only the mixed fuel.
  • FIG. 9 is a schematic view showing a system for purging liquid fuel residing in a nozzle for startup.
  • FIG. 1 is a schematic view of a gas turbine plant equipped with a burner related to a first embodiment of the present invention.
  • the gas turbine plant equipped with the burner related to this first embodiment comprises an air compressor 2 , a combustor 3 , a turbine 4 , a generator 6 , a startup motor 8 for driving a gas turbine, and so on.
  • Inlet air 101 is compressed in the air compressor 2 , and compressed air 102 from the air compressor 2 is burned in the combustor 3 together with fuel 200 and 201 .
  • burned gas 110 from the combustor 3 is supplied to the turbine 4 , the turbine 4 produces torque with the burned gas 110 , and the torque produced by the turbine 4 is transmitted to both the air compressor 2 and the generator 6 .
  • the torque transmitted to the air compressor 2 is used as power for compressing air, and the torque transmitted to the generator 6 is converted to electrical energy.
  • the generator 6 is shown as being load equipment in FIG. 1 , a pump, etc. may also be used as the load equipment.
  • the turbine 4 is not limited to the one-shaft type, and it may be of the two-shaft type.
  • the combustor 3 in this first embodiment burns multi-component mixed gas fuel (hereinafter referred to simply as “mixed fuel”) containing at least one of hydrogen (H 2 ) and carbon monoxide (CO).
  • the gas turbine plant includes supply systems for supplying not only gas fuel 201 , i.e., the mixed fuel, but also liquid fuel 200 used as fuel for startup of the gas turbine, atomizing air 103 for atomizing the liquid fuel 200 , and inert gas (steam) 104 necessary for reducing NOx.
  • the gas fuel 201 burned in the combustor 3 is, for example, multi-component gas fuel such as coke oven gas, blast furnace gas and LD gas, or coal containing hydrogen and carbon monoxide which are obtained by gasifying coal, heavy oil and other materials with the aid of oxygen, or heavy oil gasification gas.
  • the liquid fuel 200 is, for example, light oil or A-heavy oil.
  • the combustor 3 comprises an outer casing 10 working as a pressure vessel, a combustion liner 12 disposed inside the outer casing 10 and forming a combustion chamber therein, a burner 13 for forming a flame in the combustion chamber within the combustion liner 12 , and a transition piece (not shown) for introducing, to the turbine 4 , the burned gas 110 generated with the formation of the flame by the burner 13 .
  • the burner 13 employs a diffusive combustion system and is provided one for each unit of the combustor.
  • FIG. 2 is a partial enlarged side sectional view of the burner 13
  • FIG. 3 is a front view, looking from the combustion chamber side, of the burner 13 .
  • the burner 13 comprises a fuel nozzle 15 for startup from which the liquid fuel 200 used as the fuel for startup is injected into the combustion chamber, a mixed fuel nozzle 16 for injecting the gas fuel 201 , and an air swirler 17 for injecting a part 102 a of the compressed air 102 from the air compressor 2 into the combustion chamber in order to hold the flame.
  • the fuel nozzle 15 for startup is disposed at a center of the combustion chamber in the radial direction, and it comprises a liquid fuel nozzle 20 for injecting the liquid fuel 200 for the startup of the gas turbine, and an atomizing air nozzle 21 for injecting the atomizing air 103 to atomize the liquid fuel 200 .
  • the atomizing air nozzle 21 is formed by an inner casing 22 disposed so as to surround the liquid fuel nozzle 20 .
  • the atomizing air 103 and the inert gas (steam) 104 flow through a flow passage formed between an inner wall surface of the liner 22 and an outer wall surface of the liquid fuel nozzle 20 .
  • the mixed fuel nozzle 16 has a main body, i.e., a body 23 , disposed so as to surround the atomizing air nozzle 21 .
  • the gas fuel 201 flows through a flow passage formed between an inner wall surface of the body 23 and an outer wall surface of the inner casing 22 of the atomizing air nozzle 21 .
  • the air swirler 17 is disposed at a downstream end of the mixed fuel nozzle 16 positioned in the combustion chamber. As shown in FIGS. 2 and 3 , the air swirler 17 has a plurality of flow passages 17 a formed at constant intervals in the circumferential direction so that a swirl component is given to the compressed air 102 a .
  • the flow passages 17 a are formed to radially obliquely extend with respect to an outer circumference of the body 23 on the side close to the combustion chamber.
  • a part 102 a of the compressed air 102 supplied from the air compressor 2 to the combustor 3 is introduced to the flow passages 17 a of the air swirler 17 by the action of pressure balance.
  • the remaining compressed air 102 flows into the combustion chamber through combustion air holes and cooling holes which are formed in the combustion liner 12 . Accordingly, the combustion liner 12 can be cooled by the compressed air from the air compressor 2 at the same time.
  • Injection ports 16 a of the mixed fuel nozzle 16 are disposed at the inner peripheral side of the flow passage 17 a of the air swirler 17 such that the gas fuel 201 injected through the injection ports 16 a is introduced into the combustion chamber together with the swirl flow injected from the air swirler 17 .
  • the swirled compressed air 102 a from the air swirler 17 and the gas fuel 201 are mixed, whereby the flame is held in front of the air swirler 17 .
  • Cooling holes 53 are formed in a nozzle surface (swirler surface) 18 of the burner 13 , which is positioned to face the combustion chamber.
  • the cooling holes 53 are formed in large numbers in a region between the injection port 21 a of the atomizing air and the flow passages 17 a of the air swirler 17 to be communicated with a flow passage of the mixed fuel nozzle 16 .
  • a part 201 a of the gas fuel 201 injected from the mixed fuel nozzle 16 is introduced into the combustion chamber through the cooling holes 53 .
  • the fuel concentration near the nozzle surface 18 is enriched.
  • a startup fuel supply system for supplying the liquid fuel 200 to the fuel nozzle 15 for startup, and a mixed fuel supply system for supplying the gas fuel 201 to the mixed fuel nozzle 16 .
  • the startup fuel supply system is connected to an inlet port 20 b of the liquid fuel nozzle 20
  • the mixed fuel supply system is connected to an inlet port 16 b of the mixed fuel nozzle 16 .
  • Each of those supply systems includes a control valve (not shown) for adjusting a fuel mass flow.
  • an atomizing air supply system for supplying the atomizing air 103 to the atomizing air nozzle 21 is connected to an inlet port 21 b of the atomizing air nozzle 21
  • an inert gas supply system for supplying the inert gas 104 to the air swirler 17 is connected to an inlet port 10 b of the combustor outer casing 10 .
  • the atomizing air supply system and the inert gas supply system are connected to each other through a bypass line.
  • a shutoff valve 300 is disposed to selectively open and close a flow passage of the bypass line.
  • a shutoff valve 301 for selectively opening and closing a flow passage of the inert gas supply system and a steam flow control valve 302 for adjusting a mass flow of the steam flowing through the inert gas supply system are disposed in this order from the upstream side.
  • the gas turbine is driven by an external motive power supplied from, e.g., the startup motor 8 and ignition is started in the combustor 3 by using the compressed air 102 discharged from the air compressor 2 and the liquid fuel 200 .
  • the burned gas 110 from the combustor 3 is supplied to the turbine 4 so that torque is given to the turbine 4 .
  • the rotational speed of the turbine 4 is increased, and by stopping the startup motor 8 , the gas turbine is shifted to a self-sustaining operation.
  • the generator 6 is brought into operation and the mass flow of the liquid fuel 200 is further increased, whereby the inlet gas temperature in the turbine 4 rises and a load is increased.
  • the steam 104 is injected into the combustor 3 from the inert gas supply system to suppress the amount of NOx emission.
  • the steam 104 supplied to the combustor 3 passes through the shutoff valve 301 and is adjusted to a proper mass flow by the steam flow control valve 302 .
  • the steam 104 is mixed with the combustion air 102 a from the air compressor 2 and is injected into the combustion chamber through the flow passages 17 a of the air swirler 17 .
  • the oxygen concentration of the combustion air 102 a is reduced after being mixed with the steam 104 .
