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158 IPCC Special Report on Carbon dioxide Capture and Storage substantially higher COE values result from high financing costs and lower plant utilization. Similarly, the type and properties of coal assumed has a major impact on the COE, as seen in a recent Canadian Clean Power Coalition study, which found substantially higher costs for low-rank coals using a Texaco- based IGCC system (Stobbs and Clark, 2005, Table 3.10). EPRI also reports higher IGCC costs for low-rank coals (Holt et al., 2003). On the other hand, where plant-level assumptions and designs are similar across studies, there is relatively little difference in the estimated costs of CO2 capture based on current commercial technology. Similarly, the several studies in Tables 3.7 and 3.10 that estimate costs for both IGCC and PC plants on an internally consistent basis, all find that IGCC plants with capture have a lower COE than PC plants with capture. There is not yet a high degree of confidence in these cost estimates, however (see Table 3.6). plants involve combining CO2 capture with plant upgrades that increase overall efficiency and net output. Additional studies would be needed to systematically compare the feasibility and cost of IGCC repowering to supercritical boiler upgrades at existing coal-fired plants. 3.7.7 CO2 capture cost for hydrogen production and multi-product plants (current technology) While electric power systems have been the dominant technologies of interest for CO2 capture studies, other industrial processes, including hydrogen production and multi-product plants producing a mix of fuels, chemicals and electricity also are of interest. Because CO2 capture cost depends strongly on the production process in question, several categories of industrial processes are discussed below. 3.7.7.1 Hydrogen production plants The costs in Table 3.10 also reflect efforts in some studies to identify least-cost CO2 capture options. For example, one recent study (IEA GHG, 2003) found that capture and disposal of hydrogen sulphide (H2S) along with CO2 can reduce overall capture costs by about 20% (although this may increase transport and storage costs, as discussed in Chapters 4 and 5). The feasibility of this approach depends in a large part on applicable regulatory and permitting requirements. Advanced IGCC designs that may further reduce future CO2 capture costs are discussed in Section 3.7.7. Section 3.5 discussed the potential role of hydrogen as an energy carrier and the technological options for its production. Here we examine the cost of capturing CO2 normally released during the production of hydrogen from fossil fuels. Table 3.11 shows the key assumptions and cost results of recent studies of CO2 capture costs for plants with hydrogen production rates of 155,000-510,000 Nm3 h-1 (466-1531 MWt), employing either natural gas or coal as a feedstock. The CO2 capture efficiency for the hydrogen plant ranges from 87-95% using commercially available chemical and physical absorption systems. The CO2 reduction per unit of product is lower, however, because of the process energy requirements and because of additional CO2 emitted by an offsite power plant assumed in some of these studies. As hydrogen production requires the separation of H2 from CO2, the incremental cost of capture is mainly the cost of CO2 compression. 3.7.6.2 Repowering of existing coal-fired plants with IGCC For some existing coal-fired power plants, an alternative to the post-combustion capture systems discussed earlier is repowering with an IGCC system. In this case - depending on site-specific circumstances - some existing plant components, such as the steam turbine, might be refurbished and utilized as part of an IGCC plant. Alternatively, the entire combustion plant might be replaced with a new IGCC system while preserving other site facilities and infrastructure. At present, hydrogen is produced mainly from natural gas. Two recent studies (see Table 3.11) indicate that CO2 capture would add approximately 18-33% to the unit cost of hydrogen while reducing net CO2 emissions per unit of H2 product by 72-83% (after accounting for the CO2 emissions from imported electricity). The total cost of hydrogen is sensitive to the cost of feedstock, so different gas prices would alter both the absolute and relative costs of CO2 capture. Although repowering has been widely studied as an option to improve plant performance and increase plant output, there are relatively few studies of repowering motivated by CO2 capture. Table 3.8 shows results from one recent study (Chen et al., 2003) which reports CO2 capture costs for IGCC repowering of a 250 MW coal-fired unit that is assumed to be a fully amortized (hence, a low COE of 21 US$ MWh-1). IGCC repowering yielded a net plant capacity of 600 MW with CO2 capture and a COE of 62-67 US$ MWh -1 depending on whether or not the existing steam turbine can be reused. The cost of CO2 avoided was 46-51 US$/tCO2. Compared to the option of retrofitting the existing PC unit with an amine-based capture system and retaining the existing boiler (Table 3.8), the COE for IGCC repowering was estimated to be 10-30% lower. These findings are in general agreement with earlier studies by Simbeck (1999). Because the addition of gas turbines roughly triples the gross plant capacity of a steam-electric plant, candidates for IGCC repowering are generally limited to smaller existing units (e.g., 100-300 MW). Taken together with the post-combustion retrofit studies in Table 3.8, the most cost-effective options for existing For coal-based hydrogen production, a recent study (NRC,2004) projects an 8% increase in the unit cost of hydrogen for an 83% reduction in CO2 emissions per unit of product. Again, this figure includes the CO2 emissions from imported electricity. 3.7.7.2 Multi-product plants Multi-product plants (also known as polygeneration plants) employ fossil fuel feedstocks to produce a variety of products such as electricity, hydrogen, chemicals and liquid fuels. To calculate the cost of any particular product (for a given rate of return), economic analyses of multi-product plants require that the selling price of all other products be specified over the operating life of the plant. Such assumptions, in addition toPDF Image | CARBON DIOXIDE CAPTURE AND STORAGE
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