Gasification - Versatile Solutions
Gasification Technologies Overview
NASEO 2006 Annual Meeting Seattle, WA September 10-13, 2006
Gary J. Stiegel - Gasification Technology Manager National Energy Technology Laboratory
Why the Interest in Gasification? • Continuing high price of fuels − Natural gas for home heating and industrial uses − Highway transportation fuels (gasoline and diesel) • Excellent environmental performance of IGCCs for
power generation • Growing environmental community view of IGCCs as
best technology option for coal systems • Gasification is baseline technology for H2, SNG, fuels
from coal and capture of CO2 for sequestration • Consolidation of IGCC development companies • Uncertainty of carbon management requirements and
potential suitability of IGCC for CO2 controls Descriptor - include initials, /org#/date
History of Gasification Town Gas Town gas, a gaseous product manufactured from coal, supplies lighting and heating for America and Europe. Town gas is approximately 50% hydrogen, with the rest comprised of mostly methane and carbon dioxide, with 3% to 6% carbon monoxide. • First practical use of town gas in modern times was for
street lighting • The first public street lighting with gas took place in Pall Mall, London on January 28, 1807 • Baltimore, Maryland began
the first commercial gas lighting of residences, streets, and businesses in 1816 Descriptor - include initials, /org#/date
What is Gasification? Oxygen
Coal
Extreme Conditions: 1,000 psig or more 2,600 Deg F Corrosive slag and H2S gas Products (syngas) CO (Carbon Monoxide) H2 (Hydrogen) [CO/H2 ratio can be adjusted]
By-products H2S (Hydrogen Sulfide) CO2 (Carbon Dioxide) Slag (Minerals from Coal)
Gas Clean-Up Before Product Use
Water Descriptor - include initials, /org#/date
So what can you do with CO and H2 ?
Building Blocks for Chemical Industry
Clean Electricity
Transportation Fuels (Hydrogen) Descriptor - include initials, /org#/date
Chemicals from Coal - Final Products
It is likely you have recently used a product based on coal gasification.
Coal
Acetic Anhydride Acetic Acid
Descriptor - include initials, /org#/date
Comparison of Combustion and Gasification
Descriptor - include initials, /org#/date
Fundamental Comparison of IGCC with Advanced PC-Fired Plant • • • • • • • • •
IGCC Operating Principles Partial oxidation Fuel Oxidant Oxygen or Air Pressure 400-1000 psi Sulfur Control Concentrate gas Nitrogen Control Not needed Ash Control Low Vol slag Trace Elements Slag Capture Wastes/Byproducts Several Markets Performance -- eff. (%) 40-44
PC Full Oxidation Air Atmospheric Dilute gas Pre/post combustion Fly/bottom ash ESP/Stack Limited Markets 35-41
Descriptor - include initials, /org#/date
Gasification Chemistry Gasification with Oxygen C + 1/2 O2 CO
Coal
Combustion with Oxygen CO2 C + O2 Gasification with Carbon Dioxide C + CO2 2CO
Oxygen
Gasification with Steam CO + H2 C + H2 O Gasification with Hydrogen C + 2H2 CH4
Steam
Water-Gas Shift CO + H2O H2 + CO2
Gasifier Gas Composition (Vol %) H2 CO CO2 H2 O CH4
25 - 30 30 - 60 5 - 15 2 - 30 0-5
0.2 - 1 H2 S COS 0 - 0.1 N2 0.5 - 4 Ar 0.2 - 1 NH3 + HCN 0 -0.3 Ash/Slag/PM
Methanation CO + 3H2 CH4 + H2O Descriptor - include initials, /org#/date
Combustion Chemistry
Coal
Combustion with Oxygen C + O2
Air
1/ 2
O2 + H2
Combustion Gas Composition (Vol %)
CO2
H2O
CO2 H2 O SO2 N2 O2
13.5 9.8 0.4 73.2 3.2
Ash/Slag/PM
Descriptor - include initials, /org#/date
Gasification Phase Diagram – An Example CH4