  • the liquid fuel 200 is burned with air having the reduced oxygen concentration, the flame temperature in the combustion chamber lowers and the NOx emission is suppressed.
  • the fuel changeover operation is to decrease the mass flow of the liquid fuel 200 and to increase the feed rate of the gas fuel 201 while the load of the gas turbine is kept constant.
  • the load can be further increased with an increase in the mass flow of the gas fuel 201 .
  • air is usually injected from the downstream nozzle surface of the burner positioned in the combustion chamber so that the fuel for startup is atomized.
  • the supply of air for that purpose affects the metal temperature at the nozzle surface to a large extent when the multi-component mixed gas is burned. The reasons will be described below with reference to FIGS. 7 and 8 .
  • FIG. 7 is a graph showing the relationship between a mass flow ratio (F/A) of fuel (mixed gas of hydrogen, methane and nitrogen) to air and adiabatic flame temperature.
  • F/A mass flow ratio
  • the adiabatic flame temperature (° C.) has such a tendency to rise as F/A (kg/kg) is increased, to maximize at a certain F/A condition, and thereafter to lower gradually when F/A is further increased.
  • the F/A at which the adiabatic flame temperature is maximized is called a stoichiometric ratio.
  • the region in which F/A is lower than that ratio is called a fuel lean region, and the region in which F/A is higher than that ratio is called a fuel rich region.
  • the F/A value comes closer to the stoichiometric ratio when the atomizing air is supplied (area A in FIG. 7 ) than that when the atomizing air is not supplied (area B in FIG. 7 ).
  • the fuel rich region is formed near the nozzle surface of the combustor 3 .
  • F/A comes closer to the stoichiometric ratio and the flame temperature (combustion temperature) rises.
  • the inert gas e.g., steam
  • the adiabatic flame temperature tends to lower (area C in FIG. 7 ).
  • FIG. 8 is a graph showing the correlation between the supply of the atomizing air and the inert gas and the metal temperature at the nozzle surface after the shift to the gas combustion mode using only the mixed fuel.
  • FIG. 8 represents the case where the mixed gas of hydrogen, methane and nitrogen is burned.
  • the metal temperature is higher when the atomizing air is supplied than that when the atomizing air is not supplied, and the metal temperature is lower when the inert gas is supplied than that when the inert gas is not supplied. This is presumably attributable to the fact that F/A near the nozzle surface is changed and the combustion temperature is also changed depending on the atomizing air and the inert gas supply.
  • the metal temperature is more strongly affected by the flame temperature.
  • a rise of the metal temperature at the nozzle surface can be suppressed by paying consideration such that F/A near the nozzle surface does not satisfy the condition providing the value of F/A in the vicinity of the stoichiometric ratio.
  • the cooling holes 53 for introducing a part of the mixed gas fuel 201 are formed in the nozzle surface, the fuel concentration near the nozzle surface is enriched. Therefore, F/A in an area near the nozzle surface can be increased and the flame temperature near the nozzle surface can be reduced. It is hence possible to avoid a phenomenon of an increase in the flame temperature, which is caused due to a shift of F/A toward the stoichiometric ratio in the case of air cooling, and to lower the metal temperature at the nozzle surface.
  • the temperature of fuel supplied to the gas turbine differs to some extent depending on the kind of fuel
  • the temperature of coke oven gas or the like is not higher than 100° C. and the temperature of gasification gas obtained by gasifying coal with the aid of oxygen is not higher than 200-300° C.
  • Those temperatures are lower than the temperature (about 390° C.) of the air discharged from the compressor (i.e., the compressor discharge temperature). Therefore, a higher cooling capability than that in the case of air cooling can be obtained by utilizing sensible heat of the fuel.
  • the metal temperature at the nozzle surface can be held within a proper range while ensuring combustion stability within a working load range of the gas turbine, whereby reliability can be improved.
  • the injection ports 16 a for the gas fuel 201 are formed at the inner peripheral side of the flow passages 17 a of the air swirler 17 , the injection ports 16 a are subjected to the dynamic pressure of the compressed air 102 a .
  • the compressed air 102 a from the air compressor 2 is supplied to the mixed fuel nozzle 16 through the injection ports 16 a , and then the compressed air 102 a is introduced into the combustion chamber through the cooling holes 53 formed in the nozzle surface.
  • the injected liquid fuel 200 and the compressed air 102 a introduced through the cooling holes 53 are mixed.
  • liquid fuel is burned through processes of atomization of the liquid fuel, vaporization of the atomized fuel, mixing of the vaporized fuel and air, and combustion. Therefore, if the mixing of the fuel and air is insufficient, the carbonaceous concentration, such as soot, is increased during the combustion.
  • the compressed air 102 a is supplied through the cooling holes 53 for introducing the gas fuel 201 in the vicinity of an atomizing sheath (injection hole 21 a ) through which the liquid fuel for startup is injected while being atomized. This leads to an additional advantage of suppressing the generation of soot, which is caused with combustion of the liquid fuel.
  • a part of the inert gas 104 e.g., steam, which is used to reduce NOx
  • the atomizing air supply system constituted by the fuel nozzle 15 for startup e.g., steam
  • the steam 104 required for reducing NOx is supplied after the operating mode is shifted to the gas combustion mode using only the gas fuel 201 and the supply of the atomizing air 103 is stopped. Since the flame temperature near the nozzle surface lowers (see also FIG. 7 ) by injecting the steam 104 through the fuel nozzle 15 for startup, which is disposed at the center of the nozzle surface, the metal temperature at the nozzle surface can be reduced.
  • a check valve has to be disposed in the atomizing air supply system to prevent backflow of the steam 104 when the steam 104 is supplied to the fuel nozzle 15 for startup.
  • inert gas e.g., nitrogen or carbon dioxide
  • Such a case can also provide similar advantages to those described above.
  • While the above-described embodiment includes both the structure for injecting the gas fuel 201 through the cooling holes 53 and the structure for injecting the inert gas from the atomizing air supply system for the fuel nozzle 15 for startup, a high cooling effect can also be obtained with either one of those two structures.
  • the function of cooling the nozzle surface by injecting the inert gas through the center of the nozzle surface is omitted, for example, it is just required to omit the shutoff valve 300 and the bypass line in which the shutoff valve 300 is disposed.
  • the cooling function obtained by injecting the mixed fuel through the cooling holes 53 is omitted, the effect of cooling the nozzle surface can be obtained by injecting the inert gas through the center of the nozzle surface.
  • FIG. 4 is a partial enlarged side sectional view of a burner according to a second embodiment of the present invention, in which the cooling holes 53 in the first embodiment are omitted
  • FIG. 5 is a front view, looking from the combustion chamber side, of the burner according to the second embodiment.
  • similar components to those in FIGS. 1, 2 and 3 are denoted by the same reference numerals and a description of those components is omitted here.
  • the injection ports 16 a are formed at the inner peripheral side of the flow passages 17 a of the air swirler 17 , and the fuel nozzle 15 for startup is disposed at the center of the air swirler 17 in the radial direction.
  • the burner according to the second embodiment has the same structure as that shown in FIGS. 2 and 3 except for that the cooling holes 53 are omitted.
  • a rise of the metal temperature at the nozzle surface 18 can also be suppressed even with the burner having the structure that the cooling holes 53 are not formed and the fuel concentration in the area near the nozzle surface 18 cannot be enriched with the absence of the cooling holes 53 for introducing a part of the gas fuel.
  • FIG. 6 is a schematic view of a gas turbine plant equipped with the burner, shown in FIGS. 4 and 5 , according to the second embodiment of the present invention.
