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Unit at Great Plains Synfuels Plant |
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Removal of carbon dioxide (CO2) from industrial gas streams is not a new process. Gas absorption processes using chemical solvents, such as amines, to separate CO2 from other gases have been in use since the 1930s in the natural gas industry. These processes are also used to produce food and chemical grade CO2 from gas streams containing 3 to 25 percent CO2. Starting in the 1940s, physical solvents were developed to absorb CO2 from gas streams with higher CO2 concentrations (25 to 70 percent). In the 1950s and 1960s, gas adsorption processes were developed to remove CO2 from gas streams associated with hydrogen production (refineries), nitrogen separation, and dehydration. In the 1970s and 1980s, gas separation membranes were developed to capture CO2 for use in enhanced oil recovery (EOR) and natural gas processing.
A 2009 review of commercially available CO2 capture technologies identified 17 facilities (using both chemical and physical capture solvents) in current operation (table below). These include four natural gas processing operations and a synthesis gas (syngas) production facility in which more than 1 million tons of CO2 are captured per year. The largest (a natural gas processing operation in Wyoming) captures 4 million tons per year. The facilities capturing the highest volumes of CO2 are all associated with gas streams containing relatively high concentrations of CO2.
Capturing CO2 from more dilute streams, such as those generated from power production, is less common. For example, several power plants produce food-grade CO2. Although there are commercially available CO2 capture technologies, one of the key barriers to their widespread commercial deployment is the lack of experience with these systems at the appropriate scale at power plants. Currently operating CO2 capture systems in coal-based power plant applications include amine and chilled ammonia solvent systems that process about 75,000 to 300,000 tons of CO2 per year. By comparison, a single 550-megawatt (MW) net output coal-fired power plant capturing 90 percent of the emitted CO2 will need to separate approximately 5 million tons of CO2 per year.
In order to address some of the barriers to widespread commercial deployment of CO2 capture, the U.S. Department of Energy (DOE) plans to conduct several large-scale demonstrations of currently available technologies as part of the Clean Coal Power Initiative (CCPI). These include three demonstrations of CO2 capture from integrated gasification combined cycle (IGCC) power plants and three from conventional power plants. The generating capacities at the demonstration facilities range from 60 to 582 MW, and total CO2 captured ranges from 0.5 to 3 million tons per year. The demonstrations will be initiated from 2014 to 2016, and the projects will run for two to three years. In addition, a first generation oxy-combustion technology CO2 capture demonstration project is planned under the FutureGen 2.0 Initiative that will involve repowering an existing 200-MW power plant located in Illinois. Finally, additional CO2 capture demonstration projects are planned under the Industrial Carbon Capture and Storage (ICCS) program. Several of the ICCS projects are pursuing capture technologies that are similar to those being demonstrated for power plants. These projects are of similar magnitude to the CCPI capture demonstrations (90 percent capture, 0.9 million to 4 million tons/year captured).
Summary of CO2 Capture Facilities Operating in 2009 |
CO2 Source/Project Name |
Location |
Capture Rate (tons/year) |
CO2 End Use |
Post-Combustion Capture from Pulverized Coal-Fired Electric Power Plants |
AES Warrior Run Power Plant |
Cumberland, MD, USA |
120,000 |
Food/Beverage |
AES Shady Point Power Plant |
Panama, OK, USA |
73,000 |
Food/Beverage |
Searles Valley Minerals |
Trona, CA, USA |
300,000 |
Soda Ash Production |
CO2 Capture from Coal Gasification |
Great Plains Synfuels Plant |
Beulah, ND, USA |
2,000,000 |
Enhanced Oil Recovery |
CO2 Capture from Oxygen-Fired Coal Combustion |
Vattenfall Schwarze Pumpe Plant |
Germany |
75,000 |
Various Industrial |
Post-Combustion Capture from Natural Gas-Fired Facilities |
Sumitomo Chemicals Plant |
Japan |
60,000 |
Food/Beverage |
Prosint Methanol Production Plant |
Brazil |
30,000 |
Food/Beverage |
CO2 Capture for Natural Gas Reforming |
Indian Farmers Fertilizer Co. |
India |
600,000 |
Manufacturing |
Petronas Fertilizer |
Malaysia |
55,000 |
Urea Production |
Ruwais Fertilizer Industries |
UAE |
145,000 |
NR* |
Luzhou Natural Gas Chemicals |
China |
55,000 |
Urea Production |
CO2 Capture from Natural Gas Production |
Snohvit LNG Project |
Norway |
700,000 |
Geologic Storage |
Sleipner West Field |
Norway |
1,000,000 |
Geologic Storage |
In Salah Natural Gas Production |
Algeria |
1,200,000 |
Geologic Storage |
Shute Creek Natural Gas Processing |
La Barge, WY, USA |
4,000,000 |
Enhanced Oil Recovery |
Val Verde Natural Gas Plants |
Terrell/Pyros, TX, USA |
1,400,000 |
Enhanced Oil Recovery |
DTE Turtle Lake Gas Processing |
Ostego, MI, USA |
200,000 |
Enhanced Oil Recovery / Geologic Storage |
*NR – Not Reported
Material obtained from “Report of the Interagency Task Force on Carbon Capture and Storage,” August 2010. Available at: http://fossil.energy.gov/programs/sequestration/ccstf/CCSTaskForceReport2010.pdf. |
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