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Coal Gasification 101
Dr. Jeff [email protected]
2© 2005 Electric Power Research Institute, Inc. All rights reserved.
Outline
• What is coal?• What is coal gasification?• What can you do with it?• Gasification-based power plants compared to other fossil
fuel power generation options• A few words on CO2 capture
3© 2005 Electric Power Research Institute, Inc. All rights reserved.
U.S. Forecasts Largest Coal Generation Capacity Installation in 40 Years
0123456789
1011121314151617181920
1940 1945 1950 1955 1960 1965 1970 1975 1980 1985 1990 1995 2000 2005 2010 2015 2020 2025Source: U.S. Department of Energy NETL & Annual Energy Outlook 2005.
Cap
acity
Add
ed (G
Ws) Capacity Addition
Levels Not Seen in 40 Years
Industry Growth Trend Not Seen in
50 Years
20 YearMarket Trough
U.S. Coal Capacity Additions, 1940 U.S. Coal Capacity Additions, 1940 –– 20252025
4© 2005 Electric Power Research Institute, Inc. All rights reserved.
Carbon
Ash (rock)
Sulfur
Nitrogen
Hydrogen
Mercury
Water
5© 2005 Electric Power Research Institute, Inc. All rights reserved.
U.S. Coal Basins
6© 2005 Electric Power Research Institute, Inc. All rights reserved.
Typical U.S. Coal Analysis(Coal Properties Differ Markedly)
Pittsburgh #8 Illinois #6 Wyoming ND Lignite
Ultimate AnalysisMoisture 5.2 12.2 30.24 26.80Carbon 73.8 61.0 48.18 45.82Hydrogen 4.9 4.25 3.31 3.11Nitrogen 1.4 1.25 0.70 0.70Chlorine 0.07 0.07 0.01 N/ASulfur 2.13 3.28 0.37 0.69Oxygen 5.4 11.0 11.87 14.68Ash 7.1 6.95 5.32 8.20
Higher Heating Value-as Received(Btu/lb) 13,260 10,982 8,340 7,810
7© 2005 Electric Power Research Institute, Inc. All rights reserved.
What happens when coal burns?
• Carbon => CO2 (carbon dioxide)• Ash => flyash• Sulfur => SO2, SO3 (SOx)• Nitrogen => N2 and NOx• Hydrogen => H2O• Mercury => Hg, HgCl2• Water => water vapor (H2O)
8© 2005 Electric Power Research Institute, Inc. All rights reserved.
What is gasification?
• Similar to combustion (burning) but with less than half the amount of oxygen needed to fully burn the coal
• Combustion: excess air• Gasification: excess fuel (by a lot!!)
9© 2005 Electric Power Research Institute, Inc. All rights reserved.
Combustion & Gasification Products
10© 2005 Electric Power Research Institute, Inc. All rights reserved.
11© 2005 Electric Power Research Institute, Inc. All rights reserved.
12© 2005 Electric Power Research Institute, Inc. All rights reserved.
13© 2005 Electric Power Research Institute, Inc. All rights reserved.
14© 2005 Electric Power Research Institute, Inc. All rights reserved.
Combustion vs Gasification
• H2S & COS are easily removed from syngas and converted to solid sulfur or sulfuric acid
• NH3 washes out of gas with water, thermal NOx controlled by diluent injection in GT
• Ash is converted to glassy slag which is inert and usable
• >90% of Hg removed by passing high pressure syngas thru activated carbon bed
• SO2 & SO3 is scrubbed out of stack gas – reacted with lime to form gypsum
• NOx controlled with low NOx burners and catalytic conversion (SCR)
• Large volume of flyash & sludge
• Hg can be removed by contacting flue gas with activated carbon
15© 2005 Electric Power Research Institute, Inc. All rights reserved.
16© 2005 Electric Power Research Institute, Inc. All rights reserved.