  • the gas turbine plant shown in FIG. 6 employs the gas fuel 201 made of a multi-component gas containing hydrogen and/or carbon monoxide, the liquid fuel 200 serving as the fuel for the startup of the gas turbine, the atomizing air 103 for atomizing the liquid fuel 200 , and the steam (inert gas) 104 for reducing NOx.
  • the shutoff valve 301 and the flow control valve 302 are disposed in the inert gas supply system, and the shutoff valve 300 is disposed in the bypass line connecting the atomizing air supply system and the inert gas supply system to each other.
  • the gas turbine plant according to the second embodiment has substantially the same construction as that shown in FIG. 1 except for that the cooling holes in the nozzle surface are omitted.
  • the gas turbine plant according to the second embodiment can reduce the concentration of exhausted NOx by injecting the steam 104 into the combustion chamber after the liquid fuel 200 is burned and a load is applied.
  • the fuel is changed over from the liquid fuel 200 to the gas fuel 201 with a subsequent increase of the load, and the supply of the atomizing air 103 is stopped after the shift to the gas combustion mode using only the mixed fuel.
  • the shutoff valve 300 is opened so that the steam 104 is injected from the center of the nozzle surface through the fuel nozzle 15 for startup.
  • the temperature of the flame formed near the nozzle surface lowers.
  • the metal temperature at the nozzle surface can be reduced and the reliability can be improved.
  • the burner according to the second embodiment can be easily constructed by employing a known general burner adapted for the diffusive combustion system.
  • FIG. 9 is a schematic view of a gas turbine plant equipped with a burner according to a third embodiment of the present invention, the plant including a system for purging liquid fuel residing in a nozzle for startup.
  • the liquid fuel 200 is used for the startup of the gas turbine, and the supply of the liquid fuel 200 is stopped after the operating mode is shifted to the gas combustion mode using only the mixed fuel in a certain load condition.
  • the liquid fuel 200 resides in the liquid fuel nozzle 20 , there occurs a phenomenon (coking) that the liquid fuel nozzle 20 is heated by heat from the flame and the residing liquid fuel 200 is solidified in the nozzle.
  • gas such as nitrogen is supplied to the liquid fuel nozzle 20 to purge the residing liquid fuel 200 into the combustion chamber, to thereby prevent the flow passage of the liquid fuel nozzle 20 being clogged by coking.
  • FIG. 9 shows, in enlarged scale, the burner including the fuel nozzle 15 for startup and the surroundings thereof.
  • the gas turbine plant according to this third embodiment includes a nitrogen-supply purge system for supplying nitrogen 400 to the startup fuel supply system, and a gas-fuel-supply purge system 201 a which is branched from the mixed fuel supply system and is used to supply a part of the gas fuel 201 to the startup fuel supply system.
  • a shutoff valve 401 is disposed in the nitrogen-supply purge system, and a shutoff valve 201 b is disposed in the gas-fuel-supply purge system 201 a , respectively.
  • the operations for changing over fuel and purging the fuel for startup are as follows.
  • the fuel changing-over operation is performed by increasing the mass flow of the gas fuel 201 while reducing the mass flow of the liquid fuel 200 supplied to the liquid fuel nozzle 20 of the combustor.
  • the fuel changing-over operation is completed. At that time, if the liquid fuel 200 is left residing in the liquid fuel nozzle 20 , coking occurs in the liquid fuel nozzle 20 by heat from the flame.
  • the shutoff valve 401 for the nitrogen 400 is released to supply the nitrogen 400 to the liquid fuel nozzle 20 , whereby the residing liquid fuel 200 can be purged into the combustion chamber and the occurrence of coking can be prevented.
  • This purge system is intended to purge the liquid fuel.
  • a similar advantage can be obtained when the residing liquid fuel is purged by supplying, to the liquid fuel nozzle 20 , the part 201 a of the gas fuel 201 which is branched from the mixed fuel supply system and introduced to the startup fuel supply system. Further, by so purging the liquid fuel 200 residing in the liquid fuel nozzle 20 into the combustion chamber and then continuously supplying the gas fuel to the combustion chamber even after completion of the purge, the fuel concentration near the swirler surface is enriched and the fuel rich region is formed. Accordingly, the flame temperature near the swirler surface lowers so that the metal temperature at the swirler surface can be reduced.
  • the cooling means in the above-described purge systems i.e., the means for continuously supplying the nitrogen 400 and the part 201 a of the gas fuel 201 through the liquid fuel nozzle 20 in the fuel nozzle 15 for startup during the gas combustion mode using only the mixed fuel (i.e., gas exclusive combustion), can be combined with the method for cooling the swirler surface in the first embodiment.
  • the swirler surface can be effectively cooled even in the case of burning the fuel containing hydrogen, carbon monoxide, etc.
  • the swirler surface 18 has the injection port 21 a through which the atomizing air is injected, the cooling holes 53 through which the gas fuel 201 is injected into the combustion chamber, and the flow passages 17 a of the air swirler 17 through which the compressed air is supplied to the combustion chamber.
  • the injection ports for injecting the gas fuel and the atomizing air respectively from the mixed fuel nozzle 16 and the atomizing air nozzle 21 to the combustion chamber correspond to the nozzle surface in which those injection ports are formed.
  • the first to third embodiments include means for reducing the flame temperature in the vicinity of the air swirler, i.e., near the respective surfaces of the fuel nozzle 15 for startup and the mixed fuel nozzle 16 which are positioned to face the combustion chamber.
  • the metal temperature at the swirler surface rises and exceeds the melting point of the material forming the air swirler.
  • the melting point of SUS steel is 650° C.
  • the air swirler 17 fails to develop the normal function due to burning-out of the swirler by the flame, or the burner can no longer maintain the flame due to clogging of the injection ports 16 a of the mixed fuel nozzle 16 , thus resulting in deterioration of reliability of the combustor.
  • the first to third embodiments are useful in modifying the existing burners.
  • LNG liquefied natural gas
  • gas oil gas oil
  • A-heavy oil change in the kind of used fuel can be adapted with a simple modification.
  • the first and second embodiments are useful in modifying the existing burners in the following point. Supposing, for example, the case where the existing burner includes the fuel nozzle 15 for startup and the mixed fuel nozzle 16 and uses the liquid fuel in the fuel nozzle 15 for startup, it is thought that the relevant burner includes the atomizing air supply system for atomizing the liquid fuel. Therefore, the metal temperature in the vicinity of the air swirler can be reduced by just modifying the relevant burner such that the inert gas can be supplied to the atomizing gas supply system upstream of the atomizing air nozzle 21 .
  • the metal temperature in the vicinity of the air swirler can be further reduced by replacing the nozzle surface (swirler surface) 18 of the burner 13 , which is positioned to face the combustion chamber, with the nozzle surface having the cooling holes 53 formed therein.
  • the replacement of the nozzle surface requires the burner to be disassembled from the combustor, it is easier to carry out a modification such that the inert gas is supplied to the atomizing gas supply system, without disassembling the burner from the combustor.
  • the third embodiment is also useful in modifying the existing burners. Namely, a similar advantage to that in the third embodiment can be obtained just by adding the purge system for supplying the nitrogen 400 to the startup fuel supply system in order to purge the liquid fuel 200 residing in the liquid fuel nozzle 20 .
  • the supply of nitrogen 400 requires auxiliary equipment, thus resulting in an increased plant size.
  • the mixed fuel supply system is branched to additionally provide the gas-fuel-supply purge system 201 a so that a part of the gas fuel 201 is supplied to the startup fuel supply system.
  • the delivery pressure of a gas compressor disposed in the existing mixed fuel supply system for supplying the mixed fuel to the burner can also be utilized to supply the part of the gas fuel 201 through the gas-fuel-supply purge system 201 a , whereby the plant equipment can be downsized.

