Upload
others
View
6
Download
0
Embed Size (px)
Citation preview
Combined Cycle Power Plants 3. Combustor 1 / 110
HIoPE
Combined Cycle Power Plants
3. Combustor
Combined Cycle Power Plants 3. Combustor 2 / 110
HIoPE
Combined Cycle Power Plants
Fuel and Combustion Theory 2 1
Factors Affecting Combustor Design 20 2
Combustor Type 27 3
NOx Formation and Its Control 44 4
Diffusion Combustor 59 5
Dry Low NOx Combustor 65 6
Catalytic Combustor 87 7
Combustor Cooling 104 8
Combined Cycle Power Plants 3. Combustor 3 / 110
HIoPE
Combined Cycle Power Plants
The function of the combustor is to add heat energy to the flowing gases, thereby expanding
and accelerating the gases into the turbine section.
From the viewpoint of thermodynamics, if the fuel heat is added at constant pressure, the
volume of the gas is increased and, with flow area remaining the same, this causes an
acceleration of gas to occur.
Air Inlet Compressor Combustors Turbine Exhaust
Cold Section Hot Section
Combustor
Combined Cycle Power Plants 3. Combustor 4 / 110
HIoPE
Combined Cycle Power Plants
The fuel is combined with high pressure air and burned in a combustor.
The combustion chamber has the difficult task of burning large quantities of fuel, supplied through fuel spray
nozzles, with extensive volumes of air, and releasing the resulting heat in such a manner that the air is
expanded and accelerated to give a smooth stream of uniformly heated gas.
This task must be accomplished with the minimum loss in pressure and with the maximum heat release
within the limited space available.
The resulting expanded and accelerated high temperature exhaust gas is used to turn the power turbine.
Initially, mixing of fuel and air is occurred under condition that the resulting flame is self-sustaining.
The mixing should be done as uniform as possible for minimum emission and flame stabilization.
The liner is perforated to enhance mixing of the fuel and air.
The details of mixing and burning the fuel are quite complex and require extensive testing to develop a new
burner.
Because the TIT cannot be directly measured, reading are taken of the turbine pressure ratio and exhaust
gas temperature, from which the TIT is calculated.
Generals for Combustor [1/2]
Combined Cycle Power Plants 3. Combustor 5 / 110
HIoPE
Combined Cycle Power Plants
The amount of fuel added to the air will depend upon the temperature rise required. For example, if the
required TIT is 1500°C that is determined by the materials for turbine blades and nozzles, and the air has
already been heated to 500°C by the work done in the compressor, temperature rise of 1000°C is given from
the combustion process.
Since the gas temperature determines the engine power, the combustion chamber must be capable of
maintaining stable and efficient combustion over a wide range of engine operating conditions.
The temperature of the gas after combustion is about 1800 to 2000°C, which is far too hot for entry to the
nozzle guide vanes of the turbine.
The air not used for combustion, which amounts to about 60 percent of the total airflow, is therefore
introduced progressively into the flame tube.
Approximately one third of this gas is used to lower the temperature inside the combustor; the remainder is
used for cooling the walls of the flame tube.
There are three types of combustors, the can-type, the annular, and the silo combustor.
The central shaft that connects the turbine and compressor passes through the center hole.
Burners are made from materials that can withstand the high temperatures of combustion.
Generals for Combustor [2/2]
Combined Cycle Power Plants 3. Combustor 6 / 110
HIoPE
연소의 정의
• 연료 중의 가연성분(C,H,S)이 공기 중의 산소와 결합하여 산화되는 발열반응
• 연소반응의 세 가지 요소: 가연성 연료, 산소, 점화원(불씨)
완전연소
• 산소가 충분한 상태에서 가연분이 완전히 산화되는 반응
C + O2 = CO2 + 33.9 MJ/kg
H2 + 1/2O2 = H2O(water) + 143 MJ/kg HHV(Higher Heating Value)
H2 + 1/2O2 = H2O(vapor) + 120.6 MJ/kg LHV(Lower Heating Value)
S + O2 = SO2 + 9.28 MJ/kg
• 탄소는 연소하면서 일차적으로 CO가 된 후에 이차적으로 CO2 가 됨. 따라서 탄소는 수소에 비해
연소에 더 많은 시간이 소요됨
불완전연소
• 산소가 불충분한 상태에서 가연분이 불완전하게 산화되는 반응
C + O = CO + 10.3 MJ/kg
[CO + 1/2O2 = CO2 + 10.1 MJ/kg (CO는 다시 산소와 반응하여 완전연소될 수 있음)]
Combustion [1/6]
Combined Cycle Power Plants 3. Combustor 7 / 110
HIoPE
Combined Cycle Power Plants
Combustion [2/6]
Combustion, in its most basic sense, is the process whereby the hydrogen and carbon in fuels are
combined with oxygen from the air to release heat.
In general, common fuels may be classified as hydrocarbons. This means that they are predominantly
composed of carbon and hydrogen.
The source of oxygen is called the oxidizer. The oxidizer, likewise, could be a solid, liquid, or gas, but is
usually a gas (air) for gas turbines.
During combustion, new chemical substances are created from the fuel and the oxidizer. These
substances are called exhaust.
Most of the exhaust comes from chemical combinations of the fuel and oxygen.
When a hydrogen-carbon-based fuel (like gasoline) burns, the exhaust includes water (hydrogen +
oxygen) and carbon dioxide (carbon + oxygen).
But the exhaust could also include chemical combinations from the oxidizer alone.
If the gasoline were burned in air, which contains 21% oxygen and 78% nitrogen, the exhaust could also
include nitrous oxides (NOx, nitrogen + oxygen).
Combined Cycle Power Plants 3. Combustor 8 / 110
HIoPE
During the combustion process, as the fuel and oxidizer are turned into exhaust products, heat is
generated. Therefore, the temperature of the exhaust is high and the exhaust usually occurs as a gas.
Interestingly, some source of heat is also necessary to start combustion. (Gasoline and air are both
present in the fuel tank; but combustion does not occur because there is no source of heat.)
Since heat is both required to start combustion and is itself a product of combustion, we can see why
combustion takes place very rapidly.
Also, once combustion gets started, we don't have to provide a heat source because the heat of
combustion will keep things going. (Example: We don't have to keep lighting a campfire.)
To summarize, for combustion to occur three things must be present: a fuel to be burned, a source of
oxygen, and a source of heat.
In addition, sufficient temperature, sufficient residence time, and sufficient mixing are required for complete
combustion.
Combustion [3/6]
Combined Cycle Power Plants 3. Combustor 9 / 110
HIoPE
Combined Cycle Power Plants
Gas Chemical
symbol
Ratio compared to dry air (%) Molecular
mass
(kg/kmol)
Boiling
point
(C) By volume By weight Weight Ratio
Oxygen O2 20.95 23.20 1 32.00 -182.95
Nitrogen N2 78.09 75.47 3.312 28.02 -195.79
Carbon dioxide CO2 0.03 0.046 44.01 -78.5
Hydrogen H2 0.00005 ~0 2.02 -252.87
Argon Ar 0.933 1.28 39.94 -186
Neon Ne 0.0018 0.0012 20.18 -246
Helium He 0.0005 0.00007 4.00 -269
Krypton Kr 0.0001 0.0003 83.8 -153.4
Xenon Xe 9x10-6 0.00004 131.29 -108.1
Table: Composition of air
공기 조성
Combustion [4/6]
Combined Cycle Power Plants 3. Combustor 10 / 110
HIoPE
Combined Cycle Power Plants
탄화수소계 연료에 대한 연소 기초식
CnHm + (n +m/4)O2 = nCO2 + (m/2)H2O
위 식은 연료 1분자와 산소 (n +m/4) 분자가 반응하면 연료와 산소 모두 연소에 과부족이 생기지 않는 것을 나타낸다. 공연비는 질량비이므로 원자량을 탄소 12, 수소 1, 산소 16으로 하면, 연료와 산소의 질량은
연료: 12n + 1m
산소: 32(n +m/4)
그런데 공기조성에서 산소 질량이 1.0일 때 질소 질량이 3.312이므로
Air 4.31232(n +m/4)
Fuel 12n + 1m
1) 메탄 (CH4)의 공연비 = 17.25 : 1
2) 옥탄(C8H18)의 공연비 = 15.13 : 1
3) 경유 (C17H36)의 공연비 = 14.95 : 1
Fuel-Air Ratio
Combustion [5/6]
Combined Cycle Power Plants 3. Combustor 11 / 110
HIoPE
Combined Cycle Power Plants
Species Formula Adiabatic Flame Temp. (K)
Methane CH4 2223
Propane C3H8 2261
Carbon Monoxide CO 2381
Hydrogen H2 2370
Another important combustion parameter is the flame temperature.
Flame temperatures are determined by a balance of energy between reactants and products.
In principal, the highest flame temperatures would be produced at = 1, because all of the fuel and oxygen
would be consumed.
Fuel type is important in determining the flame temperature.
The methane flame temperature is approximately 150 K lower than hydrogen and CO. This distinction
makes it somewhat easier to produce low-emissions from natural gas, which is mostly methane, compared
to syngases containing undiluted H2 and CO.
Flame Temperature
Combustion [6/6]
Combined Cycle Power Plants 3. Combustor 12 / 110
HIoPE
Combined Cycle Power Plants
비점: 1기압 하에서 액화되는 온도
탄소계 분류 제품 비점(C) 밀도(kg/l) 발열량
MJ/kg (kcal/kg)
C2 이하 천연가스 메탄(CH4)
에탄(C2H6)
-162
-89
0.3
0.37
52 (12425)
48 (11470)
C3~C4 LPG 프로판(C3H8)
부탄(C4H10)
-42
-0.5
0.51
0.58
48
48
C5~C11 나프타 가솔린 35~180 0.6~0.74 44 (10513)
C9~C15 등유 등유 150~250 0.74~0.82 43 (10275)
C12~C22 경유 경유 190~350 0.82~0.88 42 (10036)
C22~ 잔유
A중유
B중유
C중유
윤활유
아스팔트
190~600 0.89 이상 42
원유의 분류와 제품
Petroleum Fuel
Combined Cycle Power Plants 3. Combustor 13 / 110
HIoPE
Combined Cycle Power Plants
Natural gas is an ideal fuel for gas turbines because it is free from solid residue and has little inherent sulfur
content resulting in low emission of SO2. The sulfur contained in natural gas can be easily removed.
Methane (CH4) and ethane (C2H6) are the principal combustible constituents of natural gas.
Natural gas may contain significant quantities of N2 and CO2.
The lower heating value (LHV) of natural gas is about 1000 Btu/ft3, but can range from 300 to 1,500 Btu/ft3
depending on composition.
It is common for gas turbine manufacturers to specify maximum allowable concentrations of H2S, SO2, and
SO3 in natural gas fuel to ensure that they have taken proper precautions to prevent high temperature
corrosion of turbine blade materials.
The distance sometimes associated with natural gas transmission and pipeline conditions can result in
changes in composition from wellhead and end user. Thus, the as-fired natural gas analysis should be based
on point of use rather than at the wellhead.
Corrosive alkali metals, such as sodium and potassium, are also absent, making natural gas an ideal fuel for
high temperature gas turbines.
Natural Gas [1/3]
Combined Cycle Power Plants 3. Combustor 14 / 110
HIoPE
Combined Cycle Power Plants
Analysis A B C D E
Constituents,
% by vol.