Dakota Gasification Gasifier
• The dry ash (non-slagging) Lurgi gasifier is used in Dakota Gasification’s lignite-to-natural gas plant
• The Lurgi process was developed in the 1930s, and was the only “mature” gasification process available when the Dakota project was initiated (circa 1980)
• The Lurgi process operates at relatively low temperature and has some undesirable characteristics– Cannot handle coal fines, produces tars & phenols as
well as syngas, bottom ash instead of slag• Since 1980 several “second generation” gasification
processes have been developed which avoid some of the Lurgi process’ undesirable characteristics
17© 2005 Electric Power Research Institute, Inc. All rights reserved.
The 3 Major Types of Gasification Processes
1. Moving-Bed Gasifier(e.g., Lurgi)
2. Fluidized-Bed Gasifier (e.g., KBR/Southern)
3. Entrained-Flow Gasifier (e.g., GE Energy, ConocoPhillips, Shell, Siemens)
18© 2005 Electric Power Research Institute, Inc. All rights reserved.
What can you do with coal gasification?
• Produce Electricity– In a Gas Turbine-based Combined Cycle power plant– Emissions approaching that of a natural gas fired power plant
• Make Fuels– Sasol has been making gasoline from coal since the 1950s in
Republic of South Africa – Dakota Gasification has been making “synthetic’ natural gas from
lignite since the 1980s• Make Chemicals
– Eastman Chemicals has been doing this since 1980s• Make Fertilizer
– Coffeyville Resources in Kansas makes ammonia-based fertilizer from petroleum coke
19© 2005 Electric Power Research Institute, Inc. All rights reserved.
20© 2005 Electric Power Research Institute, Inc. All rights reserved.
Steam Cycles vs “Combined” Cycles
• Steam Cycles have – a boiler – a steam turbine
• Referred to as “Rankine” cycle, fossil boiler, “fossil steam” plant, “conventional coal” plant
• Combined Cycles (the “CC” in IGCC) have – a Gas Turbine – a “heat recovery steam generator” (HRSG)– a steam turbine
21© 2005 Electric Power Research Institute, Inc. All rights reserved.
Conventional Coal Plant
100 MW
14 MW
86 MW
41 MW
45 MW
41 % Efficiency (LHV basis)
22© 2005 Electric Power Research Institute, Inc. All rights reserved.
Gas Turbine
Photo source: Siemens
23© 2005 Electric Power Research Institute, Inc. All rights reserved.
Gas Turbine “simple cycle”
100 MW
38 MW
62 MW
38% Efficiency (LHV basis)
24© 2005 Electric Power Research Institute, Inc. All rights reserved.
Combined Cycle
100 MW
Fuel
38 MW19 MW
62 MW
22 MW
21 MW to condenser
40 MW
19 + 38 = 57 MW 57% Efficiency! (LHV basis)
25© 2005 Electric Power Research Institute, Inc. All rights reserved.
15MW 79MW
30MW49MW
47MW21MW
9MW
Net Coal to Power: 30 + 21 – 9 = 42% (LHV basis)
17MW
100MW
IGCC schematic from US DOE26 MW
26© 2005 Electric Power Research Institute, Inc. All rights reserved.
Comparison to other fossil fuel power generation options
• Emissions• Greenhouse gases• Cost of Electricity
27© 2005 Electric Power Research Institute, Inc. All rights reserved.
Emissions Comparison – State-of-the-Art Coal Combustion, IGCC, and NGCC Values represent technology capability, not permit levels
0.0
0.1
0.2
0.3
0.4
0.5
0.6
0.7
0.8
NGCC+SCR
IGCC+S
CR
IGCC
SCPC+SCR
SCPC+SCR
lb/M
W-h
r
NOxSO2PM
PRB
Bituminous
28© 2005 Electric Power Research Institute, Inc. All rights reserved.
Emissions Comparison with Older Coal Plants and Federal Standards
250 US plants exceeded these levels in 2004
0
2
4
6
8
10
12
14
16
18
NGCC+SCR
IGCC+S
CR
IGCC
SCPC+SCR
SCPC+SCR
2006
NSPS
PC-old
lb/M
W-h
r
NOxSO2PM
29© 2005 Electric Power Research Institute, Inc. All rights reserved.