Landscapes

  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Turbine Rotor Nozzle Sealing (AREA)
  • Gas Burners (AREA)
  • Nozzles For Spraying Of Liquid Fuel (AREA)
US11/473,062 2005-06-24 2006-06-23 Burner, gas turbine combustor, burner cooling method, and burner modifying method Abandoned US20070003897A1 (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
US13/627,565 US20130019584A1 (en) 2005-06-24 2012-09-26 Burner, gas turbine combustor, burner cooling method, and burner modifying method

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
JP2005184983 2005-06-24
JP2005-184983 2005-06-24
JP2006168987A JP4728176B2 (ja) 2005-06-24 2006-06-19 バーナ、ガスタービン燃焼器及びバーナの冷却方法
JP2006-168987 2006-06-19

Related Child Applications (1)

Application Number Title Priority Date Filing Date
US13/627,565 Division US20130019584A1 (en) 2005-06-24 2012-09-26 Burner, gas turbine combustor, burner cooling method, and burner modifying method

Publications (1)

Publication Number Publication Date
US20070003897A1 true US20070003897A1 (en) 2007-01-04

Family

ID=37027009

Family Applications (2)

Application Number Title Priority Date Filing Date
US11/473,062 Abandoned US20070003897A1 (en) 2005-06-24 2006-06-23 Burner, gas turbine combustor, burner cooling method, and burner modifying method
US13/627,565 Abandoned US20130019584A1 (en) 2005-06-24 2012-09-26 Burner, gas turbine combustor, burner cooling method, and burner modifying method

Family Applications After (1)

Application Number Title Priority Date Filing Date
US13/627,565 Abandoned US20130019584A1 (en) 2005-06-24 2012-09-26 Burner, gas turbine combustor, burner cooling method, and burner modifying method

Country Status (4)

Country Link
US (2) US20070003897A1 (fr)
EP (1) EP1736707B1 (fr)
JP (1) JP4728176B2 (fr)
HK (1) HK1138057A1 (fr)

Cited By (52)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20090145983A1 (en) * 2007-12-10 2009-06-11 Power Systems Mfg., Llc Gas turbine fuel nozzle having improved thermal capability
US20090249792A1 (en) * 2008-04-03 2009-10-08 Alstom Technology Ltd. Operation of a gas turbine
US20090272821A1 (en) * 2008-04-30 2009-11-05 Cliff Yi Guo Methods and systems for mixing reactor feed
US20100089021A1 (en) * 2008-10-14 2010-04-15 General Electric Company Method and apparatus of introducing diluent flow into a combustor
US20100089020A1 (en) * 2008-10-14 2010-04-15 General Electric Company Metering of diluent flow in combustor
CN101881453A (zh) * 2009-05-06 2010-11-10 通用电气公司 具有稀释剂开口的被鼓送空气的合成气燃料喷嘴
CN101881452A (zh) * 2009-05-06 2010-11-10 通用电气公司 具有稀释开口的吹气式合成气燃料喷嘴
US20100282185A1 (en) * 2008-01-17 2010-11-11 L'air Liquide Societe Anonyme Pour L'etude Et L'exploitation Des Procedes Georges Claude Burner and method for implementing an oxycombustion
US20100281869A1 (en) * 2009-05-06 2010-11-11 Mark Allan Hadley Airblown Syngas Fuel Nozzle With Diluent Openings
US20100323309A1 (en) * 2008-01-11 2010-12-23 David Barkowski Burner and Method for Reducing Self-Induced Flame Oscillations
US20110072823A1 (en) * 2009-09-30 2011-03-31 Daih-Yeou Chen Gas turbine engine fuel injector
US20110094239A1 (en) * 2009-09-30 2011-04-28 Hitachi, Ltd. Low NOx Combustor for Hydrogen-Containing Fuel and its Operation
US20110167783A1 (en) * 2008-10-01 2011-07-14 Mitsubishi Heavy Industries, Ltd. Gas turbine device
US20110265488A1 (en) * 2010-04-29 2011-11-03 General Electric Company ALTERNATE METHOD FOR DILUENT INJECTION FOR GAS TURBINE NOx EMISSIONS CONTROL
US20120047907A1 (en) * 2010-08-24 2012-03-01 Alstom Technology Ltd Method for operating a combustion chamber and combustion chamber
US20120260666A1 (en) * 2009-10-20 2012-10-18 Barve Vinayak V Multi-fuel combustion system
US20130031907A1 (en) * 2011-08-02 2013-02-07 Ulrich Woerz Fuel injecting assembly for gas turbine engine
US20130091852A1 (en) * 2011-10-12 2013-04-18 Alstom Technology Ltd Operating method for hydrogen/natural gas blends within a reheat gas turbine
EP2584261A1 (fr) * 2011-10-21 2013-04-24 General Electric Company Buses de diffusion pour ensemble d'injecteur de carburant à faible teneur en oxygène et procédé
US20130152594A1 (en) * 2011-12-15 2013-06-20 Solar Turbines Inc. Gas turbine and fuel injector for the same
US20130219900A1 (en) * 2012-02-28 2013-08-29 Hitachi, Ltd. Gas Turbine Combustor
US20130227953A1 (en) * 2012-03-01 2013-09-05 General Electric Company System and method for reducing combustion dynamics in a combustor
US20130327050A1 (en) * 2012-06-07 2013-12-12 General Electric Company Controlling flame stability of a gas turbine generator
US20140123669A1 (en) * 2012-11-02 2014-05-08 Exxonmobil Upstream Research Company System and method for diffusion combustion with oxidant-diluent mixing in a stoichiometric exhaust gas recirculation gas turbine system
US20140190177A1 (en) * 2011-07-26 2014-07-10 Siemens Aktiengesellschaft Method for running up a stationary gas turbine
US20140250908A1 (en) * 2010-07-02 2014-09-11 Exxonmobil Upsteam Research Company Systems and Methods for Controlling Combustion of a Fuel
US20150033749A1 (en) * 2013-07-30 2015-02-05 General Electric Company System and method of controlling combustion and emissions in gas turbine engine with exhaust gas recirculation
US20150082770A1 (en) * 2013-09-20 2015-03-26 Mitsubishi Hitachi Power Systems, Ltd. Dual-Fuel Burning Gas Turbine Combustor
US20150135716A1 (en) * 2012-11-21 2015-05-21 General Electric Company Anti-coking liquid cartridge
US9121609B2 (en) 2008-10-14 2015-09-01 General Electric Company Method and apparatus for introducing diluent flow into a combustor
US20150253010A1 (en) * 2013-11-18 2015-09-10 United Technologies Corporation Dual fuel nozzle with concentric fuel passages for a gas turbine engine
US20150285502A1 (en) * 2014-04-08 2015-10-08 General Electric Company Fuel nozzle shroud and method of manufacturing the shroud
US20160033135A1 (en) * 2014-08-01 2016-02-04 Capstone Turbine Corporation Fuel Injector For High Flame Speed Fuel Combustion
US20160061108A1 (en) * 2014-08-27 2016-03-03 Siemens Energy, Inc. Diffusion flame burner for a gas turbine engine
US20160195271A1 (en) * 2013-09-23 2016-07-07 Siemens Aktiengesellschaft Burner for a gas turbine and method for reducing thermoacoustic oscillations in a gas turbine
US20170219211A1 (en) * 2014-04-30 2017-08-03 Mitsubishi Hitachi Power Systems, Ltd. Gas turbine combustor, gas turbine, control device, and control method
US20170298817A1 (en) * 2014-10-10 2017-10-19 Kawasaki Jukogyo Kabushiki Kaisha Combustor and gas turbine engine
US20170350086A1 (en) * 2016-06-06 2017-12-07 Daniel Jensen Ground Thawing Device
US20180060210A1 (en) * 2016-08-26 2018-03-01 Accenture Global Solutions Limited Application development management
US20190128514A1 (en) * 2016-04-05 2019-05-02 Métal 7 Inc. Burner for Gas Heated Furnace and Method of Operation Thereof
US10309655B2 (en) * 2014-08-26 2019-06-04 Siemens Energy, Inc. Cooling system for fuel nozzles within combustor in a turbine engine
US10794296B2 (en) * 2016-10-24 2020-10-06 Mitsubishi Hitachi Power Systems, Ltd. Gas turbine combustor and method of operating the same
US11397006B2 (en) * 2016-04-01 2022-07-26 Kawasaki Jukogyo Kabushikt Kaisha Gas turbine combustor
CN114810358A (zh) * 2022-04-25 2022-07-29 中国船舶重工集团公司第七0三研究所 燃气轮机低排放双燃料系统及其控制方法
US20220268213A1 (en) * 2021-02-19 2022-08-25 Pratt & Whitney Canada Corp. Dual pressure fuel nozzles
CN114963169A (zh) * 2022-06-01 2022-08-30 江苏集萃复合材料装备研究所有限公司 一种甲醇高温裂解制氢高效燃烧系统及方法
CN115127121A (zh) * 2022-06-15 2022-09-30 北京航空航天大学 稳焰预混燃烧装置及航空发动机模拟试验设备
US20220356845A1 (en) * 2021-05-05 2022-11-10 Pratt & Whitney Canada Corp. Fuel nozzle with integrated metering and flashback system
CN115978589A (zh) * 2022-12-30 2023-04-18 南京航空航天大学 一种带有空气隔层的燃油喷嘴
FR3139378A1 (fr) * 2022-09-05 2024-03-08 Safran Dispositif et procede d’injection de melange hydrogene-air pour bruleur de turbomachine
US12038177B1 (en) * 2023-03-14 2024-07-16 Rtx Corporation Fuel injector assembly for gas turbine engine with fuel, air and steam injection
EP4411242A1 (fr) * 2023-02-02 2024-08-07 Pratt & Whitney Canada Corp. Chambre de combustion avec injection centrale de carburant et mélange d'air en aval

