US3785146A - Self compensating flow divider for a gas turbine steam injection system - Google Patents

Self compensating flow divider for a gas turbine steam injection system Download PDF

Info

Publication number
US3785146A
US3785146A US00249393A US3785146DA US3785146A US 3785146 A US3785146 A US 3785146A US 00249393 A US00249393 A US 00249393A US 3785146D A US3785146D A US 3785146DA US 3785146 A US3785146 A US 3785146A
Authority
US
United States
Prior art keywords
steam
nozzle
flow
conduit means
combustion
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.)
Expired - Lifetime
Application number
US00249393A
Other languages
English (en)
Inventor
G Bailey
C Wilhelm
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 Co
Original Assignee
General Electric Co
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 Co filed Critical General Electric Co
Application granted granted Critical
Publication of US3785146A publication Critical patent/US3785146A/en
Anticipated expiration legal-status Critical
Expired - Lifetime legal-status Critical Current

Links

Images

Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
    • F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
    • F02C3/00—Gas-turbine plants characterised by the use of combustion products as the working fluid
    • F02C3/20—Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products
    • F02C3/30—Adding water, steam or other fluids for influencing combustion, e.g. to obtain cleaner exhaust gases
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
    • F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
    • F02C3/00—Gas-turbine plants characterised by the use of combustion products as the working fluid
    • F02C3/20—Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products
    • F02C3/30—Adding water, steam or other fluids for influencing combustion, e.g. to obtain cleaner exhaust gases
    • F02C3/305—Increasing the power, speed, torque or efficiency of a gas turbine or the thrust of a turbojet engine by injecting or adding water, steam or other fluids

