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This paper investigates the cost reduction opportunity of lower CO 2 capture ratios (CCR) on membrane-based CO 2 capture. A numerical model based on the attainable region approach is used to optimise and assess the cost of membrane-based processes for CO 2 capture from post-combustion flue gases containing 10–35% CO 2 , analysing five membranes and CO 2 capture ratios from 50 to 90%. Overall, these cost evaluations demonstrate that membrane-based post-combustion CO 2 capture can significantly benefit from lower CCRs (up to 55% reduction in CO 2 avoidance cost for a flue gas containing 35% CO 2 ). Considering lower CCRs could therefore enable early deployment of CCS despite low carbon emission cost, however the evaluations show that the optimal CCR and corresponding cost reduction potential shall be assessed considering the whole chain characteristics (CO 2 content in the flue gas, impurities, membrane module properties, CO 2 transport system, etc.). [ABSTRACT FROM AUTHOR]

This paper investigates different strategies for CO 2 conditioning and transport options for the CO 2 to be captured at a lignite-fired IGCC in the Czech Republic, including the impact of impurities present in the captured CO 2 streams. Four transport cases, combining two transport delivery location scenarios (Czech storage and European transport hub) and two transport technology options (pipeline-based and train-based transport), are designed and evaluated. For the Czech storage case, the cost evaluation of the CO 2 conditioning and transport results in costs of 10.5 and 18.3 €/t CO2 for the pipeline and train options respectively. In the European hub scenario, the CO 2 conditioning and transport costs are estimated at 15.4 and 24.9 €/t CO2 . These results clearly identify the pipeline transport options as the cost-optimal solutions for CO 2 transport in both delivery location scenarios, due to the longer transport distances and higher conditioning costs involved for train-based export. Moreover, the comparison of transport delivery location scenarios also shows that if CO 2 storage is not possible at the Czech storage location and the CO 2 has to pass through the European hub, this would result in an increase of at least 4.9 €/t CO2 , plus the additional transport and storage costs after the European hub stage. In addition, further assessments are performed to evaluate the impact of impurities in the CO 2 streams from the capture plant on the CO 2 conditioning and transport costs for the four combinations of transport scenarios and technology options. The results show that the impurities present in the CO 2 streams lead to increases in CO 2 conditioning and transport costs ranging from 1.6 to 11.4% (0.2–1.9 €/t CO2 ). However, the energy and cost impacts associated with the impurities are highly dependent on the transport technology and transport delivery location scenario considered. Furthermore, the process energy and cost performances of two alternative CO 2 liquefaction processes, designed to reduce CO 2 losses through the purged gas, are also evaluated. These two alternative processes result in higher CO 2 conditioning cost than the base case process, which suggests that reducing the CO 2 losses compared to the base case would not be a good strategy, unless high costs (70–110 €/t CO2 ) were spent to capture the CO 2 that is purged. Finally, the potential of train-based transport is evaluated beyond the four cases considered by comparing the CO 2 conditioning and transport costs of pipeline and train transports as a function of the distance for different train conditioning cost scenarios and different project economic valuation periods. The results show that train-based transport could potentially be a cost-optimal alternative to pipeline-based transport for medium to long distances especially in cases where the additional conditioning costs of train-based transport compared to pipeline are limited, or in cases of financial risk-averse decisions. [ABSTRACT FROM AUTHOR]

This paper investigates various alternatives for the application of CCS at a cement plant which is one of the focus site for CCS deployment in Norway. A matrix consisting of nine CCS alternative chains is analysed in order to quantify cost reduction potentials across the CCS value chain based on an in-house techno-economic assessment methodology and tool called iCCS. In particular, the paper quantifies the strong cost reduction potential of second generation capture technologies and transport technology selection. CO 2 EOR is also identified to have a strong potential to reduce the overall CCS cost, however the cost benefits are strongly dependent on the oil value and the considered EOR injection period. The impact of the inclusion of CO 2 capture and conditioning in the cost of cement shows that public financial support will be required to ensure that the plant remain competitive under current cement market price. Finally, comparison of the full-scale capture versus part-scale capture shows, in this case, that the economies of scale are nearly compensated by the additional steam cost, therefore limiting the interest for full-scale implementation. However, joint deployment with the two other CCS potential sites in Norway (Yara and Klemenstrud) may bring more synergies. [ABSTRACT FROM AUTHOR]