Families Citing this family (35)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JP4719704B2 (ja) * 2007-03-09 2011-07-06 株式会社日立製作所 ガスタービン燃焼器
JP4764392B2 (ja) * 2007-08-29 2011-08-31 三菱重工業株式会社 ガスタービン燃焼器
KR100872841B1 (ko) * 2007-09-28 2008-12-09 한국전력공사 디엠이 연료용 가스터빈 연소기의 연료노즐과 이의 설계방법
US8091805B2 (en) * 2007-11-21 2012-01-10 Woodward, Inc. Split-flow pre-filming fuel nozzle
JP4959524B2 (ja) 2007-11-29 2012-06-27 三菱重工業株式会社 燃焼バーナー
JP4997217B2 (ja) * 2008-12-05 2012-08-08 株式会社日立製作所 ガスタービンの運転方法及びガスタービン燃焼器
US8443607B2 (en) * 2009-02-20 2013-05-21 General Electric Company Coaxial fuel and air premixer for a gas turbine combustor
JP5896443B2 (ja) * 2009-06-05 2016-03-30 国立研究開発法人宇宙航空研究開発機構 燃料ノズル
US20120085834A1 (en) * 2010-10-07 2012-04-12 Abdul Rafey Khan Flame Tolerant Primary Nozzle Design
GB201115043D0 (en) 2011-09-01 2011-10-19 Rolls Royce Plc Steam injected gas turbine engine
US9261279B2 (en) * 2012-05-25 2016-02-16 General Electric Company Liquid cartridge with passively fueled premixed air blast circuit for gas operation
JP5889754B2 (ja) * 2012-09-05 2016-03-22 三菱日立パワーシステムズ株式会社 ガスタービン燃焼器
JP6474951B2 (ja) * 2013-04-10 2019-02-27 三菱日立パワーシステムズ株式会社 燃焼器
US9939156B2 (en) 2013-06-05 2018-04-10 Siemens Aktiengesellschaft Asymmetric baseplate cooling with alternating swirl main burners
US9234445B2 (en) * 2013-06-06 2016-01-12 Cummins Emission Solutions Inc. Systems and techniques for nozzle cooling of diesel exhaust fluid injection systems
JP2015034649A (ja) * 2013-08-07 2015-02-19 三菱日立パワーシステムズ株式会社 ガスタービン燃焼器
US20170234219A1 (en) * 2014-09-11 2017-08-17 Siemens Energy, Inc. Syngas burner system for a gas turbine engine
EP3209941B1 (fr) * 2014-10-20 2020-08-19 Ansaldo Energia S.p.A. Unité de turbine à gaz à alimentation en carburant à plusieurs fluides
CN104390235B (zh) * 2014-11-20 2017-06-27 中国船舶重工集团公司第七�三研究所 预混旋流式值班喷嘴
AU2015275260B2 (en) * 2015-12-22 2017-08-31 Toshiba Energy Systems & Solutions Corporation Gas turbine facility
US20180238548A1 (en) * 2017-02-22 2018-08-23 Delavan Inc Passive purge injectors
GB201808070D0 (en) 2018-05-18 2018-07-04 Rolls Royce Plc Burner
CN111237087B (zh) * 2020-01-19 2024-03-22 西北工业大学 一种航天动力用微孔板主被动复合冷却结构及冷却方法
CN113531584B (zh) 2020-04-15 2023-05-23 上海慕帆动力科技有限公司 燃气轮机的燃烧装置
EP3910236B1 (fr) 2020-05-15 2024-04-03 L'air Liquide, Société Anonyme Pour L'Étude Et L'exploitation Des Procédés Georges Claude Brûleur de processus et procédé de combustion des gaz de combustion contenant du monoxyde de carbone
KR102382634B1 (ko) * 2020-12-22 2022-04-01 두산중공업 주식회사 연소기용 노즐, 연소기 및 이를 포함하는 가스 터빈
CN116917667A (zh) 2021-02-25 2023-10-20 气体产品与化学公司 用于增强燃气轮机系统中的燃烧稳定性的氢气喷射
US11808457B2 (en) 2021-02-25 2023-11-07 Air Products And Chemicals, Inc. Hydrogen injection for enhanced combustion stability in gas turbine systems
CA3207755A1 (fr) * 2021-02-25 2022-09-01 Mark Daniel D'agostini Injection d'hydrogene pour stabilite de combustion amelioree dans des systemes de turbine a gaz
US20230036266A1 (en) * 2021-07-27 2023-02-02 Pratt & Whitney Canada Corp. Controlling gaseous fuel flow
US11815269B2 (en) 2021-12-29 2023-11-14 General Electric Company Fuel-air mixing assembly in a turbine engine
DE102022202935A1 (de) * 2022-03-24 2023-09-28 Rolls-Royce Deutschland Ltd & Co Kg Düsenbaugruppe mit drallfreier Luft- und Wasserstoffeinströmung
EP4343206A1 (fr) * 2022-09-23 2024-03-27 RTX Corporation Injecteur de carburant de moteur à turbine à gaz avec plusieurs circuits de carburant
JP2024067373A (ja) * 2022-11-04 2024-05-17 三菱重工業株式会社 ガスタービン燃焼器の制御装置、制御方法及び始動方法
JP7458541B1 (ja) 2023-08-04 2024-03-29 三菱重工業株式会社 ガスタービン制御装置、ガスタービン制御方法、及び、ガスタービン改造方法