Definitions

  • This invention relates generally to steam injection systems for gas turbines, and more particularly to a selfcompensating flow divider for supplying steam to two different points in the gas turbine cycle.
  • one object of the present invention is to provide an improved steam injection system for a gas turbine which adds varying amounts of total steam for the purpose of both NO, abatement and power augmentation, but which limits the steam added for the former so as not to degrade the combustion process.
  • Another object of the invention in its more general sense, is to provide an improved self-compensating flow divider which limits the amount of How added upstream of a combustion process, but which permits variation of the flow added downstream of the process to a substantialdegree.
  • Another object of the invention is to provide a steam injection system for a gas turbine which adds a limited constant percentage of steam flow rate to air flow rate for NO, abatement and which adds a variable percentage of flow rate of steam for power augmentation.
  • the invention comprises adding primary and secondary proportioned flows of injected steam to the gas turbine motive fluid.
  • the secondary flow is subdivided into two portions by splitting the injected steam into two parts, one of which bypasses the combustion process. The greater the total rate of flow of injected steam, the greater the portion which bypasses the process.
  • FIG. I is a simplified schematic view, partly in section, of a gas turbine combustion chamber
  • FIG. 2a, 2b, and 2c are simplified schematic views of a steam injection nozzle under low, medium and high rate of flow conditions respectively
  • FIG. 3 is a simplified diagram representing the mode of operation of the invention
  • FIG. 4 is a graph showing a typical steam injection schedule for a gas turbine.
  • Combustion chamber 1 is of the type where the compressed air from the compressor (not shown) is directed in a reverse flow.
  • the reverse flow of such a combustion chamber is well known in the art and provides the advantage of heating the compressed air before its use in the combustion processes.
  • Combustion chamber 1 is comprised of a generally cylindrical outer casing 2 to which is attached the easing 3. Casing 3 in turn connects with the turbine section (not shown).
  • the outer casing end cover 4 closes off the end of outer casing 2 opposite the casing 3 such that the volume within outer casing 2 is sealed from the atmosphere.
  • An annular air space 8 surrounds the liners 5 and 7 in order to accommodate the flow of the compressed air.
  • the liner end cap 9 which accommodates the fuel nozzle generally indicated as 10.
  • the liner end cap 9 is generally in the shape of a truncated cone, the top of which is for the accommodation therein of the fuel nozzle assembly 10.
  • the air swirler assembly is attached to the cap 9 but may also be attached to the fuel nozzle.
  • the fuel nozzle assembly 10 may be any convenient type known to the art which can be accommodated in the head end of the liner 5 and particularly in the end cap 9.
  • Fuel nozzle 10 is of the variety which is capable of atomizing hydrocarbon fuels.
  • the fuel nozzle 10 may be of the air atomizing type or pressure atomizing type or alternatively may be a nozzle adapted to inject gaseous fuel.
  • a first row 12 is comprised of 8 holes circumferentially spacedaboufthediher 5.
  • the thermal soaking region of the liner 5 Following the row of holes 14 downstream (in rela- I tion to the flow of combustion products) in an axial direction, is the thermal soaking" region of the liner 5. This is indicated as 15 on FIG. 1.
  • the thermal soaking" region 15 is closed in that there are no large circumferentially spaced holes along this axial length of liner; however, louvers or slits for metal cooling air are positioned throughout the length of liner 5, but are not shown for clarity. The louvers are utilized for cooling the liner 5 and the air which enters the louvers does not contribute to the combustion process to an important degree.
  • tempering air holes 16 Positioned at the end of the thermal soaking region are a plurality of circumferentially spaced tempering air holes 16.
  • the actual size and number of tempering air holes 16 will depend upon the amount of tempering air to be added to the combustion products as they leave the soaking region 15.
  • the tempering region of the liner 5 is indicated on FIG. 1 as 18 and extends generally from the tempering air holes 16 to the first stage nozzle.
  • the purpose of the tempering air holes 16 is to allow a portion of the compressed air which is relatively cool as compared to the hot combustion products to temper the combustion products before the overall air-combustion product mixture enters the first stage nozzle.
  • Tempering holes 16 are large enough to allow sufficient penetration of the cooler tempering air into the combustion products so that the desired first stage turbine inlet temperature is achieved.
  • a pipe 19 connected to a source of steam is led into the combustor casing 2 and branches to supply a first fixed nozzle 20 and a second fixed nozzle 21.
  • Nozzle 20 is arranged to empty a primary flow of steam into the annular space 8 containing compressor discharge air and also upstream of the combustion reaction zone 6.
  • Nozzles 20 in an actual turbine may be arranged to provide some cooling of the hot transition member 7.
  • a secondary nozzle 21 is positioned radially outward froma tempering airhole 16 and substantially coaxial therewith. Similar secondary nozzles 21 are positioned around the periphery of the liner, one for each of the tempering airholes 16.
  • Secondary nozzle 21 performs a flow dividing function in conjunction with holes 16 in the spaced liner 5.
  • Reference to FIGS. 2a, 2b, and 2c shows the flow dividing operation under low, medium and high steam flow rates respectively.
  • FIG. 2a steam at a low flow rate is deflected completely into the annular air space 8 by the incoming air so that none flows through hole 16.
  • FIG. 2b a moderate rate of steam flow is divided into two parts by the edge of hole 16, one part continuing in the annular air space 8 toward the combustion reaction zone and the other part entering the interior of liner 5, downstream of the reaction zone.
  • the high flow rate of steam causes almost all of the steam to flow through hole 16 into the liner 5, bypassing annular space 8.
  • FIG. 3 showing a simplified version of the system.
  • the combustion reaction Zone is represented by a block 6 while the primary nozzle is symbolized at 20' and the secondary nozzle at 21 Flow dividing hole is symbolized at 16'.
  • a primary flow of fluid A leaves primary nozzle 20 and flows toward combustion process 6' at a rate of flow proportional to that entering the inlet 19'.
  • a secondary flow from nozzle 21 is divided by hole 16' into a flow B entering the combustion process and a flow C which bypasses the combustion process and enters the flow downstream of the combustion process to rejoin it.
  • the nozzles 20', 21' or the passages supplying them are proportioned so that they pass fivesixteenths and eleven-sixteenths respectively of the total flow entering at 19.
  • the graph of FIG. 4 illustrates the result of this proportioning.
  • the horizontal axis measures total steam flow as a percent of air (motive fluid) flow. At any given rate of air flow, therefore, the horizontal axis also represents the total rate of steam flow.
  • Flow A from nozzle 20 increases approximately linearly as a percent of total air flow, as the steam flow is increased into inlet 19.
  • Flow B also increases approximately linearly at low flow rates (See FIG. 2a) but in greater quantity as determined by the relative flow passages of nozzles 20, 21.
  • flow B commences to decrease and flow C is initiated into a region downstream of combustion process 6'.
  • the spacing of the secondary nozzle 21, the sizing of hole 16' and the relative flows to nozzles 20', 21' are selected so that flow B decreases at the same rate (as measured against the total percent of steam added) that flow A increases. Closer spacing of the secondary nozzle 21' from hole 16, or proportionately reducing the sizes of nozzles 20' and 21' while maintaining the same ratio with respect to one another (thereby increasing the exit velocity of steam from nozzle 21' relative to velocity of motive fluid) will cause flow B to decrease at a greater rate.
  • said first conduit means is an elongated casing surrounding a combustion liner
  • said second conduit means is said liner
  • said primary nozzle is a fixed steam nozzle emptying into said casing
  • said secondary nozzle is a fixed steam nozzle emptying toward a hole in said liner