H2 Hydrogen
CH4 Methane
C2H4 Ethylene
C2H6 Ethane
CO Carbon monoxide
CO2 Carbon dioxide
N2 Nitrogen
O2 Oxygen
H2S Hydrogen sulfide
--
83.40
--
15.80
--
--
0.80
--
--
--
84.00
--
14.80
--
0.70
0.50
--
--
1.82
93.33
0.25
--
0.45
0.22
3.40
0.35
0.18
--
90.00
--
5.00
--
--
5.00
--
--
--
84.10
--
6.70
--
0.80
8.40
--
--
Ultimate,
% by wt.
S Sulfur
H2 Hydrogen
C Carbon
N2 Nitrogen
O2 Oxygen
--
23.53
75.25
1.22
--
--
23.30
74.72
0.76
1.22
0.34
23.20
69.12
5.76
1.58
--
22.68
69.26
8.06
--
--
20.85
64.84
12.90
1.41
Specific gravity (relative to air) 0.636 0.636 0.567 0.600 0.630
HHV, Btu/ft3 @ 60F & 30 in.Hg
Btu/lb of fuel
1,129
23,170
1,116
22,904
964
22,070
1,002
21,824
974
20,160
Source: Steam / Its generation and use, Babcock & Wilcox
The average heat content of natural gas is 1,030 Btu/ft3 on an HHV basis and 930 Btu/ft3 on an LHV basis
– about a 10% difference.
Natural Gas [2/3]
Combined Cycle Power Plants 3. Combustor 15 / 110
HIoPE
Combined Cycle Power Plants
The Wobbe index (or Wobbe number) is a key parameter for heat capacity of a gaseous fuel because it is
an indicator for the interchangeability of gases.
Wb = Wobbe index, LHV = LHV of the fuel, Sp.Gr. = specific gravity of the fuel, Tamb = ambient temperature
of the fuel in degrees absolute.
Gases with same Wobbe index or within a range of 2 to 5% for premix combustors (15% for diffusion
burners) can be used in the same combustor.
The natural gases have Wobbe index of 1220 10%.
In the gas turbine combustor, increasing the Wobbe index can cause the flame to burn closer to liner, and
decreasing the Wobbe index can cause pulsations in the combustor.
The Wobbe index of a gaseous fuel can be adjusted by diluting it with inert or lean gas (e.g., steam,
nitrogen) or improved by adding rich gases (e.g., evaporated LNG).
Propane, butane, and LPG are usually liquid, however, these will be vaporized to use in gas turbines.
amb
bTGrSp
LHVW
..
Wobbe Index
Natural Gas [3/3]
Combined Cycle Power Plants 3. Combustor 16 / 110
HIoPE
Combined Cycle Power Plants
Natural gas is the preferred fuel for industrial engines those can use various fuels.
If natural gas is not available, a liquid distillate can be used.
A relatively small number of gas turbines use residual fuels, required pre-treatment which is costly.
Units for base load operation use natural gas, but peak load applications use liquid fuels requiring the
storage of substantial quantities.
Liquid fuels are used in gas turbines are distillates and ash-bearing fuels. (Ash-bearing fuels, by definition,
include any distillate, unrefined crude oil or residual oil containing sufficient quantities of ash to cause
deposit and corrosion problems.)
Light distillates generally do not require preheating because they have sufficiently low pour points under
most ambient conditions. However, heavy distillates are required preheating to prevent filter plugging
because they have high pour points because of the high wax content.
ASTM specifies five grades of liquid fuel for different classes of machines and types of service.
• Grade 0-GT includes naphtha and other light hydrocarbon liquids that have low flash points and low
viscosities as compared to kerosene.
• Grade 1-GT is a light distillate fuel oil suitable for use in nearly all gas turbines.
• Grade 2-GT is a heavier distillate than Grade 1-GT and can be used in gas turbines not requiring the clean
burning characteristics of Grade 1-GT.
• Grade 3-GT may be a heavier distillate than Grade 2-GT, a residual fuel oil that meets the low ash
requirements, or a blend of distillate and residual oils that meets the low ash requirements.
• Grade 4-GT includes most residuals. Because of potentially wide ranging properties, the gas turbine
manufacturer should be consulted on acceptable limits on properties.
Liquid Fuel [1/4]
Combined Cycle Power Plants 3. Combustor 17 / 110
HIoPE
Combined Cycle Power Plants
Generally, fuel preheating is required for Grade 3-GT and Grade 4-GT. In some cases, however Grade 2-GT
is also required fuel preheating.
Maximum allowable limits are normally set by gas turbine manufacturers for trace metal contaminants such
as sodium, potassium, vanadium, and lead because of their corrosive effects in the hot gas path parts of the
gas turbine.
Vanadium pentoxide (V2O5) an extremely corrosive compound, and sodium vanadate (formed if sodium and
vanadium are present in the fuel) are semi-molten and corrosive at metal temperatures typical of gas turbine
operation.
Typically, the corrosive effects of vanadium are inhibited by adding one of variety of magnesium compounds
to the fuel. The magnesium reacts with vanadium pentoxide and forms magnesium orthovanadate having
melting point higher than gas turbine firing temperature.
If excess magnesium compound is added to the fuel, ash deposits on the turbine blades will increase.
Consequently, some manufacturers recommend that the weight ratio of magnesium to vanadium not exceed
3.5 to minimize ash deposits on hot gas path parts.
Sodium and potassium levels can be reduced to levels in the fuel by providing a system for washing the oil
with water.
Liquid Fuel [2/4]
Combined Cycle Power Plants 3. Combustor 18 / 110
HIoPE
Combined Cycle Power Plants
A major key to fuel flexibility is the tolerance of the machine to trace metal contaminants.
The five trace metals of most concern are vanadium, sodium, potassium, lead, and calcium. The first four
can cause the corrosion of turbine blade, while all five can cause fouling.
In general, sodium and vanadium are the two most frequently found in petroleum fuels.
The crude oil has been treated by washing to lower the sodium concentration to less than 1 ppm, using a
two-stage electrostatic desalter, and by inhibiting the 3 ppm of vanadium with an oil-soluble magnesium
additive.
Plant output and efficiency can be reduced when the ash bearing fuels (crude oil, residual oil, blends, or
heavy distillate) are used because of fouling occurred in gas turbine and HRSG.
Heavy fuels normally cannot be ignited for gas turbine startup; therefore a startup and shutdown fuel, usually
light distillate, is needed with its own storage, forwarding system, and fuel changeover equipment.
Liquid Fuel [3/4]
Combined Cycle Power Plants 3. Combustor 19 / 110
HIoPE
Combined Cycle Power Plants
Plant output and efficiency can be reduced when the fuels containing higher sulfur content are used. This is
because higher stack gas temperature is required to prevent condensation of corrosive sulfuric acid.
Sodium sulfates that result during combustion are semi-molten and corrosive at turbine blade metal
temperatures normally associated with gas turbine operation.
The sulfur contained in the fuels reacts with ammonia and produce ammonium bisulfate (NH4HSO4) and
ammonium sulfate ((NH4)2SO4) when the SCR module is employed to reduce NOx emission level.
Both ammonium compounds cause fouling and plugging of the HRSG and increase of PM-10 (particulate
matter smaller in diameter than 10 microns) emissions.
Ammonium bisulfate causes rapid corrosion of HRSG tubes, but ammonium sulfate is not corrosive.
The increase of particulate emissions due to the ammonium salts can be as high as a factor of five due to
conversion of SO2 to SO3.
Some of the SO2 formed from the fuel sulfur is converted to SO3 and it is the SO3 that reacts with water and
ammonia to form ammonium slats, ammonium bisulfate and ammonium sulfate.
The increase is a function of the amount of sulfur in the fuel, the ammonia slip (ammonia that does not react
with NOx, see GER-4249 for details), and the temperature.
Sulfur-Bearing Fuels
Liquid Fuel [4/4]
Combined Cycle Power Plants 3. Combustor 20 / 110
HIoPE
Combined Cycle Power Plants
Fuel and Combustion Theory 1
Factors Affecting Combustor Design 2
Combustor Type 3
NOx Formation and Its Control 4
Diffusion Combustor 5
Dry Low NOx Combustor 6
Catalytic Combustor 7
Combustor Cooling 8
Combined Cycle Power Plants 3. Combustor 21 / 110
HIoPE
Combined Cycle Power Plants
1) High combustion efficiency at all operating conditions.
2) Minimized pollutants and emissions: Low levels of unburned hydrocarbons and carbon monoxide, low
oxides of nitrogen at high power.
3) Low pressure drop. (3~4% is common)
4) Combustion must be stable under all operating conditions , including ignition, start-up, and full power.
• The flame should stable in a high velocity stream where sustained combustion is difficult.
• The flame must be self-sustaining and combustion must be stable over a wide range of fuel-air ratio to
avoid ignition loss during transient operation.
• Details for flame stability is quite complex because of various types of combustors.
5) Smooth combustion, with no pulsations or rough burning.
6) A low temperature variation for good turbine life requirements.
• Moderate metal temperatures are necessary to assure long life of the combustor.
• In addition, steep temperature gradients, which distort and crack the combustor liner, must be avoided.
7) Length and diameter compatible with engine envelope (outside dimensions).
8) Designed for minimum cost, repair and maintenance.
9) Carbon deposits must not be formed under any operating conditions.
• Carbon deposits can distort the liner and alter the flow patterns to cause pressure losses.
• Smoke is objectionable as well as a fouler of heat exchangers.
Design Requirement for Combustors
Combined Cycle Power Plants 3. Combustor 22 / 110
HIoPE
Combined Cycle Power Plants
The size of combustion chamber is determined by the combustion intensity, which is affected by the heat
release rate required, the volume of combustion chamber, and combustion pressure.
The nominal heat release rate = mass flow fuel/air ratio heating value of the fuel.
The lower the combustion intensity, the easier the design of combustor which will meet all design
requirements required.
As the combustor volume increases, it has a lower pressure drop, higher combustion efficiency, better outlet
temperature distribution, and more satisfactory stability characteristics.
When the liquid fuel is used, the evaporation of droplets increases with pressure. Moreover, chemical
reactions are affected by combustion chamber pressure significantly.
The combustion intensity in aviation systems is 2 - 5x104 kW/m3-atm, while industrial gas turbines have
much lower value for this, may be a tenth of this, because they have larger volume of combustion space
available.
It is not appropriate to compare the performance of different combustion systems with quite different orders
of combustion intensity.
combustion intensity = heat release rate
combustor vol. * pressure
[kW / m3-atm]
Combustion Intensity
Combined Cycle Power Plants 3. Combustor 23 / 110
HIoPE
Combined Cycle Power Plants
Combustor performance is measured by combustion efficiency, the pressure drop in the combustor, and the
evenness of the outlet temperature profile.
Combustion efficiency is a measure of combustion completeness that affects the fuel consumption directly,
since the heating value of any unburned fuel is not used to increase the turbine inlet temperature.
In the past, major goals of combustor design were high combustion efficiency and the reduction of visible
smoke, both were solved by the early 1970s.
Typical values for combustion efficiency is 99%.
Combustion efficiency at off-design conditions, such as idle, must exceed 98.5% to satisfy regulations on
exhaust carbon monoxide and UHC.
The combustion efficiency can be determined by the chemical analysis of the combustion products.
Knowing the air/fuel ratio used and the proportion incompletely burnt constituents, it is possible to calculate
combustion efficiency.
