A comparative study of refinery fuel gas oxy-fuel combustion options for CO2 capture using simulated process data

A new comprehensive techno-economic analysis method for power generation systems with CO2 capture is proposed in this paper. The correlative relationship between the efficiency penalty, investment increment, and CO2 avoidance cost is established. Through theoretical derivation, typical system analysis, and variation trends investigation, the mutual influence between technical and economic factors and their impacts on the CO2 avoidance cost are studied. At the same time, the important role that system integration plays in CO2 avoidance is investigated based on the analysis of a novel partial gasification CO2 recovery system. The results reveal that for the power generation systems with CO2 capture, the efficiency penalty not only affects the costs on fuel, but the incremental investment cost for CO2 capture (U.S.$ kW−1) as well. Consequently, it will have a decisive impact on the CO2 avoidance cost. Therefore, the added attention should be paid to improve the technical performance in order to reduce the efficiency penalty in energy system with CO2 capture and storage. Additionally, the system integration may not only decrease the efficiency penalty, but also simplify the system structure and keep the investment increment at a low level, and thereby it reduces the CO2 avoidance cost significantly. For example, for the novel partial gasification CO2 recovery system, owing to system integration, its efficiency can reach 42.2%, with 70% of CO2 capture, and its investment cost is only 87$ kW−1 higher than that of the reference IGCC system, thereby the CO2 avoidance cost is only 6.23$ t−1 CO2. The obtained results provide a comprehensive technical–economical analysis method for energy systems with CO2 capture useful for reducing the avoidance costs. Copyright © 2009 John Wiley & Sons, Ltd.

Harmonized comparison of virgin steel production using biomass with carbon capture and storage for negative emissions

Impact of post combustion capture of CO2 on existing and new Australian coal-fired power plants

The objective of this study is to assess the techno-economic potential of the proposed novel energy system, which allows for negative emissions of carbon dioxide (CO2). The analyzed system comprises four main subsystems: a biomass-fired combined heat and power plant integrated with a CO2 capture and compression unit, a CO2 transport pipeline, a CO2-enhanced geothermal system, and a supercritical CO2 Brayton power cycle. For the purpose of the comprehensive techno-economic assessment, the results for the reference biomass-fired combined heat and power plant without CO2 capture are also presented. Based on the proposed framework for energy and economic assessment, the energy efficiencies, the specific primary energy consumption of CO2 avoidance, the cost of CO2 avoidance, and negative CO2 emissions are evaluated based on the results of process simulations. In addition, an overview of the relevant elements of the whole system is provided, taking into account technological progress and technology readiness levels. The specific primary energy consumption per unit of CO2 avoided in the analyzed system is equal to 2.17 MJLHV/kg CO2 for biomass only (and 6.22 MJLHV/kg CO2 when geothermal energy is included) and 3.41 MJLHV/kg CO2 excluding the CO2 utilization in the enhanced geothermal system. Regarding the economic performance of the analyzed system, the levelized cost of electricity and heat are almost two times higher than those of the reference system (239.0 to 127.5 EUR/MWh and 9.4 to 5.0 EUR/GJ), which leads to negative values of the Net Present Value in all analyzed scenarios. The CO2 avoided cost and CO2 negative cost in the business as usual economic scenario are equal to 63.0 and 48.2 EUR/t CO2, respectively, and drop to 27.3 and 20 EUR/t CO2 in the technological development scenario. The analysis proves the economic feasibility of the proposed CO2 utilization and storage option in the enhanced geothermal system integrated with the sCO2 cycle when the cost of CO2 transport and storage is above 10 EUR/t CO2 (at a transport distance of 50 km). The technology readiness level of the proposed technology was assessed as TRL4 (technological development), mainly due to the early stage of the CO2-enhanced geothermal systems development.

The objective of this work was to perform the techno-economic analysis for the integration of two post-combustion carbon capture technologies into cement plants, namely monoethanolamine (MEA) scrubbing-based and silica-alkoxylated polyethyleneimine (SPEI) adsorbent-based processes. The key performance indicators were investigated, including emission abatement, energy performance, break-even selling price, CO2 capture and avoidance cost. The technical evaluation showed that the conventional MEA and SPEI-based processes required 3.53 GJ/tonne CO2 and 2.36 GJ/tonne CO2 of regeneration energy when achieving 90% of CO2 capture rate, respectively. In addition, the specific primary energy consumption for CO2 avoided was estimated at 6.5 GJ/tonne CO2 for the MEA-based and 4.3 GJ/tonne CO2 for the SPEI-based process. The CO2 capture costs of MEA and SPEI-based processes were estimated at 61.4 and 49.8 €/tonne CO2, respectively. Meanwhile, the CO2 avoidance cost of MEA and SPEI processes were estimated at 84.7 and 62.2 €/tonne CO2 respectively. The economic evaluation indicated that the cost of clinker production was increased by 108% with the integration of the solvent-based MEA-based and 84% for the SPEI-based processes. However, in the case, the maximum heat of 53.9 MWth is recovered from the reference cement plant, the costs of CO2 capture and CO2 avoidance for both the MEA and SPEI-based processes would be reduced. The CO2 capture costs of MEA and SPEI-based processes would decrease to 48.0 and 35.6 €/tonne CO2, respectively. Additionally, the CO2 avoidance costs for the MEA and SPEI-based processes would be reduced to 57.5 and 44.5 €/tonne CO2, respectively.