Landscapes

  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
US00249393A 1972-05-01 1972-05-01 Self compensating flow divider for a gas turbine steam injection system Expired - Lifetime US3785146A (en)

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
US24939372A 1972-05-01 1972-05-01

Publications (1)

Publication Number Publication Date
US3785146A true US3785146A (en) 1974-01-15

Family

ID=22943286

Family Applications (1)

Application Number Title Priority Date Filing Date
US00249393A Expired - Lifetime US3785146A (en) 1972-05-01 1972-05-01 Self compensating flow divider for a gas turbine steam injection system

Country Status (5)

Country Link
US (1) US3785146A (enrdf_load_stackoverflow)
JP (1) JPS4941714A (enrdf_load_stackoverflow)
DE (1) DE2321379A1 (enrdf_load_stackoverflow)
FR (1) FR2183023A1 (enrdf_load_stackoverflow)
GB (1) GB1383627A (enrdf_load_stackoverflow)

Cited By (19)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4398604A (en) * 1981-04-13 1983-08-16 Carmel Energy, Inc. Method and apparatus for producing a high pressure thermal vapor stream
US5054279A (en) * 1987-11-30 1991-10-08 General Electric Company Water spray ejector system for steam injected engine
US5239816A (en) * 1992-03-16 1993-08-31 General Electric Company Steam deflector assembly for a steam injected gas turbine engine
US5241816A (en) * 1991-12-09 1993-09-07 Praxair Technology, Inc. Gas turbine steam addition
US5536143A (en) * 1995-03-31 1996-07-16 General Electric Co. Closed circuit steam cooled bucket
WO2000011323A1 (en) * 1998-08-21 2000-03-02 Alliedsignal Inc. Apparatus for water injection in a gas turbine combustor
US6389793B1 (en) 2000-04-19 2002-05-21 General Electric Company Combustion turbine cooling media supply system and related method
US6405521B1 (en) 2001-05-23 2002-06-18 General Electric Company Gas turbine power augmentation injection system and related method
US6446440B1 (en) 2000-09-15 2002-09-10 General Electric Company Steam injection and inlet fogging in a gas turbine power cycle and related method
US6553768B1 (en) 2000-11-01 2003-04-29 General Electric Company Combined water-wash and wet-compression system for a gas turbine compressor and related method
EP1309786A4 (en) * 2000-08-11 2004-05-19 Cheng Power Systems Inc DESIGNED A STEAM INJECTOR FOR GAS TURBINE COMBUSTION CHAMBER FAIRINGS TO EXTEND PERFORMANCE AND EFFICIENCY
US20100101204A1 (en) * 2008-10-29 2010-04-29 General Electric Company Diluent shroud for combustor
US20130276450A1 (en) * 2012-04-24 2013-10-24 General Electric Company Combustor apparatus for stoichiometric combustion
US9410409B1 (en) * 2009-08-11 2016-08-09 EOR Technology LLC Thermal vapor stream apparatus and method
EP3054213A1 (en) * 2015-02-06 2016-08-10 Mitsubishi Hitachi Power Systems, Ltd. Gas turbine combustor and steam injected gas turbine
US20160369751A1 (en) * 2015-06-22 2016-12-22 Chun-Ting Chen Internal combustion engine using water as auxiliary power
US11459948B2 (en) * 2020-02-26 2022-10-04 Mitsubishi Heavy Industries, Ltd. Gas turbine plant
US12092023B1 (en) * 2023-03-14 2024-09-17 Rtx Corporation Steam cooling turbine engine combustor wall
US20250251129A1 (en) * 2024-02-01 2025-08-07 General Electric Company Gas turbine engine having a steam generating system providing steam to a combustor