H2S
Complete Combustion
SO2
Gasification Zone
100%
O2
90% 80% 70%
Mole %
H2O
H2
60%
C
50%
CO2
40% 30%
CO
20% 10% 0% 0.1
0.7
1.3
1.9
2.5
3.1
O2/MAF Coal Feed
Coal: Illinois #6, Dry Feed Descriptor - include initials, /org#/date
Integrated Gasification Combined Cycle (IGCC)
Descriptor - include initials, /org#/date
Gasification-Based Energy Production System Concepts
Sulfur Sulfur By-Product By-Product Fly Fly Ash Ash By-Product By-Product
Slag Slag By-Product By-Product
Descriptor - include initials, /org#/date
Conventional Coal Plant (Illustration only)
40 % Efficiency
15 MW
85 MW 40 MW
100 MW
45 MW Descriptor - include initials, /org#/date
Combined Cycle (Illustration only) 22 MW
100 MW Fuel
40 MW 62 MW 38 MW
19 MW
21 MW to condenser
19 + 38 = 57 MW 57% Efficiency! Descriptor - include initials, /org#/date
Coal-Based IGCC Power Plant
Gasification Island •Converts coal to synthesis gas •Synthesis gas cleaned and conditioned
Natural gas is replaced by coal-based fuel gas
Descriptor - include initials, /org#/date
Coal-Based IGCC Power Plant (Illustration only) 100MW Net Coal to Power: 30 + 22 – 9 = 43%
9MW
18MW 15MW 50MW
22MW
80MW 30MW
47MW Descriptor - include initials, /org#/date
Polk
Wabash
Gasification Buggenum
A Commercial Reality
Sarlux
Descriptor - include initials, /org#/date
Commercial-Scale Coal IGCC Power Plants • U.S. − Southern California Edison's 100 MWe Cool Water Coal Gasification Plant (1984-1988) − Dow Chemical's 160 MWe Louisiana Gasification Technology Inc (LGTI) Project (1987-1995) − PSI Energy's (now Cinergy) 262 MWe Wabash River Generating Station (1995 - present) − Tampa Electric's 250 MWe Polk Power Station (1996-present) • Foreign − NUON/Demkolec’s 253 MWe Buggenum Plant (1994-present) − ELCOGAS 298 MWe Puertollano Plant (1998present) Descriptor - include initials, /org#/date
Cumulative Worldwide Gasification Capacity and Growth MWth Syngas 80,000
Planned Planned Operating Operating
70,000 60,000 50,000 40,000 30,000 20,000 10,000 0 1970
1975
1980
1985
1990
1995
2000
2005
2010
Descriptor - include initials, /org#/date
Gasification by Primary Feedstock 35,000
Planned Operating
MWth Syngas
30,000 25,000 20,000 15,000 10,000 5,000 0 Coal
Petroleum
Gas
Petcoke
Biomass/Waste Descriptor - include initials, /org#/date
Gasification by Product 30,000
Planned
MWth Syngas
25,000
Operating
20,000
15,000 10,000 5,000 0 FT liquids
Chemicals
Power
Gaseous fuels
Not specified
Descriptor - include initials, /org#/date
Summary of Gasification Projects • 160 commercial projects -- in operation/ • • • •
constructions/design 450 gasifier vessels in 28 countries 68,000 MW thermal energy 430 million normal cubic meter per day of syngas 770,000 barrels of oil equivalent energy per day
Descriptor - include initials, /org#/date
Environmental Benefits
Descriptor - include initials, /org#/date
Wabash River Clean Coal Project A Case Study for Cleaner Air 3.1
Emissions, Pounds per Million BTUs
3
2
SO2 The Wabash River Plant in Terre Haute, Indiana, was repowered with gasification technology
1
0.8 0.1
0
BEFORE AFTER CCT CCT
NOx 0.15
BEFORE AFTER CCT CCT Descriptor - include initials, /org#/date
Tampa Electric (TECO) Clean Coal Project A Case Study for Cleaner Air Emissions (Pounds per Million Btus)
2.5 2.07
2.0
SO
1.5
2
1.2
0.6 to 1.2
TECO’s coal-to-gas plant in Polk County, FL, is the pioneer of a new type of clean coal plant.
1.0
NOx 0.47
0.5
0.07 (15ppm)
0.1
0
Older Coal Plant
Fleet Avg.
TECO CCT Plant
Older Coal Plant
Fleet Avg.
TECO CCT Plant Descriptor - include initials, /org#/date
Comparison of Environmental Factors Pulverized Coal-Fired, NGCC, and IGCC Plants Without CO2 Capture 2.2 2.0
= GEE Radiant IGCC = E-Gas IGCC
1.8
= Shell IGCC
1.6
= SubCritical PC
1.4
= SuperCritical PC = NGCC
1.2 1.0 0.8 0.6 0.4 0.2 0.0
SO2 (lb/MWh)
NOx (lb/MWh)
Particulates (lb/MWh)
CO2 (lb/1000 MWh)
* Based on Study for DOE : “Cost and Performance Comparison of Fossil Energy Power Plants” Descriptor - include initials, /org#/date
Comparison of Water Consumption for Various Fossil Plants
Gallons per MWh
1,400
Cooling Tower Losses
1,200
Flue Gas Losses
1,000
Process Losses
800 600 400 200 0 E-Gas
Shell
GE R-C
GE NGCC PC Sub PC Quench Super
Note:
Cooling water requirements are estimated for generic eastern site Descriptor - include initials, /org#/date
Coal-Fired Power Plant Emissions – Recent Permits SCPC7 WePower
PC5 Prairie State
CFB6 Indeck
IGCC1 WePower
IGCC2 Wabash
SO2
0.15
0.18
0.15
0.03
0.1333
NOx
0.07
0.08
0.08
0.03
0.103
VOC
0.004
0.004
0.004
0.004
0.002
CO
0.12
0.12
0.11
0.03
0.045
PM/PM10
0.018
0.015
0.015
0.011
0.011
Hg (lb/1012Btu)
1.12
~2
4.0
0.5
3.244
(lb/106Btu)
1. WePower SCPC and IGCC information from April 2003 Draft Environmental Impact Statement, Elm Road Generating Station, Volume 1, Public Service Commission of Wisconsin & Department of Natural Resources, Table 7-11, p. 157 (Pittsburgh 8 coal) 2. Wabash River Repowering Project, 1997 and 1998 average reported to IDNR, including fuel oil (Illinois 6 coal) 3. Wabash River has demonstrated 0.03 lb/MMBtu SOx, but operates nearer the 0.20 lb/MMBtu permit for economic reasons 4. Electric Utility Steam Generating Unit Mercury Test Program, USEPA, October 1999 (no controls) 5. “Project Summary for a Construction Permit Application from the Prairie State Generating Company, LLC”, Illinois Environmental Protection Agency. BOILER STACK ONLY 6. “Supplemental Information for Air Permit Application”, March 25, 2003,EarthtechInc. 7. “Analysis and Preliminary Determination for the construction and Operation Permits for the proposed Construction of an Electric Generation Facility for Elm Road Generating Station”, October 2, 2003, Wisconsin Department of Natural Resources
Descriptor - include initials, /org#/date
Source: ConocoPhillips
IGCC IGCC without with Mercury Removal CONDENSER
and with it
ACID GAS REMOVAL
COAL SLURRY OXYGEN COS HYDROLYSIS
BFW
WATER SYNGAS COOLER
MERCURY REMOVAL
AIR GAS TUBINE
HP STEAM
BFW
PARTICULATE REMOVAL HRSG FINES SLAG
STEAM TURBINE
Descriptor - include initials, /org#/date
Mercury Removal System Performance and Cost • Remove greater than 90% of mercury • Stable adsorption of mercury in carbon beds as
mercury sulfide • Incremental capital costs of $3.34 / kW for carbonbed removal system • Incremental cost of electricity of $0.254 / MWh for O&M and capital repayment − <0.6% COE from IGCC plant of $44 / MWh − Estimated cost of mercury removal in IGCC compares favorably (<10%) to costs of 90% removal in conventional PC power plant
Estimates for IGCC reference plant based on Tampa Electric Gasification Plant with GE Energy gasifier and sized to 287-MWe net Descriptor - include initials, /org#/date
Gasification Technology Workshops State Economic/Environmental Regulators • DOE in cooperation with the Gasification Technologies Council
(GTC), NARUC, and SSEB conducts Workshops to:
− Educate federal, state, and local environmental/economic regulators on the environmental benefits of gasification • Expanding to include state legislators/energy officials − Improve communication between the industry and regulators • Eight workshops have already been held throughout the country
− Next workshops scheduled for March 2007 (Denver) and June 2007 (Indianapolis) • Last workshop in Bismarck, ND (June 2006)
− 150 attendees; 50% of states represented; 8 state legislators • All travel expenses for State and Local Officials are reimbursed
in entirety
NASEO is invited to participate Descriptor - include initials, /org#/date
…the Benefits GASIFICATION − Stable, affordable, high-efficiency energy supply with a minimal environmental impact − Feedstock Flexibility/Product Flexibility − Flexible applications for new power generation, as well as for repowering older coal-fired plants BIG PICTURE − Energy Security - -Maintain coal as a significant component in the US energy mix − A Cleaner Environment (reduced emissions of pollutants) •
The most economical technology for CO2 capture
− Ultra-clean Liquids from Coal -- Early Source of Hydrogen
Descriptor - include initials, /org#/date
Visit NETL Gasification Website www.netl.doe.gov/technologies/coalpower/gasification/index.html
Descriptor - include initials, /org#/date
Comparison of Environmental Factors Pulverized Coal-Fired, NGCC, and IGCC Plants With CO2 Capture 2.2 2.0
= GEE Radiant IGCC = E-Gas IGCC
1.8
= Shell IGCC
1.6
= SubCritical PC
1.4
= SuperCritical PC = NGCC
1.2 1.0 0.8 0.6 0.4 0.2 0.0
SO2 (lb/MWh)
NOx (lb/MWh)
Particulates (lb/MWh)
CO2 (lb/1000 MWh)
* Based on 2006 Parson study for DOE : “Cost and Performance Comparison of Fossil Energy Power Plants” Descriptor - include initials, /org#/date