©Siemens Power Generation 2003. All Rights Reserved Design of a Gas turbine combustion system Torsten Strand torsten.st
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©Siemens Power Generation 2003. All Rights Reserved
Design of a Gas turbine combustion system Torsten Strand [email protected]
2/9/2006
Power Generation
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Content
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z The design requirements, criteria and targets z The overall design process z The gas turbine cycle: Excel calculations z Burner and cooling mass flows: Design calculations z Burner type: lean premixed, diffusion flame or something in between z Combustor heat balance, choice of combustor design: Excel calculations z The component designs z burners z combustor : Excel calculations z fuel system : Excel calculations z Ignition and supervision systems z Operation z Start up z Part load 2/9/2006
Power Generation
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Assumptions
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z We are going to design a new gas turbine with the shaft power of 35MW for a market consisting of z 60% compressor drivers for pipe line compressors z 40% industrial cogeneration z The first customer segment want a very reliable and robust simple cycle unit for pumping of gas from desolated gas fields in z Siberia ( 0 to -50°C) z Iranian mountains (-20 to +45°C, low ambient pressure) z Saudi Arabian deserts (+10 to +50°C) z Efficiency and emissions are not of prime interest z Fuel is natural gas z The second customer type want an efficient, but still very reliable gas turbine with low emissions and suitable for steam production in waste heat recovery boilers for industries, mainly in the western world. Fuel is natural gas or industrial off gases. 2/9/2006
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Case 1 Gas Turbine in Simple Cycle 63.6 % losses Gas Turbine
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36.4 % electricity
100 % fuel Pgt Pst Paux Pnet Heat duty Qfired
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44.30 0 0.10 44.20 0 121.4
MW MW MW MW MJ/s MJ/s
Alfa ∞ --Net electrical Powerefficiency Generation 36.4 % Net total efficiency 36.4 %
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Case 2 Gas Turbine in Cogeneration Cycle 12 % losses
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1-pressure HRSG
52.2 % process heat
Gas Turbine 35.9 % electricity
100 % fuel
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Pgt Pst Paux Pnet Heat duty Qfired Alfa NetPower electrical efficiency Generation Net total efficiency
43.82 0 0.23 43.59 63.4 121.4
MW MW MW MW MJ/s MJ/s
0.69 --35.9 % 5 88.1 %
Case 3 Gas Turbine in Combined Cycle Steam Turbine (condensing) 12 % losses 520 deg C
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2-pressure HRSG 31 deg C
Gas Turbine
100 % fuel
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Alfa Net electrical efficiency Net total efficiency
31 deg C 15 deg C
27 deg C 35 % losses
35.9 % electricity Pgt Pst Paux Pnet Heat duty Qfired
16.8 % electricity
43.69 20.78 0.70 63.77 0 120.9
MW MW MW MW MJ/s MJ/s
∞ --52.7 % 52.7 %
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Case 4 Gas Turbine in Combined Cycle Steam Turbine (district heating)
11 % losses
11.3 % electricity
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510 deg C 2-pressure HRSG
78 deg C
42.1 % heat
90 deg C
Gas Turbine
60 deg C 35.9 % electricity 100 % fuel
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78 deg C
Pgt Pst Paux Pnet Heat duty Qfired
43.70 14.18 0.62 57.26 51.1 121.4
MW MW MW MW MJ/s MJ/s
Alfa 1.12 --Powerefficiency Generation 47.2 % Net electrical Net total efficiency 89.3 %
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Is it possible to use the same design for both applications? z Well, we will try!
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z The compressor drive requires a variable speed power turbine, so we have to assume a twin shaft unit z The efficiency of the cogeneration unit ought to be in the range of 37% at full load, which means that the heat input is around 95MW
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The core engine 1
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z We have now a basic design. z A critical parameter is the Turbine Inlet Temperature. The higher TIT the better gas turbine cycle, but generally also less robustness and higher turbine cooling flow z Let us assume a conservative TIT = 1300°C z From experience the turbine cooling flow will then be around 16% 95MWth TIT
35MWe
Turbine cooling 2/9/2006
Power Generation
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Turbine Inlet Temperature and emissions
Turbine Inlet Temperature C and NOX
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1500
200
Ceramics Steam Cooling
Single Crystal Blades
GTX100 Jet Engines 1000
GT200 GT10B/C GT35/GT120
100
Stationary Gas Turbines 500
1940
1960
1980
2000
Year 2/9/2006
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The gas turbine cycle T Tflame
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p5, t5m
p3, t3
t5
ηct = (t5m - t6)/(t5m - t6s)
p6, t6
ηpt = (t6m - t7)/(t6m - t7s) ηc = (t3s - t2)/(t3 - t2)
p7, t7
p2, t2
s 2/9/2006
Power Generation
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The turbine pressure levels
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z How are the pressure levels at the compressor and power turbine sat? z The turbine can be seen as a tube with restrictors z In order to pass a certain flow at a certain temperature there is an associated flow area/pressure combination z The flow area is determined by the turbine inlet guide vanes zInner/outer diameter zExit blade angle, which is on gas turbines is generally fairly large, which means that the stage design is of reaction type (the enthalpy drop is divided between vane and blade)
m = A *rot(2*Δp*ρ) = A *rot(2*Δp*p/RT) = Ψ*A*p/rot(RT) For computational purposes the below formula is very useful
m*rot(T)/p = constant 2/9/2006
Power Generation
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Turbine flow The flow capacity of the turbine is determined by the smallest area in the turbine inlet guide vane and the root and tip section diameters the turbine “wideness” the turbine flow number m*rotT/p ©Siemens Power Generation 2003. All Rights Reserved
the ”turbine constant”
The flow capacity of the turbine determines the position of the operating line in the compressor map.
2/9/2006
An uncooled turbine has better efficiency than a cooled turbine, which has less good profiles (lower aspect ratio, thick trailing edges) and Power Generation 13 mixing losses from the cooling flows
The gas turbine cycle T Tflame p5, t5m
t5
ηct = (t5m - t6)/(t5m - t6s)
p6, t6
p3, t3
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ηpt = (t6m - t7)/(t6m - t7s) ηc = (t3s - t2)/(t3 - t2)
p7, t7
p2, t2
s
The next step is to make a simple thermodynamic model of the gas turbine in order to get the conditions for the combustor. We will do it in Excel!
95Mth TIT
35MWe
Turbine cooling Power Generation
2/9/2006
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Power Generation
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SGT-600, Industrial gas turbine
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Gas turbine principle & components
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Power Generation
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The core engine 2 z Now we need to choose the pressure level for the turbine inlet z There is an optimal pressure level for efficiency associated with the turbine inlet temperature, but it is generally quite high which means a low TET. We have also to consider the steam production in the waste heat recovery boiler, so we need a fairly high TET > 520°C ?? z We will try some pressures for TIT = 1300°C z1800 kPa z1700 kPa z1600 kPa z1500 kPa
η=38.3% η=38.0% η=37.6% η=37.1%
TET=509°C TET=517°C TET=526°C TET=536°C
T3=438°C T3=426°C T3=413°C T3=400°C
z The higher the pressure the higher also the compressor exit air temperature T3. That air is zthe combustion air zthe cooling air for the turbine and combustor walls
z For combustion high air temperature is generally better z NOx and combustion pulsations have a tendency to increase with pressure Power Generation
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The combustor 1
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z Now we have basic full load data for the combustor z Air flow to the combustor: 82.8/426/1785 kg/s/°C/kPa z Fuel flow: 2.02 kg/s z Combustor exit flow: 84.8/1300/1700 kg/s/°C/kPa z In order to design the combustor we have to know which type of burner we are going to use 2.02 kg/s 82.8 kg/s 426°C 1785kPa
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84.8 kg/s 1300°C 1700kPa
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Burner 1: types of burners z The conventional combustors were designed for Stoichiometric combustion, using fuel injectors with low air flows Φ ≅1. Water or steam injection were used for NOx reduction z The lean premixed combustors are designed with a high air flow that cools the flame
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z The low oxygen combustors relay on a combustion process in O2-depleted gas, achieved by recirculation of combustion products NOx ppmv
Diffusion flames
200
Φ = 1/λ
Water Injection 100
Lean Premix Combustion
0. 5
Steam Injection
1.0
1.5
Fuel/Air Equivalence Ratio 2/9/2006
Power Generation
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Diffusion type dual fuel Injector
Water inlet
2100K
STD PARTPOSITIONABLE ELBOW
HCV GAS HOLES
PURGE HOLES
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STEAM INLET
Air
Gas inlet Oil inlet
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Dual fuel Injector for gas and oil with water and steam injection
Power Generation
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NOx and CO vs Flame Temperature NOx ppm
CO ppm
EV Burner DLE Gas
AEV Burner DLE Gas & Oil
50 ©Siemens Power Generation 2003. All Rights Reserved
NOx 40
40 30
30
CO
Low oxygen burner20
20
Catalytic burner
10
10 1700
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1800 Flame Temp K
1900
- Advanced DLE burners Power - Generation
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Our case
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z The Oil&Gas customers have presently no high requirements on emissions, but the industrial customers will have a requirement of NOx < 10 ppm z We will try to build a low NOx burner of lean premix type z Our trial choice is a LP burner with a design flame temperature of 1750K z How much air is needed for the combustion? z We will do a heat balance calculation for the flame zone
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Power Generation
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The combustor 2
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z Now we have the basic flow data for the combustor z Air flow to the burner: 65/426/1785 kg/s/°C/kPa z Fuel flow: 2.02 kg/s z Wall cooling flow: 17/426/1785 kg/s/°C/kPa
2.02 kg/s 84 kg/s 65 kg/s
1300°C 1700kPa
17 kg/s 426°C 2/9/2006
1785kPa
Power Generation
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Wall cooling z The burner air is around 65 kg/s out of the 82 kg/s combustion air z We have around 21% of the combustion air for wall cooling, which ought to be enough for a film cooled sheet metal combustor. 438 ©Siemens Power Generation 2003. All Rights Reserved
450
500
850
1477÷1300
If the film cooling air is on the low side Thermal Barrier Coating can be used. If there is more air than necessary for cooling, it can be injected as dilution air in the down stream part of the combustor. 2/9/2006
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Wall cooling designs The shown wall design is the traditional one for film cooled combustors. Several similar designs with improved performance are in use 438
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450
Impingement
1477÷1300
500
850
Convection
The use of Thermal barrier coatings has been more common. Conventionally only thin TBC (