Solid Waste Comparison(Based on nominal 500 MW plant size)
0
50
100
150
200
250
300
350
400
450
PC-Sub
PC-USC
CFB IGCC PC-Sub
PC-USC
CFB IGCC PC-Sub
PC-USC
CFB IGCC PC-Sub
PC-USC
CFB IGCC
Solid
Was
te, l
b/M
Wh
SulfurSpent SorbentAsh/Slag
Pittsburgh #8 Illinois #6 TX LigniteWyoming PRB
30© 2005 Electric Power Research Institute, Inc. All rights reserved.
Makeup Water Comparison
0
1
2
3
4
5
6
7
8
9
10
PC CFB IGCC
Mak
eup
Wat
er, g
pm/M
W
31© 2005 Electric Power Research Institute, Inc. All rights reserved.
Atmospheric CO2 Trends
Source: CSIRO Atmospheric Research,
www.cmar.csiro.au
Peak of last Ice Age - 20,000 yrs ago
33© 2005 Electric Power Research Institute, Inc. All rights reserved.
CO2 Emissions without CO2 Capture
0
200
400
600
800
1,000
1,200
PC-Sub PC-Super PC-Ultra NGCC IGCC PC-old
CO
2 E
mis
sion
s (k
g/M
W-h
r)
34© 2005 Electric Power Research Institute, Inc. All rights reserved.
IGCC with CO2 Removal and OptionalHydrogen Co-Production
O2 N2
Air
BFW
BFWSteam
Steam Turbine
HRSG
CoalPrep
Gas CoolingGasificationC + H2O = CO + H2
Sulfur and CO2
Removal
Air Separation
Unit
GasTurbine
Air
Hydrogen
CO2 to use or sequestrationSulfur
ShiftCO+ H2O = CO2 + H2
35© 2005 Electric Power Research Institute, Inc. All rights reserved.
FutureGen Project
• A 275 MW (nominal) IGCC with CO2 capture and H2export– Coal gasification followed by water-gas shift reaction– 90% of CO2 will be removed from syngas,
compressed to circa 2000 psia and injected into deep geologic formations for sequestration
– Remaining syngas will be primarily H2• Small slipstream will upgraded to high purity H2 and sold
“over the fence”• Balance will be fired in an advanced combined cycle
• Site selection RFP issued in March 2006• Operation targeted to begin in 2012
36© 2005 Electric Power Research Institute, Inc. All rights reserved.
Pulverized Coal (PC) with CO2 Removal
CO2 to useor SequestrationFresh Water
PCBoiler SCR
SteamTurbine
CO2Removal
MEA
Coal Flue Gasto StackESP FGDAir
Fly Ash Gypsum/Waste
37© 2005 Electric Power Research Institute, Inc. All rights reserved.
CO2 Capture Comparison
Exhaust or Syngas
Pressure
CO2 Volumetric Concentration
CO2 Partial Pressure
Natural Gas Combined Cycle Exhaust
14.7 psia 4% 0.6 psia
Supercritical Coal Boiler Exhaust
14.7 psia 13% 1.9 psia
IGCC Syngas 825 psia 40% 330 psia
38© 2005 Electric Power Research Institute, Inc. All rights reserved.
Impact of CO2 CaptureResults from recent IEA & US DOE studies on bituminous coal adjusted to standard EPRI economic inputs, $2/MMBtu coal, 85% capacity factor, 2005 USD
49.6 52.045.7 46.1
11.6
16.321.3 19.0
0
10
20
30
40
50
60
70
80
GE IGCC Shell IGCC SCPC-IEA SCPC-DOE
30-y
ear L
evel
ized
Cos
t of E
lect
ricity
, $/M
Whr
Delta for CaptureWithout Capture
Range of Uncertainty
Range of Uncertainty
(Excludes cost of emission
allowances and CO2 pipeline to
sequestration site)
The End