This paper provides a techno-economic analysis of a hypothetical first-of-its-kind CO2 capture and storage project in a modern Chinese steel production plant. It assumes the use of amine capture technology of the relatively high concentration CO2 emissions from the iron making process. The technical configuration of the project was modelled using the Advanced System for Process Engineering (ASPEN), combined with a financial model. Global crude steel production reached 1.6 billion tonnes in 2015, an increase of 41% over the 1.1 billion tonnes in 2005. China alone produced 804 million tonnes of crude steel in 2015, an increase of 130% over the 350 million tonnes in 2005. Applying environmentally-friendly and low-carbon technologies is the major future trend for the steel sector globally. The EU Commission’s Low Carbon Roadmap anticipates a global emission intensity of less than 0.2 tCO2 per tonne of crude steel by the end of 2050 compared to the current level of above 1.3 tCO2 per tonne, and China’s average of 2.18 tCO2 per tonne in 2014. The Roadmap suggests carbon capture and storage is a key technology to achieve larger emission reductions in the iron/steel sector. The cost of CO2 avoidance for the modelled 0.5 million tonne/year capacity CO2 capture project with transport and storage is USD69/tCO2. Assuming that the project runs at 90% capacity (0.45 MtCO2/year), over 25 years, the project would capture 11.25 MtCO2. However, this is offset by emissions from increased energy consumption so the project would only reduce aggregate emissions by 0.36 MtCO2/year, or a total of 8.88 MtCO2 over its lifetime. The cost of CO2 avoidance is sensitive to a number of assumptions, including the discount rate and the cost of CO2 transportation and storage. The discount rate of the capture project is assumed to be 12%, taking into account the cost of capital of Bao Steel and the risk of the CO2 capture project. If a project is considered as a moderate risk investment applying an 8% discount rate, the cost of CO2 avoidance (i.e. the abatement cost) will be reduced from USD69/t CO2 to USD64/tCO2. The assumption on transport and storage cost could be lower if the project could share the infrastructure with other large stationary emission sources.

Techno-economic analysis of carbon capture from a coal-fired power plant integrating solar-assisted pressure-temperature swing adsorption (PTSA)

Learning rates and future cost curves for fossil fuel energy systems with CO2 capture: Methodology and case studies

Techno-economic assessment of CO2 capture at steam methane reforming facilities using commercially available technology

Low-carbon cement manufacturing enabled by electrified calcium looping and thermal energy storage

Feasibility of integrating solar energy into a power plant with amine-based chemical absorption for CO2 capture

Techno-economic performance and challenges of applying CO2 capture in the industry: A case study of five industrial plants

The CCS paradox: The much higher CO2 avoidance costs of existing versus new fossil fuel power plants

Technical and economic prospects of coal- and biomass-fired integrated gasification facilities equipped with CCS over time

Oxy-fuel combustion coal-fired power plants can achieve significant reduction in carbon dioxide emissions, but at the cost of lowering their efficiency. Research and development are conducted to reduce the efficiency penalty and to improve their reliability. High-pressure oxy-fuel combustion has been shown to improve the overall performance by recuperating more of the fuel enthalpy into the power cycle. In our previous papers, we demonstrated how pressurized oxy-fuel combustion indeed achieves higher net efficiency than that of conventional atmospheric oxy-fuel power cycles. The system utilizes a cryogenic air separation unit, a carbon dioxide purification/compression unit, and flue gas recirculation system, adding to its cost. In this study, we perform a techno-economic feasibility study of pressurized oxy-fuel combustion power systems. A number of reports and papers have been used to develop reliable models which can predict the costs of power plant components, its operation, and carbon dioxide capture specific systems, etc. We evaluate different metrics including capital investments, cost of electricity, and CO2 avoidance costs. Based on our cost analysis, we show that the pressurized oxy-fuel power system is an effective solution in comparison to other carbon dioxide capture technologies. The higher heat recovery displaces some of the regeneration components of the feedwater system. Moreover, pressurized operating conditions lead to reduction in the size of several other critical components. Sensitivity analysis with respect to important parameters such as coal price and plant capacity is performed. The analysis suggests a guideline to operate pressurized oxy-fuel combustion power plants in a more cost-effective way.