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Table TS.4. Summary of CO2 capture costs for new hydrogen plants based on current technology Technical Summary 29 Performance and cost measures New hydrogen plant Range Representative value Low High Emission rate without capture (kgCO2 GJ-1) 78 - 174 137 Emission rate with capture (kgCO2 GJ-1) 7 - 28 17 Percent CO2 reduction per GJ (%) 72 - 96 86 Plant efficiency with capture, LHV basis (%) 52 - 68 60 Capture energy requirement (% more input GJ-1) 4 - 22 8 Cost of hydrogen without capture (US$ GJ-1) 6.5 - 10.0 7.8 Cost of hydrogen with capture (US$ GJ-1) 7.5 - 13.3 9.1 Increase in H2 cost with capture (US$ GJ-1) 0.3 - 3.3 1.3 Percent increase in H2 cost with capture (%) 5 - 33 15 Cost of net CO2 captured (US$/tCO2) 2 - 56 15 Capture cost confidence level moderate to high Notes: Ranges and representative values are based on data from Table 3.11. All costs in this table are for capture only and do not include the costs of CO2 transport and storage. Costs are in constant US$2002. Hydrogen plant feedstocks are natural gas (4.7-5.3 US$ GJ-1) or coal (0.9-1.3 US$ GJ-1); some plants in dataset produce electricity in addition to hydrogen. Fixed charge factors vary from 13-20%. All costs include CO2 compression but not additional CO2 transport and storage costs (see Section 8 for full CCS costs). methods of CO2 transport and assesses the health, safety and environment aspects, and costs. Methods of CO2 transport in Table TS.4, where costs vary from 2–56 US$/tCO2 net captured. New or improved methods of CO2 capture, combined with advanced power systems and industrial process designs, could reduce CO2 capture costs and energy requirements. While costs for first-of-a-kind commercial plants often exceed initial cost estimates, the cost of subsequent plants typically declines as a result of learning-by-doing and other factors. Although there is considerable uncertainty about the magnitude and timing of future cost reductions, the literature suggests that, provided R&D efforts are sustained, improvements to commercial technologies can reduce current CO2 capture costs by at least 20–30% over approximately the next ten years, while new technologies under development could achieve more substantial cost reductions. Future cost reductions will depend on the deployment and adoption of commercial technologies in the marketplace as well as sustained R&D. 4. Transport of CO2 Except when plants are located directly above a geological storage site, captured CO2 must be transported from the point of capture to a storage site. This section reviews the principal Pipelines today operate as a mature market technology and are the most common method for transporting CO2. Gaseous CO2 is typically compressed to a pressure above 8 MPa in order to avoid two-phase flow regimes and increase the density of the CO2, thereby making it easier and less costly to transport. CO2 also can be transported as a liquid in ships, road or rail tankers that carry CO2 in insulated tanks at a temperature well below ambient, and at much lower pressures. The first long-distance CO2 pipeline came into operation in the early 1970s. In the United States, over 2,500 km of pipeline transports more than 40 MtCO2 per year from natural and anthropogenic sources, mainly to sites in Texas, where the CO2 is used for EOR.These pipelines operate in the ‘dense phase’ mode (in which there is a continuous progression from gas to liquid, without a distinct phase change), and at ambient temperature and high pressure. In most of these pipelines, the flow is driven by compressors at the upstream end, although some pipelines have intermediate (booster) compressor stations.PDF Image | CARBON DIOXIDE CAPTURE AND STORAGE
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