Combustion efficiency = Actually released energy
Theoretically available energy
Combustion efficiency = Fuel burnt in the combustor
Total fuel input
Combustion Efficiency
LHVf
afa
theretical
actualcomb
m
hmhmm
h
h
23
h2 = enthalpy leaving the compressor
h3 = enthalpy entering the turbine
ma = mass flow rate of air
mf = mass flow rate of fuel
LHV = lower heating value of fuel
Combined Cycle Power Plants 3. Combustor 24 / 110
HIoPE
Combined Cycle Power Plants
1
1,
2,
21
o
o
T
TKKPLF
The pressure loss in a combustor is a major problem
because it affects gas turbine efficiency and power
output.
The pressure loss occurred in the combustor is a very
important parameter, because the efficiency of the gas
turbine will be reduced by an equal percentage.
Typical values for pressure loss in combustor is usually
in the range of 2~4% of static pressure.
Pressure loss in a combustor is caused by friction,
turbulence and the temperature rise due to
combustion.
The pressure loss due to friction is called as friction
loss and is found to be much higher.
The fundamental loss is caused by temperature rise
due to combustion.
The overall stagnation pressure loss is the sum of the
fundamental loss and friction loss.
PLF = Cold loss + Hot loss
PLF = Pressure loss factor, K1 = cold loss, K2 =
fundamental loss
1 2 3 0
40
30
20
10
Temperature ratio, To,2/To,1
Pre
ssu
re lo
ss fa
cto
r
Cold loss, K1
Fundamental
pressure loss
Pressure Loss in a Combustor
V1 V2
1 2
1
2/ 1,
2,
2
11
2,1,
o
ooo
T
T
V
pp
Combined Cycle Power Plants 3. Combustor 25 / 110
HIoPE
Combined Cycle Power Plants
Uniformity of the Combustor Outlet Temperature Profile [1/2]
The uniformity of the combustor outlet temperature
profile can be investigated along two directions,
tangential and radial.
The uniformity of the combustor outlet temperature
profile affects the useful level of TIT, because the
average gas temperature is limited by the peak
gas temperature.
The figure shown in the right hand side is a
temperature profile measured at the exit of the gas
turbine at various loads.
The profile factor is the ratio between the
maximum exit temperature and the average exit
temperature.
This is a very important parameter for determining
the health of the gas turbine caused by thermal
fatigue.
The settings for shutdown of gas turbines using
natural gas as a fuel are set at about 100F
between the maximum and minimum temperatures
at any given time at the exit.
Temperature difference between adjacent probes
should not exceed 40~50F for turbines using
natural gas as a fuel.
[ An example of exit temperature profile of a gas
turbine for various loads, 16 probes were used ]
Profile Factor
Combined Cycle Power Plants 3. Combustor 26 / 110
HIoPE
Combined Cycle Power Plants
The turbine downstream of the combustor has to withstand very
high temperatures and stresses, due to the centrifugal loads.
These stresses are highest towards the hub of the blade, so the
radial temperature profile in the combustor is controlled, with the
peak temperatures around two thirds of the way up the blade.
Temperature factor, also known as traverse factor, is defined as:
1) The peak gas temperature minus mean gas temperature
divided by mean temperature rise in the nozzle design. The
traverse number must have a lower value between 0.05 and
0.15 in the turbine nozzle vanes.
2) The difference between the highest and the average radial
temperature.
Temperature Factor
Uniformity of the Combustor Outlet Temperature Profile [2/2]
Tip
Hub
Temperature
Combined Cycle Power Plants 3. Combustor 27 / 110
HIoPE
Combined Cycle Power Plants
Fuel and Combustion Theory 1
Factors Affecting Combustor Design 2
Combustor Type 3
NOx Formation and Its Control 4
Diffusion Combustor 5
Dry Low NOx Combustor 6
Catalytic Combustor 7
Combustor Cooling 8
Combined Cycle Power Plants 3. Combustor 28 / 110
HIoPE
Combined Cycle Power Plants
Function of a diffuser = Velocity energy Pressure energy
The velocity of the air leaving the compressor is decreased before it enters the combustor in order to
reduce the combustor pressure loss and the air velocity in the combustor.
Reduced air velocity in the combustor contributes to flame stability
The velocity of compressor discharged air is so high – 150 m/s – and this velocity is reduced to about 60
m/s by the diffuser.
Combustion must maintained in a stream of air moving with high velocity of 30-60 m/s.
Diffuser
Combined Cycle Power Plants 3. Combustor 29 / 110
HIoPE
Combined Cycle Power Plants
Can-Type Combustor [1/8]
Arrangement
GE 9FB.05
Combined Cycle Power Plants 3. Combustor 30 / 110
HIoPE
Combined Cycle Power Plants
Arrangement
Can-Type Combustor [2/8]
Combined Cycle Power Plants 3. Combustor 31 / 110
HIoPE
Combined Cycle Power Plants
Can type combustor, which is also called as multiple chamber, or can-annular combustor, is commonly used
for industrial gas turbines.
The major advantage is that development can be carried out on a single can using only a fraction of the
overall airflow and fuel flow.
It is relatively easy to maintain them. That is, each can be removed easily and worked on independently.
The individual combustors are interconnected with small cross-fire tubes (interconnector tubes ) so that, as
combustion occurs in the two combustors with igniter plugs, the flame can move to all of the remaining cans.
Another mission of the cross-fire tubes is that this allows each can to operate at the same pressure, which
make the engine vibration free.
Flow at the exit of the combustor is not uniform, which make the engine vibration higher.
The combustion ignition system uses two spark plugs and two flame detectors, along with cross-fire tubes.
Ignition in one of the chambers produces a pressure rise which forces hot gases through the cross-fire tubes,
propagating ignition to other cans within one second.
Flame detectors, located diametrically opposite the spark plugs, signal the control system when ignition has
been completed.
Can-Type Combustor [3/8]
Combined Cycle Power Plants 3. Combustor 32 / 110
HIoPE
Combined Cycle Power Plants
Can type combustors can be of the straight-through design or reverse-flow design and have single fuel
nozzles in the diffusion combustors, while each combustor have three to eight nozzles and one pilot nozzle
in the center in the DLN combustor.
In theory, a large number of fuel nozzles provide better distribution of the fuel gas (or greater atomization of
the liquid fuel droplets) and more rapid and uniform burning and heat release. But the problems of equally
distributing fuel to each fuel nozzle significantly limit the number of fuel nozzles employed.
The straight-through design is used on aircraft engines, while a reverse-flow design is used on heavy-duty
gas turbines.
Can-Type Combustor [4/8]
Combined Cycle Power Plants 3. Combustor 33 / 110
HIoPE
Combined Cycle Power Plants
Transition Piece 1st Stage Nozzle
1st Stage
Blades
3rd Stage
Blades
Combustion
Can
2nd Stage
Nozzle
2nd Stage
Blade
3rd Stage
Nozzle
Transition Piece
Can-Type Combustor [5/8]
Combined Cycle Power Plants 3. Combustor 34 / 110
HIoPE
Combined Cycle Power Plants
[GEAE ] [ Siemens ]
The development of a can type combustor requires experiments with only one can, while the annular
combustor must be treated as a unit and requires much more hardware and a large amount of compressor
flow.
Can-Type Combustor [6/8]
Combined Cycle Power Plants 3. Combustor 35 / 110
HIoPE
Combined Cycle Power Plants
① 선회유동 형성 (수백 fps의 축방향 공기속도를 5~6 fps로 감속). 만약, 축방향 공기속도가 너무 빠르면,
• 연소정지( flame-out) 초래
• 연소기 압력강하 초래
• 연소기 효율저하 초래
② 연료-공기 혼합 촉진
③ 화염길이 짧게 유지
• 연소실 길이 축소
• 터빈으로 화염전파 방지
Swirler
Can-Type Combustor [7/8]
Combined Cycle Power Plants 3. Combustor 36 / 110
HIoPE
Combined Cycle Power Plants
A free vortex increases tangential velocity at the
center.
The higher velocity at the center produces a lower
static pressure and thus a radial pressure gradient.
This is the reason that a recirculation zone is
formed just downstream of swirl vanes.
The recirculation zone acts as flame holders during
continuous operation of gas turbine.
Recirculation Zone
Can-Type Combustor [8/8]
Combined Cycle Power Plants 3. Combustor 37 / 110
HIoPE
Combined Cycle Power Plants
It consists of an outer casing, a liner
completely annular in form, and an
inner casing.
The annular combustor is commonly
used today in all sizes of aero engines.
Annular Combustor [1/5]
Configuration
Combined Cycle Power Plants 3. Combustor 38 / 110
HIoPE
Combined Cycle Power Plants
V94.3 gas turbine consists of 16-stage axial flow
compressor followed by an annular combustor and a
four-stage reaction type axial-flow turbine.
Annular combustors are superior to can combustors
in terms of overall temperature distribution factor
(OTDF). Can combustors have a relative higher
OTDF that may result in thermo-mechanical fatigue
problems.
Annular combustor popularity increases with higher
temperatures or low-BTU gases, because the
amount of cooling air required is much less than in
can type designs due to a much smaller surface
area.
The amount of cooling air required becomes an
important consideration in low-BTU gas applications,
because most of air is used up in the primary zone
and little is left for film cooling.
V94.3 & V84.3 [Siemens]
Annular Combustor [2/5]
Combined Cycle Power Plants 3. Combustor 39 / 110
HIoPE
Combined Cycle Power Plants
GT26 & GT24 [Alstom]
Annular Combustor [3/5]
Combined Cycle Power Plants 3. Combustor 40 / 110
HIoPE
Combined Cycle Power Plants
DLE Combustor for Aeroderivative Gas Turbines (GE)
Premixer
Combustion Liner
Heat Shield
Three rings of
fuel nozzles
Annular Combustor [4/5]
Combined Cycle Power Plants 3. Combustor 41 / 110
HIoPE
Combined Cycle Power Plants
Advantages Disadvantages
• The main advantage of the annular combustion
chamber is that for the same power output, the
length of the chamber is only 75 per cent of that of a
can-annular system of the same diameter, resulting
in a considerable saving in weight and cost.
• Its minimal surface area requires less cooling air.
• Another advantage is the elimination of combustion
propagation problems from chamber to chamber.
• Flow at the exit of the combustor is uniform, which
make the engine vibration free.
• It has a reduced surface exposed to the gas, which
should result in less pressure loss across the
chamber.
• It is difficult to obtain an uniform fuel-air distribution
and an uniform outlet temperature distribution, in
spite of employing a large number of fuel jets.
• The structure of annular combustors is inevitably
weak. Therefore, it has big possibility of buckling of
the hot flame tube walls.
• The development of an new annular chamber
should be carried out with a test facility capable of
supplying the full engine air mass flow. This requires
a huge layout and involves enormous cost.
• However, a major disadvantage is that it is hard to
repair it.
Annular Combustor [5/5]
Combined Cycle Power Plants 3. Combustor 42 / 110
HIoPE
Combined Cycle Power Plants
Industrial gas turbines initially employed large external (silo) combustors in order to ensure efficient
combustion, which is caused by lower gas velocities.
Typically emission levels of CO 10 ppm were achieved and UHC emission was undetectable.
Silo combustors require too much cooling air and at part load the large areas of cooling surface adversely
affected combustion efficiency.
The initial use of diffusion burners increased NOx formation.
Long residence times also increased NOx formation.
Because of high level of NOx formation and other structural reasons silo combustors were replaced by small
multiple chambers.