Citations (19)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3057707A (en) * 1959-02-02 1962-10-09 Belge Produits Chimiques Sa Process for treatment of hydrocarbons
US3381896A (en) * 1965-09-24 1968-05-07 Ray Oil Burner Co System for purging nozzles in dual fuel burners
US3826080A (en) * 1973-03-15 1974-07-30 Westinghouse Electric Corp System for reducing nitrogen-oxygen compound in the exhaust of a gas turbine
US4582479A (en) * 1984-12-31 1986-04-15 The Cadre Corporation Fuel cooled oxy-fuel burner
US4890453A (en) * 1987-02-06 1990-01-02 Hitachi, Ltd. Method and apparatus for burning gaseous fuel, wherein fuel composition varies
US4977740A (en) * 1989-06-07 1990-12-18 United Technologies Corporation Dual fuel injector
US5228283A (en) * 1990-05-01 1993-07-20 General Electric Company Method of reducing nox emissions in a gas turbine engine
US5323614A (en) * 1992-01-13 1994-06-28 Hitachi, Ltd. Combustor for gas turbine
US5375995A (en) * 1993-02-12 1994-12-27 Abb Research Ltd. Burner for operating an internal combustion engine, a combustion chamber of a gas turbine group or firing installation
US5720164A (en) * 1990-11-27 1998-02-24 Rolls-Royce Plc Gas generators having dual fuel injector purge means
US5784875A (en) * 1995-11-27 1998-07-28 Innovative Control Systems, Inc. Water injection into a gas turbine using purge air
US20010004828A1 (en) * 1998-05-08 2001-06-28 Yukimasa Nakamoto Gas turbine fuel system comprising fuel oil distribution control system, fuel oil purge system, purging air supply system and fuel nozzle wash system
US20010004827A1 (en) * 1999-12-08 2001-06-28 General Electric Company Fuel system configuration for staging fuel for gas turbines utilizing both gaseous and liquid fuels
US6434945B1 (en) * 1998-12-24 2002-08-20 Mitsubishi Heavy Industries, Ltd. Dual fuel nozzle
US6463741B1 (en) * 1999-11-03 2002-10-15 Alstom (Switzerland) Ltd Method for operating a power plant
US6640548B2 (en) * 2001-09-26 2003-11-04 Siemens Westinghouse Power Corporation Apparatus and method for combusting low quality fuel
US20040035114A1 (en) * 2002-08-22 2004-02-26 Akinori Hayashi Gas turbine combustor, combustion method of the gas turbine combustor, and method of remodeling a gas turbine combustor
US7028478B2 (en) * 2003-12-16 2006-04-18 Advanced Combustion Energy Systems, Inc. Method and apparatus for the production of energy
US7296412B2 (en) * 2003-12-30 2007-11-20 General Electric Company Nitrogen purge for combustion turbine liquid fuel system

Family Cites Families (20)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3591907A (en) * 1966-10-04 1971-07-13 North American Rockwell Shrink fit fabrication method for fluid injectors
US3591086A (en) * 1968-05-31 1971-07-06 Marquardt Corp Nozzle for injection of slurry fuels
US3603092A (en) * 1969-09-24 1971-09-07 Nasa Injection head for delivering liquid fuel and oxidizers
JPS61140712A (ja) * 1984-12-11 1986-06-27 Toshiba Corp ガス燃料ノズル
US4903480A (en) * 1988-09-16 1990-02-27 General Electric Company Hypersonic scramjet engine fuel injector
US5161379A (en) * 1991-12-23 1992-11-10 United Technologies Corporation Combustor injector face plate cooling scheme
US5288021A (en) * 1992-08-03 1994-02-22 Solar Turbines Incorporated Injection nozzle tip cooling
JP3335713B2 (ja) * 1993-06-28 2002-10-21 株式会社東芝 ガスタービン燃焼器
JPH10238776A (ja) * 1997-02-28 1998-09-08 Central Res Inst Of Electric Power Ind ガスタービン燃焼器
JPH11210494A (ja) * 1998-01-26 1999-08-03 Toshiba Corp ガスタービン燃料供給装置のパージ装置およびパージ装置の運転方法
JP3742722B2 (ja) * 1998-03-16 2006-02-08 財団法人電力中央研究所 ガスタービン燃焼器
JP2000130757A (ja) * 1998-10-23 2000-05-12 Hitachi Ltd ガス化発電プラントのガスタービン燃焼器
JP3620776B2 (ja) * 1998-10-23 2005-02-16 財団法人電力中央研究所 ガス化発電プラント用ガスタービン燃焼器
JP2000345856A (ja) * 1999-06-07 2000-12-12 Hitachi Ltd ガス化発電プラントおよびその運転方法
JP4209058B2 (ja) * 1999-12-17 2009-01-14 三菱重工業株式会社 発電システム
US6363724B1 (en) * 2000-08-31 2002-04-02 General Electric Company Gas only nozzle fuel tip
JP3765560B2 (ja) * 2001-01-09 2006-04-12 財団法人電力中央研究所 ガスタービン燃焼器
GB2373043B (en) * 2001-03-09 2004-09-22 Alstom Power Nv Fuel injector
JP2003247425A (ja) * 2002-02-25 2003-09-05 Mitsubishi Heavy Ind Ltd 燃料ノズル、燃焼器およびガスタービン
JP2004003730A (ja) * 2002-05-31 2004-01-08 Hitachi Ltd ガスタービン燃焼器用燃料噴射ノズル

Patent Citations (19)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3057707A (en) * 1959-02-02 1962-10-09 Belge Produits Chimiques Sa Process for treatment of hydrocarbons
US3381896A (en) * 1965-09-24 1968-05-07 Ray Oil Burner Co System for purging nozzles in dual fuel burners
US3826080A (en) * 1973-03-15 1974-07-30 Westinghouse Electric Corp System for reducing nitrogen-oxygen compound in the exhaust of a gas turbine
US4582479A (en) * 1984-12-31 1986-04-15 The Cadre Corporation Fuel cooled oxy-fuel burner
US4890453A (en) * 1987-02-06 1990-01-02 Hitachi, Ltd. Method and apparatus for burning gaseous fuel, wherein fuel composition varies
US4977740A (en) * 1989-06-07 1990-12-18 United Technologies Corporation Dual fuel injector
US5228283A (en) * 1990-05-01 1993-07-20 General Electric Company Method of reducing nox emissions in a gas turbine engine
US5720164A (en) * 1990-11-27 1998-02-24 Rolls-Royce Plc Gas generators having dual fuel injector purge means
US5323614A (en) * 1992-01-13 1994-06-28 Hitachi, Ltd. Combustor for gas turbine
US5375995A (en) * 1993-02-12 1994-12-27 Abb Research Ltd. Burner for operating an internal combustion engine, a combustion chamber of a gas turbine group or firing installation
US5784875A (en) * 1995-11-27 1998-07-28 Innovative Control Systems, Inc. Water injection into a gas turbine using purge air
US20010004828A1 (en) * 1998-05-08 2001-06-28 Yukimasa Nakamoto Gas turbine fuel system comprising fuel oil distribution control system, fuel oil purge system, purging air supply system and fuel nozzle wash system
US6434945B1 (en) * 1998-12-24 2002-08-20 Mitsubishi Heavy Industries, Ltd. Dual fuel nozzle
US6463741B1 (en) * 1999-11-03 2002-10-15 Alstom (Switzerland) Ltd Method for operating a power plant
US20010004827A1 (en) * 1999-12-08 2001-06-28 General Electric Company Fuel system configuration for staging fuel for gas turbines utilizing both gaseous and liquid fuels
US6640548B2 (en) * 2001-09-26 2003-11-04 Siemens Westinghouse Power Corporation Apparatus and method for combusting low quality fuel
US20040035114A1 (en) * 2002-08-22 2004-02-26 Akinori Hayashi Gas turbine combustor, combustion method of the gas turbine combustor, and method of remodeling a gas turbine combustor
US7028478B2 (en) * 2003-12-16 2006-04-18 Advanced Combustion Energy Systems, Inc. Method and apparatus for the production of energy
US7296412B2 (en) * 2003-12-30 2007-11-20 General Electric Company Nitrogen purge for combustion turbine liquid fuel system