This paper describes a detailed technical and economic assessment of conditioning and transporting 13.1 MTPA CO 2 with impurities in an on-shore pipe-line over a distance of 500 km. The impurities that are included in the study represents 5 mol% residuals from air-components (N 2 and O 2 ) and 10 mol% residuals from natural gas components (N 2 and CH 4 ). The analysis includes compression from low pressure, after the captures process, to the pipeline conditions in the dense phase of 150 bar. In the technical analysis of the pipeline transport, thermo-physical properties depending of the pressure and temperature locally as the stream evolves through the pipeline are used as well as heat transferred with the surroundings. The case studies investigate different pipeline diameters from 18″ to 28″ to find the most economical pipeline diameter for each impurity level. The cost model includes the material, labour and energy costs and the result are dependent on the number of required, booster stations, the pipeline wall thickness, the energy consumption and cooling demand. The wall thicknesses are chosen for each investigated diameter based on strength design and rounded off to the next available standard wall thickness according to the API-standard. In the second part, a 24″ pipeline with 4 booster stations is selected and the feed flow rate has been adjusted to match the installed compression power. The results show that for the cost-optimal diameter the specific conditioning and transport cost increases by 13 and 22% for the two cases compared to transporting pure CO 2 . This represents an increase from 2.3 to 3.8 €/ton CO2 . The second scenario, where impure CO 2 is transported in an existing pipeline, the cost is shown to be around 20–40% more expensive than transporting pure CO 2 . The effect on energy consumption and cost from different ambient conditions are also discussed and it is shown that for the selected case the cost of transport will vary 0.01 €/ton/K with change in average temperature from 15 °C as the baseline. Impurities can also be expected to have a significant impact on the technical and economic performances of the whole CCS chain and it is therefore important to evaluate this on a case-to-case bases in order to find possible trade-offs between capture, conditioning, transport and storage and to provide recommendations. [ABSTRACT FROM AUTHOR]

This paper focuses on the identification of membrane properties required to enable cost-competitive post-combustion CO 2 capture from a coal power plant using membrane-based processes. In order to identify such properties, a numerical version of the attainable region approach proposed by Lindqvist et al., built as part of the of the iCCS tool developed by SINTEF Energy Research, is used to identify and assess the technical and cost performances of the optimal membrane process for a given set of membrane properties (selectivity and permeance). This numerical model is used to assess the cost performances of 1600 sets of membrane properties (selectivity and permeance) for post-combustion CO 2 capture from a coal power plant as defined by the European Benchmarking Task Force and compare it with the reference commercial solvent concept (MEA) to identify the membrane properties required in a base case that treats both membrane- and MEA-based processes as mature and developed. The results show that to reach this competiveness with simple process configurations requires a permeance of at least 3 m 3 (STP)/(m 2 ·h·bar) with high selectivity, or alternatively a selectivity of at least 65 with high permeances . These limits can be reduced to permeances as low as 1 m 3 (STP)/(m 2 ·h·bar) with high selectivity, or selectivities as low as 30 with high permeances, when advanced membrane process configurations are being considered. The assessments of five additional cases quantify how additional costs associated with demonstration projects and higher membrane module costs can significantly increase the selectivities and permeances required to compete with MEA based capture. In order to link the membrane development works to the results presented in this paper, the constraint introduced by Robeson's upper bound limitation, as well as data available in the literature on membrane modules and polymeric materials, are compared with the results obtained. The inclusion of the upper bound shows that the capacity to generate thin membrane film layers is important in order to avoid reducing the range of membrane properties, in which diffusion governed membrane can be interesting in term of cost performances, especially in cases that take demonstration and/or higher module costs into consideration. The comparison with literature data shows that while several membranes and polymeric materials have the potential to be cost-competitive with further properties improvements, and once membrane-based CO 2 capture becomes mature and demonstrated, financial support will be required to demonstrate and help mature the technology. Finally, ways to use the results presented here for membrane development by membrane development experts, for membrane selection by industrial users, and for technology development and demonstration support by decision-makers are discussed. [ABSTRACT FROM AUTHOR]