Siemens V94.3 GE 10 Siemens
Silo Combustor
Combined Cycle Power Plants 3. Combustor 43 / 110
HIoPE
Combined Cycle Power Plants
Type Advantages Disadvantages
Can • Better maintenance
• Easier development
• Flow is not uniform at the combustor outlet
• Higher vibration
• Heavier
• Longer
Annular
• Flow is uniform at the combustor outlet
• Vibration free
• Not heavier
• Higher thermal efficiency because of
smaller cooling area
• No components for flame propagation
• Maintenance is not easy
• Development is difficult
Silo • Complete combustion
• Minimization of CO emission
• Higher NOx emission
• No good for part load operation
Comparison of Combustors
Combined Cycle Power Plants 3. Combustor 44 / 110
HIoPE
Combined Cycle Power Plants
Fuel and Combustion Theory 1
Factors Affecting Combustor Design 2
Combustor Type 3
NOx Formation and Its Control 4
Diffusion Combustor 5
Dry Low NOx Combustor 6
Catalytic Combustor 7
Combustor Cooling 8
Combined Cycle Power Plants 3. Combustor 45 / 110
HIoPE
Combined Cycle Power Plants
Thermal NOx [1/4]
There are two mechanisms of NOx formation in gas turbine combustors.
1) The oxidation of atmospheric nitrogen found in the combustion air (thermal NOx and prompt NOx), and
2) The conversion of nitrogen chemically bound in the fuel (fuel NOx).
Thermal NOx is formed by a series of chemical reactions in which oxygen and nitrogen present in the
combustion air dissociate and subsequently react to form NOx.
Prompt NOx, a form of thermal NOx, is formed in the proximity of the flame front as intermediate combustion
products such as HCN, N and NH that are oxidized to form NOx.
Prompt NOx is formed in both fuel-rich flame zones and DLN combustion zones.
The contribution of prompt NOx to overall NOx emissions is relatively small in conventional diffusion
combustors, but this contribution is a significant percentage of overall thermal NOx in DLN combustors.
For this reason, prompt NOx becomes an important consideration for DLN combustor designs, establishing
a minimum NOx level attainable in lean mixtures.
The thermal route is a primary mechanism for NOx when flame temperatures are above approximately 1800
K(1523C). Below this temperature, the thermal reactions are relatively slow.
Thus, a common approach to NOx control is to reduce the combustion temperature so that very little thermal
NOx can form.
Combined Cycle Power Plants 3. Combustor 46 / 110
HIoPE
Combined Cycle Power Plants
General Emission Performance of a Lean Premix Combustor
Thermal NOx [2/4]
1700 1200 1300 1400 1500 1600
140
120
100
80
60
40
20
0
Reaction temperature, C
NO
x,
CO
, vp
pm
@ 1
5%
O2
CO emissions
1800
160
Pulsation
NOx emissions
Operating
range
Pre
ssu
re p
uls
atio
ns
Compressor
Fuel
Turbine
Air
Power
Exhaust NOx
~ 25 ppm 350C
Bypass Air
1800C
1300C
Combined Cycle Power Plants 3. Combustor 47 / 110
HIoPE
Combined Cycle Power Plants
The mechanisms of NOx formation are as follows.
• Extended Zeldovich mechanism:
(1) O + N2 NO + N
(2) N + O2 NO + O
(3) N + OH NO + H
• Nitrous oxide:
(4) N2 + O + M N2O + M (여기서 M은 N2, O2, CO2 같은 제 3의 물질)
(5) N2O + O NO + NO
(6) N2O + H NO + NH
• Prompt:
(7) N2 + CH HCN + N
In the absence of thermal NOx, the other mechanisms become significant. Non-equilibrium concentration of
O or H atoms in the flame region can produce NOx via reactions (1) to (3), and this is known as Zeldovich
NOx.
The prompt mechanism is followed by a sequence of reactions converting HCN to NO; reaction (7) is just
the initiation.
Prompt NOx is formed very briefly during the combustion process by the interaction of CH radicals on N2,
the quantity of NO produced in this manner being also relatively small.
Thermal NOx [3/4]
Combined Cycle Power Plants 3. Combustor 48 / 110
HIoPE
Combined Cycle Power Plants
NOx product is approximately 95% of NO, with NO2 making up the balance plus a small amount of N2O.
Emission limits are defined as the quantity of nitrogen dioxide equivalent, as the NO is ultimately converted
into NO2 in the atmosphere.
The rate of NO formation has been determined theoretically by
The reduction in temperature becomes the main strategy for controlling thermal NOx emission from gas
turbines.
t = residence time at high temperature (sec)
T = absolute temperature (K)
[N2], [O2] = concentration of nitrogen, oxygen (mol/cm3)
d[NOx]/dt = rate of NOx formation (mol/cm3/s)
The Rate of Thermal NOx Formation
5.0
225.0
16
x ON69090
exp100.6]NO[
TTdt
d
Thermal NOx [4/4]
Combined Cycle Power Plants 3. Combustor 49 / 110
HIoPE
Combined Cycle Power Plants
Fuel NOx
Fuel NOx is the conversion of fuel-bound nitrogen (FBN) to NOx during combustion.
During combustion, the nitrogen bound in the fuel is released as a free radical and ultimately forms free N2
or NO.
Fuel NOx can contribute as much as 50% of total emissions from oil and 80% from coal. This is because the
amount of FBN is large in coal, small in oil, but little in natural gas.
Natural gas typically contains little or no FBN. As a result, when compared to thermal NOx, fuel NOx is not a
major contributor to overall NOx emissions from stationary gas turbine firing natural gas. Molecular nitrogen,
present as N2 in natural gas, does not contribute significantly to fuel NOx formation.
Some low-Btu synthetic fuel contain nitrogen in the form of ammonia (NH3).
Other low-Btu fuels such as sewage and process waste stream gases also contain nitrogen.
When these fuels are burned, the nitrogen bonds break and some of the resulting free nitrogen oxidizes to
form NOx.
With excess air, the degree of fuel NOx formation is primarily a function of the nitrogen content in the fuel.
The fraction of FBN converted to fuel NOx decreases as the nitrogen content increases, although the
absolute magnitude of fuel NOx increases. For example, a fuel with 0.01 percent nitrogen may have 100
percent of its FBN converted to fuel NOx, whereas a fuel with a 1.0 percent nitrogen may have only a 40
percent conversion rate.
Combined Cycle Power Plants 3. Combustor 50 / 110
HIoPE
Combined Cycle Power Plants
Tropospheric ozone has been a significant air pollution problem because it is the primary constituent of
smog.
Many countries do not meet ozone standard and thereby expose large segments of the population to
unhealthy levels of ozone in the air.
NO2 reacts in the presence of air and ultraviolet light (UV) in sunlight to form ozone and nitric oxide (NO).
The NO then reacts with free radicals in the atmosphere, which are also created by the UV acting volatile
organic compounds (VOC).
The free radicals then recycle NO to NO2. In this way, each molecule of NO can produce ozone multiple
times.
In addition to the ozone concerns, NOx and SOx in the atmosphere are captured by moisture to form acid
rain.
Acid rain impacts certain ecosystems and some segments of our economy.
All of these facts indicate the need to reduce NOx emissions, and understanding of its generation and control
mechanisms.
오존 농도 0.12 ppm/h 이상
(오존주의보) 0.3 ppm/h 이상
(오존경보) 0.5 ppm/h 이상 (오존중대경보)
인체에 나타나는 증상
• 눈과 코 자극
• 불안감과 두통 유발
• 호흡수 증가
• 호흡기 자극
• 가슴압박
• 시력감소
• 폐기능 저하
• 기관지 자극
• 패혈증 유발
Ozone
Combined Cycle Power Plants 3. Combustor 51 / 110
HIoPE
Combined Cycle Power Plants
대류권에 시간당 오존농도가 0.12ppm 이상일 때 내려지는 주의보.
성층권의 오존은 지구상의 생명을 보호하는 보호막 역할을 한다. 그리고 대류권에 오존(ozone: O3, 강력한 발암물질)이 적당량 존재할 경우 강력한 산화력으로 살균, 탈취작용을 한다.
그러나 오존농도가 일정기준 이상 높아지면 호흡기나 눈이 자극을 받아 기침이 나고 눈이 따끔거리며, 심한 경우 폐 기능저하를 가져오는 등 인체에 피해를 주기도 하며, 농작물 수확량 감소를 가져오는 유독물질이 된다.
오존 경보제에 의해 각 자치단체장이 권역별로 시간당 오존농도가 0.12 ppm에 달하면 주의보, 0.3 ppm으로 오르면 경보, 0.5 ppm 이상 치솟으면 중대경보를 내리게 된다.
농도가 '주의보' 발령 수준일 때 1시간 이상 노출되면 호흡기와 눈에 자극을 느끼고, 기침을 유발한다. 따라서 주의보가 발령되면 호흡기 환자나 노약자, 5세 이하의 어린이는 외출을 삼가고 운전자도 차량 이용을 자제해야 한다.
'경보'가 발령되면 소각시설과 자동차의 사용 자제가 요청되고 해당지역의 유치원과 학교는 실외학습을 자제해야 한다.
'중대경보'가 발령되는 0.5 ppm에 6시간 노출되면 숨을 들이마시는 기도가 수축되면서 마른기침이 나오고 가슴이 답답해지고 통증을 느끼게 된다. 특히 물에 잘 녹지 않는 오존이 장시간 폐 깊은 곳까지 들어가면 염증과 폐수종을 일으키며, 심하면 호흡곤란을 일으켜 실신하는 수도 있다.
중대경보가 발령되면 소각시설 사용과 자동차 통행이 금지되며, 주민의 실외활동 금지가 요청된다.
오존 주의보
Combined Cycle Power Plants 3. Combustor 52 / 110
HIoPE
Combined Cycle Power Plants
NOx Control Methods in Gas Turbines
1. Diluent injection
• Steam, CO2, N2 or other diluent is injected to the combustion zone of diffusion combustor.
• Since NOx formation is a function of flame temperature, the addition of diluent lowers the flame
temperature to reduce NOx formation.
2. Premixed fuel lean combustion
• Typical premixed combustion mixes the fuel and oxidant upstream of the burner.
• Premixed combustion allows use of leaner fuel mixtures that reduce the flame temperature, and
therefore thermal NOx formation.
• This is the basis for DLN combustor operation.
3. Catalytic combustion
• Lean premixed combustion is also the basis for achieving low emissions from catalytic combustors.
These systems use a catalytic reactor bed mounted within the combustor to burn a very lean fuel air
mixture.
• The catalyst material stability and its long term performance are the major challenges in the development
of an operational catalytic combustor.
• Catalytic combustion is also an unlikely solution for retrofitting existing turbines.
4. Post combustion treatment
Combined Cycle Power Plants 3. Combustor 53 / 110
HIoPE
Combined Cycle Power Plants
Since September 1979, when regulations required that NOx emission be limited to 75 ppmvd, many gas
turbines have accumulated millions of operating hours using either steam or water injection to meet
required NOx levels. Most gas turbines control NOx emission with diluent injection into the combustor until
1990.
The injected diluent used as a heat sink that lowers the combustion zone temperature, which is the primary
parameter affecting NOx formation. As the combustion zone temperature decreases, NOx production
decreases exponentially.
The increased diluent injection lowers the thermal efficiency because some of the energy of combustion
gases is used to heat the water or steam.
Water (or steam) injection for power augmentation economically attractive in some circumstance, such as
peaking applications. However, the process required large quantities of clean water – to at least boiler feed
water standard – to avoid corrosion of blade or fouling and blocking of cooling air holes by impurities.
In case of water injection, however, there was an increase in levels of pressure fluctuations associated with
combustion. Such dynamic pressures can excite acoustic resonance which may shorten combustor life.
Steam injection, while lacking the cooling effect of water evaporation, can nevertheless give better mixing
and lower dynamic pressure levels than water injection.
Carbon monoxide, representing the measure of the inefficiency of the combustion process, also increases
as the diluent injection increases.