Cited By (82)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8136359B2 (en) * 2007-12-10 2012-03-20 Power Systems Mfg., Llc Gas turbine fuel nozzle having improved thermal capability
US20090145983A1 (en) * 2007-12-10 2009-06-11 Power Systems Mfg., Llc Gas turbine fuel nozzle having improved thermal capability
US20100323309A1 (en) * 2008-01-11 2010-12-23 David Barkowski Burner and Method for Reducing Self-Induced Flame Oscillations
US20100282185A1 (en) * 2008-01-17 2010-11-11 L'air Liquide Societe Anonyme Pour L'etude Et L'exploitation Des Procedes Georges Claude Burner and method for implementing an oxycombustion
US20090249792A1 (en) * 2008-04-03 2009-10-08 Alstom Technology Ltd. Operation of a gas turbine
US9170023B2 (en) * 2008-04-03 2015-10-27 Alstom Technology Ltd. Operation of a gas turbine
US8434700B2 (en) * 2008-04-30 2013-05-07 General Electric Company Methods and systems for mixing reactor feed
US20090272821A1 (en) * 2008-04-30 2009-11-05 Cliff Yi Guo Methods and systems for mixing reactor feed
US20110167783A1 (en) * 2008-10-01 2011-07-14 Mitsubishi Heavy Industries, Ltd. Gas turbine device
US9097188B2 (en) * 2008-10-01 2015-08-04 Mitsubishi Hitachi Power Systems, Ltd. Gas turbine device
US20100089021A1 (en) * 2008-10-14 2010-04-15 General Electric Company Method and apparatus of introducing diluent flow into a combustor
US9121609B2 (en) 2008-10-14 2015-09-01 General Electric Company Method and apparatus for introducing diluent flow into a combustor
US8567199B2 (en) * 2008-10-14 2013-10-29 General Electric Company Method and apparatus of introducing diluent flow into a combustor
US20100089020A1 (en) * 2008-10-14 2010-04-15 General Electric Company Metering of diluent flow in combustor
US20100281871A1 (en) * 2009-05-06 2010-11-11 Mark Allan Hadley Airblown Syngas Fuel Nozzle with Diluent Openings
CN101881452A (zh) * 2009-05-06 2010-11-10 通用电气公司 具有稀释开口的吹气式合成气燃料喷嘴
US8607570B2 (en) * 2009-05-06 2013-12-17 General Electric Company Airblown syngas fuel nozzle with diluent openings
CN101881453A (zh) * 2009-05-06 2010-11-10 通用电气公司 具有稀释剂开口的被鼓送空气的合成气燃料喷嘴
US20100281872A1 (en) * 2009-05-06 2010-11-11 Mark Allan Hadley Airblown Syngas Fuel Nozzle With Diluent Openings
US20100281869A1 (en) * 2009-05-06 2010-11-11 Mark Allan Hadley Airblown Syngas Fuel Nozzle With Diluent Openings
US20110072823A1 (en) * 2009-09-30 2011-03-31 Daih-Yeou Chen Gas turbine engine fuel injector
US20110094239A1 (en) * 2009-09-30 2011-04-28 Hitachi, Ltd. Low NOx Combustor for Hydrogen-Containing Fuel and its Operation
US8607572B2 (en) 2009-09-30 2013-12-17 Hitachi, Ltd. Low NOx combustor for hydrogen-containing fuel and its operation
US20120260666A1 (en) * 2009-10-20 2012-10-18 Barve Vinayak V Multi-fuel combustion system
US20110265488A1 (en) * 2010-04-29 2011-11-03 General Electric Company ALTERNATE METHOD FOR DILUENT INJECTION FOR GAS TURBINE NOx EMISSIONS CONTROL
US10570825B2 (en) * 2010-07-02 2020-02-25 Exxonmobil Upstream Research Company Systems and methods for controlling combustion of a fuel
US20140250908A1 (en) * 2010-07-02 2014-09-11 Exxonmobil Upsteam Research Company Systems and Methods for Controlling Combustion of a Fuel
US20120047907A1 (en) * 2010-08-24 2012-03-01 Alstom Technology Ltd Method for operating a combustion chamber and combustion chamber
US9464574B2 (en) * 2011-07-26 2016-10-11 Siemens Aktiengesellschaft Method for running up a stationary gas turbine
US20140190177A1 (en) * 2011-07-26 2014-07-10 Siemens Aktiengesellschaft Method for running up a stationary gas turbine
US20130031907A1 (en) * 2011-08-02 2013-02-07 Ulrich Woerz Fuel injecting assembly for gas turbine engine
US9133767B2 (en) * 2011-08-02 2015-09-15 Siemens Energy, Inc Fuel injecting assembly for gas turbine engine including cooling gap between supply structures
US20130091852A1 (en) * 2011-10-12 2013-04-18 Alstom Technology Ltd Operating method for hydrogen/natural gas blends within a reheat gas turbine
EP2584261A1 (fr) * 2011-10-21 2013-04-24 General Electric Company Buses de diffusion pour ensemble d'injecteur de carburant à faible teneur en oxygène et procédé
US20130098048A1 (en) * 2011-10-21 2013-04-25 General Electric Company Diffusion nozzles for low-oxygen fuel nozzle assembly and method
US8955329B2 (en) * 2011-10-21 2015-02-17 General Electric Company Diffusion nozzles for low-oxygen fuel nozzle assembly and method
US20130152594A1 (en) * 2011-12-15 2013-06-20 Solar Turbines Inc. Gas turbine and fuel injector for the same
US20130219900A1 (en) * 2012-02-28 2013-08-29 Hitachi, Ltd. Gas Turbine Combustor
US9121612B2 (en) * 2012-03-01 2015-09-01 General Electric Company System and method for reducing combustion dynamics in a combustor
US20130227953A1 (en) * 2012-03-01 2013-09-05 General Electric Company System and method for reducing combustion dynamics in a combustor
US20130327050A1 (en) * 2012-06-07 2013-12-12 General Electric Company Controlling flame stability of a gas turbine generator
US10100741B2 (en) * 2012-11-02 2018-10-16 General Electric Company System and method for diffusion combustion with oxidant-diluent mixing in a stoichiometric exhaust gas recirculation gas turbine system
US20140123669A1 (en) * 2012-11-02 2014-05-08 Exxonmobil Upstream Research Company System and method for diffusion combustion with oxidant-diluent mixing in a stoichiometric exhaust gas recirculation gas turbine system
US10161312B2 (en) * 2012-11-02 2018-12-25 General Electric Company System and method for diffusion combustion with fuel-diluent mixing in a stoichiometric exhaust gas recirculation gas turbine system
US20140123668A1 (en) * 2012-11-02 2014-05-08 Exxonmobil Upstream Research Company System and method for diffusion combustion with fuel-diluent mixing in a stoichiometric exhaust gas recirculation gas turbine system
US20150135716A1 (en) * 2012-11-21 2015-05-21 General Electric Company Anti-coking liquid cartridge
US10006636B2 (en) * 2012-11-21 2018-06-26 General Electric Company Anti-coking liquid fuel injector assembly for a combustor
US9903588B2 (en) * 2013-07-30 2018-02-27 General Electric Company System and method for barrier in passage of combustor of gas turbine engine with exhaust gas recirculation
US20150033749A1 (en) * 2013-07-30 2015-02-05 General Electric Company System and method of controlling combustion and emissions in gas turbine engine with exhaust gas recirculation
US20150082770A1 (en) * 2013-09-20 2015-03-26 Mitsubishi Hitachi Power Systems, Ltd. Dual-Fuel Burning Gas Turbine Combustor
US10094567B2 (en) * 2013-09-20 2018-10-09 Mitsubishi Hitachi Power Systems, Ltd. Dual-fuel injector with a double pipe sleeve gaseus fuel flow path
US20160195271A1 (en) * 2013-09-23 2016-07-07 Siemens Aktiengesellschaft Burner for a gas turbine and method for reducing thermoacoustic oscillations in a gas turbine
US20150253010A1 (en) * 2013-11-18 2015-09-10 United Technologies Corporation Dual fuel nozzle with concentric fuel passages for a gas turbine engine
US10731861B2 (en) * 2013-11-18 2020-08-04 Raytheon Technologies Corporation Dual fuel nozzle with concentric fuel passages for a gas turbine engine
US20150285502A1 (en) * 2014-04-08 2015-10-08 General Electric Company Fuel nozzle shroud and method of manufacturing the shroud
US20170219211A1 (en) * 2014-04-30 2017-08-03 Mitsubishi Hitachi Power Systems, Ltd. Gas turbine combustor, gas turbine, control device, and control method
US10718522B2 (en) * 2014-04-30 2020-07-21 Mitsubishi Hitachi Power Systems, Ltd. Gas turbine combustor, gas turbine, control device, and control method
US20160033135A1 (en) * 2014-08-01 2016-02-04 Capstone Turbine Corporation Fuel Injector For High Flame Speed Fuel Combustion
US10184664B2 (en) * 2014-08-01 2019-01-22 Capstone Turbine Corporation Fuel injector for high flame speed fuel combustion
US10309655B2 (en) * 2014-08-26 2019-06-04 Siemens Energy, Inc. Cooling system for fuel nozzles within combustor in a turbine engine
US20160061108A1 (en) * 2014-08-27 2016-03-03 Siemens Energy, Inc. Diffusion flame burner for a gas turbine engine
US20170298817A1 (en) * 2014-10-10 2017-10-19 Kawasaki Jukogyo Kabushiki Kaisha Combustor and gas turbine engine
US11397006B2 (en) * 2016-04-01 2022-07-26 Kawasaki Jukogyo Kabushikt Kaisha Gas turbine combustor
US10718512B2 (en) * 2016-04-05 2020-07-21 Metal 7 Inc. Burner for gas heated furnace and method of operation thereof
US20190128514A1 (en) * 2016-04-05 2019-05-02 Métal 7 Inc. Burner for Gas Heated Furnace and Method of Operation Thereof
US20170350086A1 (en) * 2016-06-06 2017-12-07 Daniel Jensen Ground Thawing Device
US10633816B2 (en) * 2016-06-06 2020-04-28 Daniel Jensen Ground thawing device
US20180060210A1 (en) * 2016-08-26 2018-03-01 Accenture Global Solutions Limited Application development management
US10794296B2 (en) * 2016-10-24 2020-10-06 Mitsubishi Hitachi Power Systems, Ltd. Gas turbine combustor and method of operating the same
US12007116B2 (en) * 2021-02-19 2024-06-11 Pratt & Whitney Canada Corp. Dual pressure fuel nozzles
US20220268213A1 (en) * 2021-02-19 2022-08-25 Pratt & Whitney Canada Corp. Dual pressure fuel nozzles
US20220356845A1 (en) * 2021-05-05 2022-11-10 Pratt & Whitney Canada Corp. Fuel nozzle with integrated metering and flashback system
US11525403B2 (en) * 2021-05-05 2022-12-13 Pratt & Whitney Canada Corp. Fuel nozzle with integrated metering and flashback system
CN114810358A (zh) * 2022-04-25 2022-07-29 中国船舶重工集团公司第七0三研究所 燃气轮机低排放双燃料系统及其控制方法
CN114963169A (zh) * 2022-06-01 2022-08-30 江苏集萃复合材料装备研究所有限公司 一种甲醇高温裂解制氢高效燃烧系统及方法
CN115127121A (zh) * 2022-06-15 2022-09-30 北京航空航天大学 稳焰预混燃烧装置及航空发动机模拟试验设备
FR3139378A1 (fr) * 2022-09-05 2024-03-08 Safran Dispositif et procede d’injection de melange hydrogene-air pour bruleur de turbomachine
WO2024052611A1 (fr) * 2022-09-05 2024-03-14 Safran Dispositif et procede d'injection de melange hydrogene-air pour bruleur de turbomachine
CN115978589A (zh) * 2022-12-30 2023-04-18 南京航空航天大学 一种带有空气隔层的燃油喷嘴
EP4411242A1 (fr) * 2023-02-02 2024-08-07 Pratt & Whitney Canada Corp. Chambre de combustion avec injection centrale de carburant et mélange d'air en aval
US12111056B2 (en) 2023-02-02 2024-10-08 Pratt & Whitney Canada Corp. Combustor with central fuel injection and downstream air mixing
US12038177B1 (en) * 2023-03-14 2024-07-16 Rtx Corporation Fuel injector assembly for gas turbine engine with fuel, air and steam injection