Families Citing this family (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CA1083835A (en) * 1976-07-14 1980-08-19 International Power Technology, Inc. Regenerative parallel compound dual-fluid heat engine
JPS54129216A (en) * 1978-03-30 1979-10-06 Motonosuke Tsutsui Apparatus for purification* sounddproofing and fuel saving for jet aircraft
DE3012172A1 (de) * 1980-03-28 1981-10-08 Kraftwerk Union AG, 4330 Mülheim Gasturbine mit durch dampfeinspritzung verringerter stickoxydemissio
JPS5959672U (ja) * 1982-10-13 1984-04-18 三菱重工業株式会社 ガスタ−ビン燃焼器
GB2187273B (en) * 1985-10-31 1990-01-24 Bernard George Ediss A gas turbine binary cycle
JPS63167067U (enrdf_load_stackoverflow) * 1987-04-15 1988-10-31
JPH01114623A (ja) * 1987-10-27 1989-05-08 Toshiba Corp ガスタービン燃焼器
GB2219070B (en) * 1988-05-27 1992-03-25 Rolls Royce Plc Fuel injector
JPH02133553U (enrdf_load_stackoverflow) * 1989-04-03 1990-11-06
JPH0425967U (enrdf_load_stackoverflow) * 1990-06-14 1992-03-02
WO2009021729A2 (de) * 2007-08-13 2009-02-19 Harald Winkler Wärmekraftmaschine

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2636345A (en) * 1947-03-21 1953-04-28 Babcock & Wilcox Co Gas turbine combustor having helically directed openings to admit steam and secondary air
GB756264A (en) * 1953-07-31 1956-09-05 Gen Motors Corp Improvements in thrust augmenting devices for aircraft gas turbine engines
US3088280A (en) * 1959-04-17 1963-05-07 Rolls Royce Reducing smoke in gas turbine engine exhaust
US3238719A (en) * 1963-03-19 1966-03-08 Eric W Harslem Liquid cooled gas turbine engine
US3359723A (en) * 1965-10-29 1967-12-26 Exxon Research Engineering Co Method of combusting a residual fuel utilizing a two-stage air injection technique and an intermediate steam injection step

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2636345A (en) * 1947-03-21 1953-04-28 Babcock & Wilcox Co Gas turbine combustor having helically directed openings to admit steam and secondary air
GB756264A (en) * 1953-07-31 1956-09-05 Gen Motors Corp Improvements in thrust augmenting devices for aircraft gas turbine engines
US3088280A (en) * 1959-04-17 1963-05-07 Rolls Royce Reducing smoke in gas turbine engine exhaust
US3238719A (en) * 1963-03-19 1966-03-08 Eric W Harslem Liquid cooled gas turbine engine
US3359723A (en) * 1965-10-29 1967-12-26 Exxon Research Engineering Co Method of combusting a residual fuel utilizing a two-stage air injection technique and an intermediate steam injection step

Cited By (28)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4398604A (en) * 1981-04-13 1983-08-16 Carmel Energy, Inc. Method and apparatus for producing a high pressure thermal vapor stream
US5054279A (en) * 1987-11-30 1991-10-08 General Electric Company Water spray ejector system for steam injected engine
US5241816A (en) * 1991-12-09 1993-09-07 Praxair Technology, Inc. Gas turbine steam addition
US5239816A (en) * 1992-03-16 1993-08-31 General Electric Company Steam deflector assembly for a steam injected gas turbine engine
US5536143A (en) * 1995-03-31 1996-07-16 General Electric Co. Closed circuit steam cooled bucket
US6112511A (en) * 1997-08-29 2000-09-05 Alliedsignal, Inc. Method and apparatus for water injection via primary jets
WO2000011323A1 (en) * 1998-08-21 2000-03-02 Alliedsignal Inc. Apparatus for water injection in a gas turbine combustor
US6389793B1 (en) 2000-04-19 2002-05-21 General Electric Company Combustion turbine cooling media supply system and related method
US6481212B2 (en) 2000-04-19 2002-11-19 General Electric Company Combustion turbine cooling media supply system and related method
US6584779B2 (en) 2000-04-19 2003-07-01 General Electric Company Combustion turbine cooling media supply method
EP1309786A4 (en) * 2000-08-11 2004-05-19 Cheng Power Systems Inc DESIGNED A STEAM INJECTOR FOR GAS TURBINE COMBUSTION CHAMBER FAIRINGS TO EXTEND PERFORMANCE AND EFFICIENCY
US6446440B1 (en) 2000-09-15 2002-09-10 General Electric Company Steam injection and inlet fogging in a gas turbine power cycle and related method
US6553768B1 (en) 2000-11-01 2003-04-29 General Electric Company Combined water-wash and wet-compression system for a gas turbine compressor and related method
US6405521B1 (en) 2001-05-23 2002-06-18 General Electric Company Gas turbine power augmentation injection system and related method
US20100101204A1 (en) * 2008-10-29 2010-04-29 General Electric Company Diluent shroud for combustor
US8454350B2 (en) 2008-10-29 2013-06-04 General Electric Company Diluent shroud for combustor
US9410409B1 (en) * 2009-08-11 2016-08-09 EOR Technology LLC Thermal vapor stream apparatus and method
US20130276450A1 (en) * 2012-04-24 2013-10-24 General Electric Company Combustor apparatus for stoichiometric combustion
CN105864824B (zh) * 2015-02-06 2018-08-24 三菱日立电力系统株式会社 燃气轮机燃烧器及蒸汽注入燃气轮机
CN105864824A (zh) * 2015-02-06 2016-08-17 三菱日立电力系统株式会社 燃气轮机燃烧器及蒸汽注入燃气轮机
EP3054213A1 (en) * 2015-02-06 2016-08-10 Mitsubishi Hitachi Power Systems, Ltd. Gas turbine combustor and steam injected gas turbine
US10088160B2 (en) 2015-02-06 2018-10-02 Mitsubishi Hitachi Power Systems, Ltd. Gas turbine combustor and steam injected gas turbine
US20160369751A1 (en) * 2015-06-22 2016-12-22 Chun-Ting Chen Internal combustion engine using water as auxiliary power
US11459948B2 (en) * 2020-02-26 2022-10-04 Mitsubishi Heavy Industries, Ltd. Gas turbine plant
US12092023B1 (en) * 2023-03-14 2024-09-17 Rtx Corporation Steam cooling turbine engine combustor wall
EP4431807A2 (en) * 2023-03-14 2024-09-18 RTX Corporation Steam cooling turbine engine combustor wall
US20240309811A1 (en) * 2023-03-14 2024-09-19 Raytheon Technologies Corporation Steam cooling turbine engine combustor wall
US20250251129A1 (en) * 2024-02-01 2025-08-07 General Electric Company Gas turbine engine having a steam generating system providing steam to a combustor

Also Published As

Publication number Publication date
DE2321379A1 (de) 1973-11-22
GB1383627A (en) 1974-02-12
JPS4941714A (enrdf_load_stackoverflow) 1974-04-19
FR2183023A1 (enrdf_load_stackoverflow) 1973-12-14

Similar Documents

Publication Publication Date Title
US3785146A (en) Self compensating flow divider for a gas turbine steam injection system
US3747336A (en) Steam injection system for a gas turbine
US3169367A (en) Combustion apparatus
US5680767A (en) Regenerative combustor cooling in a gas turbine engine
US3602605A (en) Cooling system for a gas turbine
US6666018B2 (en) Combined cycle pulse detonation turbine engine
US2676460A (en) Burner construction of the can-an-nular type having means for distributing airflow to each can
US2405723A (en) Propulsion apparatus
US3866417A (en) Gas turbine engine augmenter liner coolant flow control system
US5272870A (en) Cooling arrangement for jet engines
US3938326A (en) Catalytic combustor having a variable temperature profile
US3998047A (en) Method and apparatus for preventing overspeed in a gas turbine
US11255544B2 (en) Rotating detonation combustion and heat exchanger system
US3600890A (en) Turbine cooling construction
US20190128525A1 (en) Combustor and gas turbine including the same
US2977760A (en) Annular combustion chambers for use with compressors capable of discharging combustion supporting medium with a rotary swirl through an annular outlet
US3237401A (en) Regenerative expander engine
US2704440A (en) Gas turbine plant
US3740949A (en) Fuel cooled ram air reaction propulsion engine
US4265590A (en) Cooling air supply arrangement for a gas turbine engine
US2702454A (en) Transition piece providing a connection between the combustion chambers and the turbine nozzle in gas turbine power plants
GB1069217A (en) Improvements relating to engines
US9021783B2 (en) Pulse detonation engine having a scroll ejector attenuator
Paxson et al. Ejector enhanced pulsejet based pressure gain combustors: an old idea with a new twist
US11555471B2 (en) Thrust chamber device and method for operating a thrust chamber device