The lowest practical levels achieved with diluent injection are generally 25 ppm when firing natural gas and
42 ppm when firing oil.
Water/Steam Injection [1/3]
Combined Cycle Power Plants 3. Combustor 54 / 110
HIoPE
Combined Cycle Power Plants
Water to fuel ratio
0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0
1.0
0.8
0.6
0.4
0.2
0.0
Rela
tive
NO
x p
rod
uctio
n r
ate
Steam injection
Water injection
Mixture of natural
gas and steam
Water/Steam Injection [2/3]
Water injection is extremely effective means for
reducing NOx formation.
To maximize the effectiveness of the water
injection, fuel nozzles have been designed with
additional passage to inject water into the
combustor head end.
The water is thus effectively mixed with the
incoming combustion air and reaches the flame
zone at its hottest point.
Steam injection for NOx reduction follows
essentially the same path into the bombustor
head end as water.
However, steam is not as effective as water in
reducing thermal NOx.
The high latent heat of water acts as a strong
heat sink in reducing the flame temperature.
In general, for a given NOx reduction,
approximately 1.6 times as much steam as
water on a mass basis is required for control.
There are practical limits to the amount of water or steam that can be injected into the combustor. This is
because the increased quantities of water/steam were proved detrimental to cycle efficiency and part lives,
and the emission rates for other pollutants also began to rise significantly.
Combined Cycle Power Plants 3. Combustor 55 / 110
HIoPE
Combined Cycle Power Plants
Base load operation (MS7001E)
Peak load operation (MS7001E)
100exp(-1.58W/F ratio)
0.0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1.0
100
10
Water to fuel ratio
NO
x, p
pm
vd @
15%
O2
50
Experimental Results TR-108057 (EPRI)
Water/Steam Injection [3/3]
Combined Cycle Power Plants 3. Combustor 56 / 110
HIoPE
Combined Cycle Power Plants
Selective Catalytic Reduction [1/3]
SCR is the most effective and proven technology to reduce NOx emissions, greater
than 90%.
NOx level less than 9 ppmvd can be obtained at 15% oxygen for all combined
cycle plants with selective catalytic reduction (SCR) systems.
760F
O2=17%
895F
O2=16.4%
NOx=30 ppmv
CO=15 ppmv
680F
SC
R c
ata
lyst
CO
ca
taly
st
395F
O2=16.4%
NOx=6 ppmv
CO=3 ppmv
Duct burner
Combined Cycle Power Plants 3. Combustor 57 / 110
HIoPE
Combined Cycle Power Plants
NOx contained in the gas turbine exhaust gas is converted into harmless molecular nitrogen and water on
the catalyst bed by the reaction with ammonia.
Typically, the SCR catalyst operates under a narrow temperature range of 570F/300C and 750F/400C.
The equipment is comprised of segments stacked in the exhaust duct. Each segment has a honeycomb
pattern with passages aligned to the direction of the flow.
A catalyst such a vanadium pentoxide is deposited on the surface of the honeycomb.
For a GE turbine MS7001EA an SCR designed to remove 90% of the NOx has a volume of 175 m3 and
weights 111 tons.
The major disadvantages of this system are the cost of installation and maintenance of the system, the
efficiency penalty due to the pressure drop introduced by the catalyst, and the potential for NH3 slip.
HRSG flue gas draft losses: approximately 25 mbar, 35 mbar if catalysts are required.
A certain amount of ammonia, that is excess ammonia, may pass through the catalyst unreacted and
emitted into the atmosphere as “ammonia slip”.
Both NOx and ammonia are acutely toxic, and they contribute to fine particle formation, acidifying deposition.
In most cases, ammonia slip is currently limited by permit condition to either 5 or 10 ppm at 15% O2,
because ammonia is a hazardous material.
Selective Catalytic Reduction [2/3]
Combined Cycle Power Plants 3. Combustor 58 / 110
HIoPE
Combined Cycle Power Plants
Ammonium hydroxide (수산화 암모늄) solution sprayed over a mesh containing titanium and vanadium
oxide catalysts reacts with the NOx to form nitrogen and water.
The reaction rate shows peak level at around 350C, and this temperature is appeared between the
evaporator and economizer sections of HRSG.
However, when the NOx emission should be controlled less than 10 ppm, this system can be used with the
combination of water injection.
Anhydrous ammonia (NH3) is the most cheap reagent.
Aqueous ammonia (NH4OH) is a safer to transport, handle and store than anhydrous ammonia. For these
reasons, many end-users and operators use it.
SCR systems are sensitive to fuels containing more than 1000 ppm sulfur.
Ammonia can lead to fouling of HRSG tubes downstream of the SCR if moderate quantities of sulfur are
present in the flue gas.
Ammonia and sulfur react to form ammonium bisulfate, a sticky substance that forms in the low temperature
section of HRSG (usually the economizer).
The deposited ammonium bisulfate is difficult to remove and can lead to a marked increase in pressure
drop across the HRSG.
Selective Catalytic Reduction [3/3]
Combined Cycle Power Plants 3. Combustor 59 / 110
HIoPE
Combined Cycle Power Plants
Fuel and Combustion Theory 1
Factors Affecting Combustor Design 2
Combustor Type 3
NOx Formation and Its Control 4
Diffusion Combustor 5
Dry Low NOx Combustor 6
Catalytic Combustor 7
Combustor Cooling 8
Combined Cycle Power Plants 3. Combustor 60 / 110
HIoPE
Combined Cycle Power Plants
Diffusion Combustion
Both fuel and oxidizer are supplied to the reaction zone
in an unmixed state in a diffusion combustor.
Fuel mixes with the air by turbulent diffusion and the
flame front can be considered the locus of the
stoichiometric mixture where temperatures reach
approximately 2000C.
Stoichiometric mixture will lead to both the highest flame
temperature and the fastest reaction rates.
Optimal conditions for combustion are restricted to the
vicinity of the surface of stoichiometric mixture. This is
the surface where fuel and air are locally mixed in a
proportion that allows both to be entirely consumed.
Since combustion is much faster than diffusion in most
cases, the latter governs the rate of entire combustion
process. This is the reason why those flames are called
diffusion flames.
Diffusion combustion has been used extensively
because there is no backfire.
Fuel
Post flame
radiation
Surface of
stoichiometric
mixture
Air Air
Combined Cycle Power Plants 3. Combustor 61 / 110
HIoPE
Combined Cycle Power Plants
Combustion Zones
The fuel injected into the combustor is evaporated and burnt in the primary zone, where air-fuel ratio is
about 60:1.
The fuel is burnt almost stoichiometrically with one-third or less of the compressor discharge air.
The combustion process consists of three phases, the endothermic dissociation of the fuel molecules,
followed by a fast, exothermic formation of CO and H2O, and finally the slower, exothermic oxidation of CO
to CO2.
About 80% of the energy is released in the second phase during the formation of CO. The slower burn-out to
CO2 can require 75% of the combustion zone length.
The hot combustion products are cooled by dilution in the dilution zone with excess air to temperatures
acceptable to combustor walls and turbine blades.
Combined Cycle Power Plants 3. Combustor 62 / 110
HIoPE
Combined Cycle Power Plants
Emission in a Diffusion Combustor [1/2]
1000
0.5
4000
3000
2000
1.5 1.0
Equivalence ratio
Fla
me
te
mp
era
ture
, F
100
300
200
NO
x r
ate
, p
pm
v
High smoke
emissions High CO
emissions
Sto
ich
iom
etr
ic c
on
ditio
n
Fuel rich Fuel lean
Op
tim
um
ba
nd
Stoichiometric condition means that
the proportions of the reactants are
such that there are exactly enough
oxidizer molecules to bring about a
complete reaction to stable molecular
forms in the products.
Equivalence ratio ( ) is the ratio of
the oxygen content at stoichiometric
condition and actual condition
[ Emission for diffusion combustors using No. 2 oil as a fuel ]
With precisely enough air to
theoretically consume all of the fuel,
combustion is referred to as a
“stoichiometric” f/a ratio.
Adding more air produces combustion
that is fuel-lean, and adding less air
produces combustion that is fuel-rich.
= (f/a) stoichiometric
(f/a) actual
Combined Cycle Power Plants 3. Combustor 63 / 110
HIoPE
Combined Cycle Power Plants
The overall air/fuel ratio is in the region of 100:1,
while the stoichiometric ratio is approximately 15:1
The air/fuel ratio might vary from about 60:1 to 120:1
for simple cycle gas turbines and from 100:1 to 200:1
if a heat exchange is used.
1400
NOx limit
CO
em
issio
n, p
pm
Primary zone temperature, K
120
100
80
60
40
20
0 1500 1600 1700 1800 1900 2000
0
5
10
30
25
20
15
CO limit
Permissible temperature
range to meet both CO and
NOx limits (optimum band)
NO
x e
mis
sio
n, p
pm
Emission in a Diffusion Combustor [2/2]
Carbon monoxide is produced when incomplete
combustion occurs.
Increasing combustion temperatures improves
burning and thus reduces carbon monoxide
emissions.
Nitrogen is the dominant element in the
atmosphere. Raising the temperature of air
causes it to react with oxygen, producing nitrogen
oxides (NOx).
Normal combustion temperatures rage from
1871C to 1927C. At this temperature, the
volume of NOx in the combustion gas is about
0.01%.
The higher the air temperature and exposure time
to these temperatures, the greater the formation
of NOx.
There is an optimum band, where both CO and
NOx emissions are low.
The ideal combustor would therefore always burn
fuel within this band, independent of the engine
operating condition.
Combined Cycle Power Plants 3. Combustor 64 / 110
HIoPE
Combined Cycle Power Plants
[ Stability loop ]
It is necessary to maintain an optimum air-fuel ratio to
ensure ignition and sufficiently fast combustion.
Rich mixture will result in cracking(열분해) of the fuel
with the formation of amorphous carbon which is
difficult to burn. Although insufficient air is a cause of
carbon formation, the problem is intimately associated
with improper mixing.
Lean mixture (or poor atomization) and poor mixing will
lead to failure of combustion.
Operation outside the region of stable burning results
in unstable combustion causing vibration and
combustion failure.
The stability range and air-fuel ratio range decreases
as the air velocity is increased.
Stability Limits
Normally, combustors are designed with an inlet air velocity not exceeding 80 m/s at design load.
In order to cool the products of combustion to a temperature acceptable to turbine blades, it is necessary to
use a total air-fuel ratio far in excess of those permitting stable combustion.
This difficulty is usually avoided by admitting a satisfactory amount of primary air so as to maintain stable
combustion.
The products of combustion are then cooled by introducing additional air called secondary air.
The air-fuel ratio calculated with respect to the sum of primary and secondary air is known as the total air-
fuel ratio.
Combined Cycle Power Plants 3. Combustor 65 / 110
HIoPE
Combined Cycle Power Plants
Fuel and Combustion Theory 1
Factors Affecting Combustor Design 2
Combustor Type 3
NOx Formation and Its Control 4
Diffusion Combustor 5
Dry Low NOx Combustor 6
Catalytic Combustor 7
Combustor Cooling 8
Combined Cycle Power Plants 3. Combustor 66 / 110
HIoPE
Combined Cycle Power Plants
Catalytic combustor
Design Change of Combustors
Diffusion combustor Wet combustor DLN combustor
Steam or water injection Inclusion of catalyst
Single fuel nozzle Multiple fuel nozzle
Reduced NOx emission Low NOx emission Near zero NOx emission
Premix fuel and air
before combustion
Fuel injector Spark
plug D
iese
l e
ng
ine
Sp
ark
ig
nitio
n e
ng
ine
Combined Cycle Power Plants 3. Combustor 67 / 110
HIoPE
Combined Cycle Power Plants
Diffusion Flame Premixed Flame
• Fuel and air mix and burn at the same time
• An example for diffusion combustion is a Diesel
engine, where a liquid fuel spray is injected into the
compressed hot air within the cylinder. It rapidly
evaporates and mixes with the air and then auto-
ignition under partly premixed conditions
• Flame color is bright yellow
• NOx formation in post-flame regions
• Fuel and air mixed and then burn
• In a spark ignition engine, a premixed turbulent
flame front propagates from the spark through the
combustion chamber until the entire mixture is
burnt.