Also Published As

Publication number Publication date
EP1736707B1 (fr) 2018-01-24
EP1736707A3 (fr) 2014-03-19
JP4728176B2 (ja) 2011-07-20
JP2007033022A (ja) 2007-02-08
EP1736707A2 (fr) 2006-12-27
HK1138057A1 (en) 2010-08-13
US20130019584A1 (en) 2013-01-24

Similar Documents

Publication Publication Date Title
EP1736707B1 (fr) Brûleur, chambre de combustion d'une turbine à gaz, procédé de refroidissement d'un brûleur, et procédé de modification d'un brûleur
JP5889754B2 (ja) ガスタービン燃焼器
JP5438727B2 (ja) 燃焼器、バーナ及びガスタービン
EP1503142B1 (fr) Méthode de fonctionnement d'une centrale combinée avec une installation de gazéification de charbon
EP2846022B1 (fr) Système de combustion de turbine à gaz
JP5075900B2 (ja) 水素含有燃料対応燃焼器および、その低ＮＯｘ運転方法
CN101614395B (zh) 喷烧器及喷烧器的冷却方法
US9739488B2 (en) Gas turbine combustor with two kinds of gas fuel supply systems
JP4997217B2 (ja) ガスタービンの運転方法及びガスタービン燃焼器
US20120208137A1 (en) System and method for operating a combustor
JP2014202465A (ja) 燃焼器
JP6148133B2 (ja) ガスタービン燃焼器及びガスタービンシステム
US11946422B2 (en) Method of operating a combustor for a gas turbine
WO2018173122A1 (fr) Chambre de combustion de turbine à gaz
EP2487419A2 (fr) Système et procédé de fonctionnement d'une chambre de combustion
JP2015034649A (ja) ガスタービン燃焼器
JP2015102266A (ja) ガスタービン燃焼器
WO2024043268A1 (fr) Turbine à gaz et installation de turbine à gaz

Legal Events

Date Code Title Description
AS Assignment

Owner name: HITACHI, LTD., JAPAN

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:KOIZUMI, HIROMI;INOUE, HIROSHI;SASAO, TOSHIFUMI;AND OTHERS;REEL/FRAME:018265/0063;SIGNING DATES FROM 20060622 TO 20060626

STCB Information on status: application discontinuation

Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION