Table TS.1. Current maturity of CCS system components.
An X indicates the highest level of maturity for each component. There are also less mature technologies for most components.
| CCS component |
CCS technology |
Research phase a |
Demonstration phase b |
Economically feasible under specific conditions c |
Mature market d |
a Research phase means that the basic science is understood, but the technology is currently in the stage of conceptual design or testing at the laboratory or
bench scale, and has not been demonstrated in a pilot plant.
b Demonstration phase means that the technology has been built and operated at the scale of a pilot plant, but further development is required before the
technology is required before the technology is ready for the design and construction of a full-scale system.
c Economically feasible under specific conditions means that the technology is well understood and used in selected commercial applications, for instance if
there is a favourable tax regime or a niche market, or processing on in the order of 0.1 MtCO2 yr-1, with few (less than 5) replications of the technology.
d Mature market means that the technology is now in operation with multiple replications of the technology worldwide.
e CO2 injection for EOR is a mature market technology, but when used for CO2 storage, it is only economically feasible under specific conditions.
f ECBM is the use of CO2 to enhance the recovery of the methane present in unminable coal beds through the preferential adsorption of CO2 on coal.
Unminable coal beds are unlikely to ever be mined, because they are too deep or too thin. If subsequently mined, the stored CO2 would be released.
|
| Capture |
Post-combustion |
|
|
X |
|
| Pre-combustion |
|
|
X |
|
| Oxyfuel combustion |
|
X |
|
|
| Industrial separation (natural gas processing, ammonia production) |
|
|
|
X |
| Transportation |
Pipeline |
|
|
|
X |
| Shipping |
|
|
X |
|
| Geological storage |
Enhanced Oil Recovery (EOR) |
|
|
|
Xe |
| Gas or oil fields |
|
|
X |
|
| Saline formations |
|
|
X |
|
| Enhanced Coal Bed Methane recovery (ECBM)f |
|
X |
|
|
| Ocean storage |
Direct injection (dissolution type) |
X |
|
|
|
| Direct injection (lake type) |
X |
|
|
|
| Mineral carbonation |
Natural silicate minerals |
X |
|
|
|
| Waste materials |
|
X |
|
|
| Industrial uses of CO2 |
|
|
|
|
X |
Source: IPCC 
Carbon Dioxide Capture and Storage: Technical Summary (2005)
1. Introduction and framework of this report, p. 18
Related publication:
Other Figures & Tables on this publication:
Table TS.1. Current maturity of CCS system components.
An X indicates the highest level of maturity for each component. There are also less mature technologies for most components.
Table TS.2. Profile by process or industrial activity of worldwide large stationary CO2 sources with emissions of more than 0.1 MtCO2 per year.
Table TS.3. Summary of CO2 capture costs for new power plants based on current technology.
Because these costs do not include the costs (or
credits) for CO2 transport and storage, this table should not be used to assess or compare total plant costs for different systems with capture. The full costs of
CCS plants are reported in Section 8.
Table TS.4. Summary of CO2 capture costs for new hydrogen plants based on current technology
Table TS.5. Sites where CO2 storage has been done, is currently in progress or is planned, varying from small pilots to large-scale
commercial applications.
Table TS.6. Storage capacity for several geological storage options. The storage capacity includes storage options that are not economical.
Table TS.7. Fraction of CO2 retained for ocean storage as simulated by seven ocean models for 100 years of continuous injection at three
different depths starting in the year 2000.
Table TS.8. Costs for ocean storage at depths deeper than 3,000 m.
Table TS.9. 2002 Cost ranges for the components of a CCS system as applied to a given type of power plant or industrial source.
The costs
of the separate components cannot simply be summed to calculate the costs of the whole CCS system in US$/CO2 avoided. All numbers are
representative of the costs for large-scale, new installations, with natural gas prices assumed to be 2.8-4.4 US$ GJ-1 and coal prices 1-1.5 US$
GJ-1.
Table TS.10. Range of total costs for CO2 capture, transport and geological storage based on current technology for new power plants using
bituminous coal or natural gas
Table TS.11. Mitigation cost ranges for different combinations of reference and CCS plants based on current technology for new power
plants. Currently, in many regions, common practice would be either a PC plant or an NGCC plant14. EOR benefits are based on oil prices of
15 - 20 US$ per barrel. Gas prices are assumed to be 2.8 -4.4 US$/GJ-1, coal prices 1-1.5 US$/GJ-1 (based on Table 8.3a).
Table TS.12. Differences in the forms of CCS and biological sinks that might influence the way accounting is conducted.
Figure TS.1. Schematic diagram of possible CCS systems
Figure TS.2a. Global distribution of large stationary sources of CO2
Figure TS.2b. Prospective areas in sedimentary basins
Figure TS.3. Overview of CO2 capture processes and systems
Figure TS.4. (a) CO2 post-combustion capture at a plant in Malaysia
Figure TS.5. Transport costs for onshore pipelines and offshore pipelines
Figure TS.6. Costs, plotted as US$/tCO2 transported against distance, for onshore pipelines, offshore pipelines and ship transport
Figure TS.7. Methods for storing CO2 in deep underground geological formations
Figure TS.8. Potential leakage routes and remediation techniques for CO2 injected into saline formations
Figure TS.9. Methods of ocean storage
Figure TS.10. Material fluxes and process steps associated with the mineral carbonation of silicate rocks or industrial residues (Courtesy ECN).
Figure TS.11. CO2 capture and storage from power plants
Figure TS.12. Global potential contribution of CCS as part of a mitigation portfolio
Figures TS.2a. & TS.2b.