• Flame color is blue to bluish-green
• Low NOx burners
Different Modes of Laminar Combustion
Post flame
oxidation and
radiation
Premixed
flame front
Fuel + air Fuel
Post flame
radiation Surface of
stoichiometric
mixture
Air Air
Combined Cycle Power Plants 3. Combustor 68 / 110
HIoPE
Combined Cycle Power Plants
The high costs of both water injection and SCR systems give opportunities to develop advanced
combustors, so-called dry low NOx (DLN) combustors.
Moreover, the introduction of steam or water to the gas turbine combustor is a thermodynamic loss, due to
taking some of the energy from combustion gases to heat water or steam. However, DLN combustor has no
impact on the cycle efficiency. Therefore, DLN combustor is more desirable than steam/water injection.
DLN combustor premixes air and fuel, and makes a fuel lean mixture that significantly reduces peak flame
temperature and thermal NOx formation.
Another important advantage of the DLN combustor is that the amount of NOx formed does not increase
with residence time.
Since long residence times are required to minimize CO and unburned hydrocarbon (UHC) emissions, DLN
systems can achieve low CO and UHC emissions while maintaining low NOx levels.
To minimize flame temperature and hence NOx formation the fuel/air mixture is weakened to as near the
extinction point as can safely be realized. The main problems associated with lean premix flames are
stability, inflexibility and the limited turn-down range.
To stabilize the flame, hybrid system having two fuel injectors of main fuel and pilot fuel is used commonly.
In the hybrid system, the bulk of the fuel (more than 75%) is burned in a premixed burner, the remainder
being supplied to a small pilot diffusion flame embedded in the flow.
The main fuel is injected into the air stream immediately downstream of the swirler at the inlet to the
premixing chamber. The pilot fuel is injected directly into the combustion chamber with little if any premixing.
A small portion of the fuel is always burned richer to provide a stable “piloting” zone, while the remainder is
burned lean.
In both cases, a swirler is used to create the required flow conditions in the combustor to stabilize the flame.
DLN Combustor [1/2]
Combined Cycle Power Plants 3. Combustor 69 / 110
HIoPE
Combined Cycle Power Plants
With the flame temperature being much closer to the lean limit than in a diffusion combustor, some action
has to be taken when the engine load is reduced to prevent flame out.
If no action was taken, flame out would occur since the mixture strength would become too lean to burn.
Due to flame instability limitations of the DLN combustor below approximately 50% of rated load, the
combustor is typically operated in a conventional diffusion flame mode, resulting in higher NOx levels.
DLN fuel injector is much larger because it contains the fuel/air premixing chamber and the quantity of air
being mixed is large, approximately 50-60% of the combustion air flow.
The operation is limited to a narrow range of fuel/air ratio between the production of excessive NOx and
excessive CO.
Some manufacturers are now offering dual-fuel DLN combustors.
However, DLN operation on liquid fuels has been problematic due to issues involving liquid evaporation and
auto-ignition.
This consideration becomes more important as power producers consider converting from natural gas only
to dual-fuel operation as natural gas price rise.
DLN Combustor [2/2]
Combined Cycle Power Plants 3. Combustor 70 / 110
HIoPE
Combined Cycle Power Plants
1) 순수한 예혼합연소는 잉여공기비(excess air ratio)가 증가함에 따라 NOx 발생이 급격히 줄어들며, 잉여공기비가 2 이하인 경우 CO 발생은 매우 적다.
2) 순수한 예혼합연소는 운전영역이 매우 좁은데, 이는 잉여공기비가 2에 가까워지면 화염이 꺼지기 때문이다.
3) 예혼합연소에 파일럿 화염을 적용하면 화염이 꺼지는 염려가 없이 넓은 잉여공기비에 걸쳐서 운전이 가능하다. 이와 같은 이유 때문에 GE사와 Siemens사 모두 파일럿 화염을 적용한 예혼합연소기를 개발하여 사용하고 있다.
4) 파일럿 화염을 적용한 예혼합연소는 NOx와 CO의 발생을 최소화하기 위해서 운전영역을 NOx와 CO 발생 교차지점으로 제한한다.
5) 확산연소는 잉여공기비 전 영역에 걸쳐서 예혼합연소에 비해 NOx 발생량이 많다.
6) 확산연소의 운전영역은 예혼합연소에 비해 더 큰 잉여공기비를 가지는 부분에서 형성되며, NOx와 CO의 배출량도 훨씬 많다.
Emissions in a DLN Combustion [1/2]
CCPP includes gas turbines with DLN combustors that can
operate with stack gas NOx emission concentration as low
as 25 ppmvd at 15% oxygen without steam or water
injection, when the natural gas is used as a fuel.
NOx can be reduced to less than 9 ppmvd by the installation
of SCR in the HRSG.
Excess air ratio
NO
x a
nd
CO
em
issio
ns, p
pm
Combined Cycle Power Plants 3. Combustor 71 / 110
HIoPE
Combined Cycle Power Plants
Fla
me
te
mp
era
ture
Fuel to air ratio
Fuel rich Fuel lean
Diffusion combustor
Premixed
combustor
Extinction
of lean
premix
flame
200
250
100
150
50
0
25
Diffusion
combustor DLN
combustor
Catalytic
combustor
NO
x e
mis
sio
n, p
pm
vd
Fuel: natural gas
Emissions in a DLN Combustion [2/2]
Reduction of emissions in the premix combustor
NOx are reduced by
• Lowering flame temperature by lean combustion
• Elimination of local hot spots
CO and UHC are reduced by
• Increasing combustion residence time (volume)
• Combustor design to prevent local quenching
Combined Cycle Power Plants 3. Combustor 72 / 110
HIoPE
Combined Cycle Power Plants
Diffusion vs. Premix
Discuss the advantages of a lean premix combustor
1) Lower NOx emission Low flame temperature
2) Larger power output Less cooling air is required
3) Lower CO and UHC emission Increased residence time
4) Extended hot gas parts No water/steam injection
Diffusion
combustor
Lean premix
combustor
Combined Cycle Power Plants 3. Combustor 73 / 110
HIoPE
Combined Cycle Power Plants
1) The fuel-air equivalence ratio and residence time in the flame zone
to be low enough to achieve low NOx.
2) Acceptable levels of combustion noise (dynamics).
3) Stability at part-load operation.
4) Sufficient residence time for CO burn-out.
GE DLN Combustor [1/5]
DLN-1 Combustor
Combined Cycle Power Plants 3. Combustor 74 / 110
HIoPE
Combined Cycle Power Plants
Operating Modes of DLN-1 Combustor
GE DLN Combustor [2/5]
Combined Cycle Power Plants 3. Combustor 75 / 110
HIoPE
Combined Cycle Power Plants
A small portion of the fuel is always burned richer to provide a stable ‘piloting’ zone, while the remainder is
burned lean.
Primary
Flame is in the primary stage only. This mode is used to ignite, accelerate and operate the machine over
low- to mid-loads, up to pre-selected combustion reference temperature.
Lean-Lean
Flame is in both the primary and secondary stages. This mode is used for intermediate loads between two
pre-selected combustion reference temperature.
Secondary
Flame is in the secondary stage only. This mode is a transition state between lean-lean and premix modes.
This mode is necessary to extinguish the flame in the primary zone, before fuel is reintroduced into the
primary zone.
Premix
Fuel to both primary and secondary zones. Flame is in the secondary stage only. Optimum emissions are
generated in this mode by premixed flow. In the premix mode, the first stage thoroughly mixes the fuel and
air and delivers a uniform, lean, and unburned fuel/air mixture to the second stage.
A pilot nozzle produces a stable diffusion flame that can maintain high flammability in the premixed flame.
Operating Modes of DLN-1 Combustor
GE DLN Combustor [3/5]
Combined Cycle Power Plants 3. Combustor 76 / 110
HIoPE
Combined Cycle Power Plants
CO
(p
pm
vd
)
350
300
250
200
150
100
50
0 0 10 20 30 40 50 60 70 80 90 100
0
10
20
30
40
50
60
70
80
90
100
ISO ambient conditions
Gas turbine load, %
NO
x @
15%
O2 (
pp
mvd
)
NOx
CO
Emission Level - GE DLN-1 Combustor (Fuel: NG)
GE DLN Combustor [4/5]
Combined Cycle Power Plants 3. Combustor 77 / 110
HIoPE
Combined Cycle Power Plants
DLN-2.6 Fuel Nozzle Arrangement
GE DLN Combustor [5/5]
Combined Cycle Power Plants 3. Combustor 78 / 110
HIoPE
Combined Cycle Power Plants
Siemens DLN Combustor [1/3]
Hybrid Burner
Combined Cycle Power Plants 3. Combustor 79 / 110
HIoPE
Combined Cycle Power Plants
Most of the fuel is injected through eight main
fuel nozzles in the support housing, which is
divided into two fuel stages of four main nozzles
each.
The remainder of the fuel is divided between the
C-stage and the pilot.
The pilot nozzle includes a diffusion stage and a
premix pilot stage.
By injecting fuel through multiple injection holes
in the swirler vanes, enhanced fuel/air mixing is
achieved, thus reducing the peak temperature of
local hot spots that contribute NOx formation.
[ ULN (Ultra-Low NOx) combustor cross-section ]
ULN Burner
Siemens DLN Combustor [2/3]
Gas only support housing Combustor basket Dual fuel pilot nozzle Dual fuel support housing
Combined Cycle Power Plants 3. Combustor 80 / 110
HIoPE
Combined Cycle Power Plants
(Supply)
Steam
(Return)
(Return) Bypass valve
M501G steam cooled
liner in fabrication
Premixing nozzle
Pilot nozzle
MHI : G Series Combustor
Combined Cycle Power Plants 3. Combustor 81 / 110
HIoPE
Combined Cycle Power Plants
EV Cone Burner
Alstom DLN Combustor [1/2]
Combined Cycle Power Plants 3. Combustor 82 / 110
HIoPE
Combined Cycle Power Plants
Alstom EV burner consists of an axially split diffusing cone, the two halves offset to form tangential slots.
Combustion air is fed through the slots forming a powerful vortex in the cone.
Gas is injected into the vortex via small holes at the edge of the slots.
Pre-mixing in the cone is followed by combustion at exit where the vortex breaks down, allowing
recirculation and flame stabilization.
As the flame is outside the burner, the burner structure remains relatively cool.
The burner is guaranteed by ABB to give less than 25 ppm NOx with natural gas and 42 ppm with oil firing
and water injection.
EV Cone Burner
Alstom DLN Combustor [2/2]
Combined Cycle Power Plants 3. Combustor 83 / 110
HIoPE
Combined Cycle Power Plants
Auto-ignition is the spontaneous self-ignition of a combustible mixture.
For a given fuel mixture at a particular temperature and pressure, there is a finite time before self-ignition
will occur.
DLN combustors have premix ducts on the head of the combustor to mix the fuel uniformly with air.
To avoid auto-ignition, the residence time of the fuel in the premix duct must be less than the auto-ignition
delay time of the fuel.
Auto-ignition delay times for fuels do exist, but a literature survey will reveal that there is considerable
variability for a given fuel.
Reasons for auto-ignition could be classified as follows: 1) long fuel auto-ignition delay time assumed, 2)
variations in fuel composition, 3) fuel residence time incorrectly calculated, 4) auto-ignition triggered early
by ingestion of combustible particles.
If auto-ignition does occur in the premix duct, then it is probable that the resulting damage will require repair
and/or replacement of parts before the engine is run again at full load.
Problems in DLN Combustors
1. Auto-Ignition
Combined Cycle Power Plants 3. Combustor 84 / 110
HIoPE
Combined Cycle Power Plants
Flashback into a premix duct occurs when the local flame
speed is faster than the velocity of the fuel-air mixture leaving
the premix duct.
Flashback usually happens during unexpected engine
transients, such as compressor surge.
The resultant change of air velocity would almost certainly
result in flashback.
Unfortunately, as soon as the flame-front pressure drop will
cause a reduction in velocity of the mixture through the duct.
This amplifies the effect of the original disturbance, thus
prolonging the occurrence of the flashback.
2. Flashback
Advanced cooling techniques could be offered to
provide some degree of protection during a flashback
event cause by engine surge.
Flame detection systems coupled with fast-acting fuel
control valves could also be designed to minimize the
impact of a flashback.
Thorough mixing is also essential to avoid unsteady
combustion and flashback.
Fairing
Fused Tip
[GE DLN-2 fully faired (flashback resistant) fuel nozzle]
Problems in DLN Combustors
[Damage to fuel nozzles due to flashback]
Combined Cycle Power Plants 3. Combustor 85 / 110
HIoPE
Combined Cycle Power Plants
Combustion instability, called as “rumble”, only used to be a problem with conventional combustors at very
low engine powers.
It was associated with the fuel-lean zones of a combustor where the conditions of burning are less attractive,
and this is a main cause of oscillatory burning.
In a conventional combustor, the heat release from these oscillatory burning was only a significant
percentage of the total combustor heat release at low power conditions.
In DLN combustors, most of the fuel is burned very lean to reduce flame temperature.
Therefore, these lean zones that are prone to oscillatory burning are now present from idle to full load. This
is the reason why resonance usually occur within the combustor.
The pressure amplitude at any given resonant frequency can rapidly buildup and cause failure of the
combustor.
The use of dynamic pressure transducer in the combustor ensures that each combustor can is burning
evenly. This is achieved by controlling the flow in each combustor can until the spectrums obtained from
each combustor can match.
This technique has been used and found to be very effective and ensures combustor stability.
Fundamentally, stable combustion in DLN combustors requires more accurate control of fuel-air ratio in
combustors at all loads.
Many factors affect the combustor flame stability such as changes in fuel composition, heating value, grid
frequency, ambient conditions, operating load transients, and even operator-influenced conditions during
transient operations.
3. Combustion Instability
Problems in DLN Combustors
Combined Cycle Power Plants 3. Combustor 86 / 110
HIoPE
Combined Cycle Power Plants
DLN combustors tend to create harmonics in the combustor that may result in vibration and acoustic noise.
As the firing temperature getting higher, dynamic pressure oscillation activity within the combustor, noise,
has increased; increasing wear and necessitating more frequent maintenance.
In DLN combustors, especially in the lean premix chambers, pressure fluctuations can set up very high
vibrations, leading to major failures.
Multi-fuel-nozzle combustion system has been adopted popularly to reduce the noise from combustor by
many gas turbine manufacturers.
The heat from combustion, pressure fluctuation, and vibration in the compressor may cause cracks in the
liner and nozzle.
The edges of the holes in the liner are of great concern because the holes act as stress concentrators for
any mechanical vibrations and, on rapid temperature fluctuations, high-temperature gradients are formed in
the region of the hole edge, giving rise to a corresponding thermal fatigue.
O&M costs for turbines equipped with DLN combustor can be higher because of a variety of factors,
including replacement of blades and vane due to damage resulting from dynamic pressure pulsation, and
combustor sensitivity to changes in fuel composition.
4. Noise
Problems in DLN Combustors
Damage to a GE 7FA fuel nozzle caused by
combustion dynamic instabilities. The
damage from combustion dynamic
instabilities can easily extend to other high-
temperature components including liners and
transition pieces.
Combined Cycle Power Plants 3. Combustor 87 / 110
HIoPE
Combined Cycle Power Plants
Fuel and Combustion Theory 1
Factors Affecting Combustor Design 2
Combustor Type 3
NOx Formation and Its Control 4
Diffusion Combustor 5
Dry Low NOx Combustor 6
Catalytic Combustor 7
Combustor Cooling 8
Combined Cycle Power Plants 3. Combustor 88 / 110
HIoPE
Combined Cycle Power Plants
Catalytic Combustor
• The fuel and air are injected
separately into the combustion
zone where they mix and react.
• It tend to have flame temperatures
that are typical of stoichiometric
combustion and therefore produce
high NOx emissions.
• Obtaining reasonable emissions
from a diffusion flame combustor,
generally requires the injection of
diluents into the combustion
section to lower the flame
temperature, typically either steam
or water.
• F-class firing temperatures
produce 25 ppm of NOx.
• The fuel and air are premixed
upstream of flame zone.
• This results in significantly lower
flame temperature than the
diffusion flame combustor resulting
in lower NOx emissions without
diluent injection.
• The limitation on low emissions
from the lean premixed
combustion system is the
combustion instabilities which
occur as the lean flammability limit
of the mixture is approached.
• These instabilities can lead to
large pressure fluctuation in the
combustor.
• F-class firing temperature produce
7-9 ppm of NOx.
• The goal of the ATS program was
the development of a high
efficiency, high firing temperature
engine (>1700 K) with NOx
emissions less than 10 ppm for
lean premixed systems and 5 ppm
for the catalytic system.
• It shows promise to achieve lower
emissions because the
combustion instabilities at the lean
flammability limit are no longer a
limiting factor.
• Although catalytic combustion
systems have not yet been
employed in large industrial gas
turbines, results from current
development are encouraging and
emissions in the range of 2-3 ppm
are achievable.
Diffusion Flame Combustor DLN Combustor
Development History of Combustors
Combined Cycle Power Plants 3. Combustor 89 / 110
HIoPE
Combined Cycle Power Plants
Catalysts influence a chemical reaction by changing its mechanism:
Reaction without catalyst: A + B = AB (final product)
Reaction with catalyst: A + K = AK (transient product )
AK + B = AB + K
K – catalyst
Catalyst K is preserved in the chemical reaction.
Catalytic Reactions
Siemens metal ceramic coating
Combined Cycle Power Plants 3. Combustor 90 / 110
HIoPE
NOx Reduction in a Catalytic Combustor
Definition of catalytic agent: “A substance by its mere presence alters the velocity of a reaction, and may be
recovered unaltered in nature or amount at the end of the reaction.” or “Catalysts is a chemical compound
which influence the rate of chemical reaction by lowering its activation energy, i.e. the initial energy
necessary to initiate the chemical reaction.”
A catalyst promotes a chemical reaction, such as fuel with oxygen, but is itself neither consumed nor
produced by the reaction.
There are three basic classes of reactions that one may desire to promote combustion in gas turbines: fuel
preparation such as reforming prior to combustion, fuel oxidation with heat release, and pollutant destruction.
Catalytic combustion normally refers to fuel oxidation with heat release, particularly when the catalyst is
placed within combustor casing.
The primary motivation of the catalytic combustion is to make combustion temperature lower for reduced
NOx emissions.
The presence of a combustion catalyst enables complete combustion at lower temperatures than otherwise
possible. That is, catalytic combustor can operate stably with flame temperatures far below 1525C.
In addition, catalytic combustor offers lower dynamic pressure oscillations.
Most non-catalytic combustors operate with peak flame temperatures higher than 1525C (2780F) to ensure
adequate flame stability and margin flow blowout.
NOx emissions even for perfectly premixed flames at 1525C can exceed 3 ppm.
Although catalytic combustion systems have not yet been employed in large industrial gas turbines, results
from current development are encouraging and emissions in the range of 2-3 ppm are achievable.
Combined Cycle Power Plants 3. Combustor 91 / 110
HIoPE
Combined Cycle Power Plants
Fundamentals of Catalytic Combustors
The requirements for the application of catalytic combustor in a gas turbine are as follows:
• Ignition of the fuel/air mixture at typical compressor outlet temperatures. (if a pilot flame has to be used to
reach the ignition temperature, this can produce a significant amount of thermal NOx.)
• High catalyst activity to maintain complete conversion of fuel into thermal energy.
• Low pressure drop over the catalyst.
• Thermal shock resistance.
• Retention of high specific surface area and catalytic activity under high temperatures of operation.
A single substance cannot fulfill all of these. Therefore, a typical catalytic combustor for gas turbines usually
consists of three main components: the support, the washcoat , and catalyst.
[ Schematic of a monolithic catalyst ]
Combined Cycle Power Plants 3. Combustor 92 / 110
HIoPE
Combined Cycle Power Plants
Main Components for Catalytic Combustion
1. Support
A mechanical support is the base for a high efficiency catalytic combustion system.
In order to minimize the pressure drop over the system, normally a honeycomb structure is used.
Honeycombs give large area to volume ratios, allowing high mass flow with lower pressure drops.
Other requirements of the support are a high thermal shock resistance, low thermal expansion, and
chemically inert to combustion gases.
The monolith material should have a porosity of 30-40% with large pores of a diameter of 5-15 m to obtain
the proper surface for adhesion of a washcoat.
Oxidation is a concern because the support thickness of only 0.01 in.
Combined Cycle Power Plants 3. Combustor 93 / 110
HIoPE
Combined Cycle Power Plants
Main Components for Catalytic Combustion
2. Washcoat and Catalyst
The washcoat is applied onto the surface of the mechanical support to provide a large specific surface area
that has to be maintained at high temperatures.
Thermal expansion of the washcoat must not differ much from the support material to avoid separation from
support during combustion.
The active metal catalyst can be platinum (Pt), palladium (Pd), rhodium (Rh) or mixture of these compounds.
The activity of catalysts for gas turbine combustors should also be stable and last for at least one year of
operation without problems.
Pd is the most commonly used catalytic combustion due to its enhanced thermal stability compared to Pt
and its high reactivity for CH4 combustion.
At temperatures below about 970 K, Pd is present as PdO. As the temperature increases, a reversible
reduction to metallic Pd takes place, resulting in a decrease of activity. As the temperature increases further,
the activity of metallic Pd exceeds that of PdO.
Pt has a higher activity for CO and saturated hydrocarbons.
However, Pd and Pt have problems in terms of sintering (loss of active surface area) and evaporation at
high temperatures resulting in a deactivation of the catalyst. This is a main obstacle in the development of
catalytic combustor. Additionally, these two materials are expensive noble metals.
Combined Cycle Power Plants 3. Combustor 94 / 110
HIoPE
Combined Cycle Power Plants
Air
Air
Fuel Gas-Phase
Burnout
Fuel
Fuel
Gas-Phase
Burnout
Air
Air
Fuel
Gas-Phase
Burnout
Air
Air
Fuel
Secondary fuel/air
Secondary fuel/air
Air
Air
Fuel
Premixer Catalytic Reactor
Type of Catalytic Combustors
(e) Rich catalytic lean
burn Gas-Phase
Burnout
Air
Air
Fuel + Air Premixer Catalytic Reactor
Air cooled catalyst
(d) Hybrid
combustion with
secondary fuel/air
(c) Hybrid combustion,
full burn-out
downstream of the
catalysts
(b) Hybrid combustion
with secondary fuel
(a) Fully catalytic
combustion by
multiple segments
Combined Cycle Power Plants 3. Combustor 95 / 110
HIoPE
Combined Cycle Power Plants
Type of Catalytic Combustors
1. Fully catalytic combustion by multiple segments
The total premixed fuel/air stream is oxidized by a set of catalyst segments.
The reaction should be completed (99.9% combustion efficiency) within the catalyst bed. Therefore, there is
no need to separate the gas-phase combustion zone from the catalyst.
Thus, the temperature just downstream of the last segment is same as the turbine inlet temperature.
The advantage of this type of combustor is its simplicity as no secondary fuel or air has to be mixed in and
no flame has to be anchored.
However, the very high temperatures in the final segments as well as the difficulty of controlling the heat
release in the first segments will probably make this design difficult for most gas turbine applications.
Normally, highly active noble metal catalysts have been used in the first segments in order to initiate the
oxidation at a low inlet temperature. Therefore, the implementation of a pilot flame for start-up procedure is
not necessary.
The difficulty of finding suitable materials maintaining high catalytic activity and thermal stability under
prolonged exposure time above 1300C has yet to be solved.
Metal substrates are more suitable than ceramic ones for gas turbine applications because they are able to
withstand gas turbine demands such as thermal stress and thermal shock.
However, metal temperatures must normally by limited to less than about 950C (1750F) for long durability.
Air
Air
Fuel
Premixer Catalytic Reactor
(a) Fully catalytic combustion by multiple segments
Combined Cycle Power Plants 3. Combustor 96 / 110
HIoPE
Combined Cycle Power Plants
Type of Catalytic Combustors
2. Hybrid combustion with secondary fuel
Most of the fuel passes through the catalyst segments but some of the fuel is mixed downstream of the last
catalyst segment and is burnt in a homogeneous reaction zone downstream catalysts.
This design is supposed to keep the temperature of the catalyst segments below 1000C.
The catalyst will work as a preheater increasing the temperature to a level where ultra-lean combustion may
take place.
Hence, the flame limits could be extended to fuel-air mixtures yielding temperatures well below the ones
needed for the formation of thermal NOx.
Air
Air
Fuel Gas-Phase
Burnout
Fuel
Fuel Premixer Catalytic Reactor
(b) Hybrid combustion with secondary fuel
Combined Cycle Power Plants 3. Combustor 97 / 110
HIoPE
Combined Cycle Power Plants
Type of Catalytic Combustors
3. Hybrid combustion using inactive channels
All of the premixed fuel/air enter the first segment.
Selected number of channels of the monolith support have not been coated with catalysts.
The unburnt fuel passing through the inactive channels is oxidized downstream of the last segment in a
homogenous reaction zone.
This design has two advantages. One is that there is no need for a secondary mixing zone after the last
catalyst segment. The other is that the unreacted gas in the inactive channels will cool the active channels
and thereby limit the temperature of the catalysts.
In this case, combustor outlet temperatures of up to 1400C and at the same time keeping the catalyst
temperature below 1000C were demonstrated by GE.
Clearly, this design has the advantage of reducing the operating temperature of the catalyst, thus increasing
the lifetime of the catalyst.
Gas-Phase
Burnout
Air
Air
Fuel
Premixer Catalytic Reactor
(c) Hybrid combustion, full burn-out downstream of the catalysts
Combined Cycle Power Plants 3. Combustor 98 / 110
HIoPE
Combined Cycle Power Plants
Type of Catalytic Combustors
4. Hybrid combustion using secondary fuel/air
Secondary fuel/air is injected downstream of the last catalyst segment.
The disadvantage of such a design is the difficulty of achieving a homogeneous mixture of fuel and air in
the post-catalytic reaction zone.
Advantage is the catalyst temperature can keep low enough to avoid deterioration.
It has been demonstrated that the catalyst bed temperature could be kept between 700 and 800C with the
ignition temperature being 360C. Combustor outlet temperature as high as 1390C at 13 bar pressure
realized.
A Pt/Pd/Rh-based cordierite honeycomb catalyst has been used in the experimental work and NOx level
below 5 ppm were measured.
Gas-Phase
Burnout
Air
Air
Fuel
Secondary fuel/air
Secondary fuel/air
Premixer Catalytic Reactor
(d) Hybrid combustion with secondary fuel/air
Combined Cycle Power Plants 3. Combustor 99 / 110
HIoPE
Combined Cycle Power Plants
Type of Catalytic Combustors
5. Rich catalytic lean burn [1/2]
All the above-mentioned designs are based on lean premixed combustor design.
The inlet air flow to the catalyst is separated into two streams, and a portion of the air is mixed with the fuel
and reacts on the surface of the catalyst under fuel rich conditions.
The remaining air is used to cool the backside of the catalyst.
The two streams mix at the catalyst exit and then react and burnout in the homogeneous reaction zone.
By operating the catalyst in the fuel rich region, the reaction rate is limited by the rate of diffusion of oxygen
to the catalyst surface.
Therefore, RCL design is able to tolerate wider variations in fuel-air ratio within the catalyst region than the
LCL design.
RLC does not require the preburner, because the fuel and air react at compressor discharge temperature of
typical gas turbines.
The choice of catalyst is critical for RCL in order to insure proper catalyst lightoff *.
(e) Rich catalytic lean burn
Gas-Phase
Burnout
Air
Air
Fuel + Air Premixer Catalytic Reactor
Air cooled catalyst
* Lightoff is defined as the temperature at which the catalyst surface initially becomes active.
Combined Cycle Power Plants 3. Combustor 100 / 110
HIoPE
Combined Cycle Power Plants
Rich catalytic module
Type of Catalytic Combustors
5. Rich catalytic lean burn [2/2]
[ Rich catalytic lean burn ] [ Lean catalytic lean burn ]
Combined Cycle Power Plants 3. Combustor 101 / 110
HIoPE
Combined Cycle Power Plants
High Temperature Catalytic Combustors
In the high firing temperature gas turbines, such as FB-class and H-class GTs, gas-phase combustion
temperatures may need to exceed 1525C (2780F), before addition of cooling air, in order to meet required
TIT.
At the current level of firing temperature and catalysts development, NOx emissions will exceed 3 ppm at
15% O2.
However, it has been reported that catalytic combustors have low combustion dynamics, because gas-
phase energy release in the combustor is the driving force for combustion-induced pressure oscillations
(combustion dynamics) and these oscillations are reduced when a portion of the fuel is catalytically reacted
prior to gas-phase combustion.
Regardless of pollutant emission levels, however, catalytic combustion may prove useful even when
temperatures must be well in excess of 1525C (2780F).
In fact, combustion dynamics often become most problematic at high flame temperatures and a solution is
most needed.
In addition, non-catalytic premixed combustors employ piloting or fuel staging to improve combustion
dynamics.
Thus, a catalytic combustor with low combustion noise without piloting or fuel staging may offer reduced
NOx emissions as compared to an equivalent non-catalytic system.
Combined Cycle Power Plants 3. Combustor 102 / 110
HIoPE
Combined Cycle Power Plants
Catalytic combustor in the 501D5
Catalytic combustor in the SGT6-5000F
Catalytic Combustor
Combined Cycle Power Plants 3. Combustor 103 / 110
HIoPE
Combined Cycle Power Plants
Lean Catalytic Lean Burn (LCL) Design
All of the fuel and air are premixed and
enter catalyst section under fuel lean
conditions.
At the end of the catalyst section any fuel
not reacted is burned out in a reaction zone.
To insure proper catalyst activity, the inlet
temperature of fuel-air mixture to the
catalyst of approximately 500C. Since this
temperature is higher than the compressor
discharge temperature of a typical gas
turbine, a preburner will be necessary.
Operation of the catalyst in the lean region
requires very close control of the fuel-air
ratio in the vicinity of the catalyst to avoid
high reaction rates and excessive catalyst
temperatures.
This technology has been commercially
operated on a small gas turbine, Kawasaki
1.5 MW, and has been studied by GE and
Siemens on large gas turbines.
Combined Cycle Power Plants 3. Combustor 104 / 110
HIoPE
Combined Cycle Power Plants
Fuel and Combustion Theory 1
Factors Affecting Combustor Design 2
Combustor Type 3
NOx Formation and Its Control 4
Diffusion Combustor 5
Dry Low NOx Combustor 6
Catalytic Combustor 7
Combustor Cooling 8
Combined Cycle Power Plants 3. Combustor 105 / 110
HIoPE
Combined Cycle Power Plants
In early gas turbine engines
25~30% : used for combustion
70~75% : used for cooling
In the modern engines
45% : used for combustion
35% : used for cooling the
combustor
20% : used for cooling the turbine
By using more air to support combustion, the
thermal efficiency of the engine is improved
and the size of the engine for a given output is
reduced.
Use of Air in a Combustor
Compressor
Fuel
Turbine
Air
Power
Exhaust NOx ~
25 ppm 350C
Bypass Air
1800C 1300C
Combined Cycle Power Plants 3. Combustor 106 / 110
HIoPE
Combined Cycle Power Plants
Film Cooling [1/2]
The liner is exposed to a high temperature because of heat radiated by the flame and combustion.
To extend the life of the liner, it is necessary to lower the temperature of the liner and use a material having a
high resistance to thermal stress and fatigue.
The air film cooling method reduces the temperature of the liner.
This reduction is accomplished by fastening a metal ring inside the liner to leave a definite annular clearance.
Air is admitted into this clearance space through rows of small holes in the liner and impingement cooling is
done at this stage, and the air is directed by the metal rings as a film of cooling air along the liner inside.
Combined Cycle Power Plants 3. Combustor 107 / 110
HIoPE
Combined Cycle Power Plants
Air film flow prevent carbon from forming on the inside of the liner. Carbon deposits
can cause hot spots or block cooling air passages.
Liner Types
Film Cooling [2/2]
Combined Cycle Power Plants 3. Combustor 108 / 110
HIoPE
Combined Cycle Power Plants
Thermal Barrier Coating
Modern combustors also make extensive use of thermal barrier
coatings to further insulate the metal from the extreme gas
temperatures.
TBC is now standard on most high-performance gas turbines.
The thickness of coating layer is 0.4~0.6 mm and can reduce
metal temperatures by 50~150C on the basis coating material of
ZrO2-Y2O3. (cooling temperature is about 4~9C per mil of coating
layer thickness)
TBC consists of two layers. The first layer is a bond coat of
NICrAlY and the second is a top coat of YTTRIA-stabilized
zirconia.
The purpose of the TBC is to increase the thermal efficiency of the
gas turbine through reduced cooling air and maintaining higher
gas temperature.
The purpose of the bond coat is to insulate oxide.
Hot gases
Thermal Barrier Coating
Bond Coat
Base
Material
Cooling gases
1400C 1200 1000
Combined Cycle Power Plants 3. Combustor 109 / 110
HIoPE
Combined Cycle Power Plants
Steam Cooling
(Supply)
Steam
(Return)
(Return) Bypass valve
Premixing nozzle
Pilot nozzle
Combined Cycle Power Plants 3. Combustor 110 / 110
HIoPE
Combined Cycle Power Plants
질의 및 응답
작성자: 이 병 은 (공학박사) 작성일: 2015.02.11 (Ver.5) 연락처: [email protected]
Mobile: 010-3122-2262 저서: 실무 발전설비 열역학/증기터빈 열유체기술