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Escosa, Jesús M., and Luis M. Romeo. "Optimizing CO2 avoided cost by means of repowering." Applied Energy 86, no. 11 (November 2009): 2351–58. http://dx.doi.org/10.1016/j.apenergy.2009.02.015.
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Gatti, Manuele, Emanuele Martelli, Daniele Di Bona, Marco Gabba, Roberto Scaccabarozzi, Maurizio Spinelli, Federico Viganò, and Stefano Consonni. "Preliminary Performance and Cost Evaluation of Four Alternative Technologies for Post-Combustion CO2 Capture in Natural Gas-Fired Power Plants." Energies 13, no. 3 (January 22, 2020): 543. http://dx.doi.org/10.3390/en13030543.
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The objective of this study is to assess the technical and economic potential of four alternative processes suitable for post-combustion CO2 capture from natural gas-fired power plants. These include: CO2 permeable membranes; molten carbonate fuel cells (MCFCs); pressurized CO2 absorption integrated with a multi-shaft gas turbine and heat recovery steam cycle; and supersonic flow-driven CO2 anti-sublimation and inertial separation. A common technical and economic framework is defined, and the performance and costs of the systems are evaluated based on process simulations and preliminary sizing. A state-of-the-art natural gas combined cycle (NGCC) without CO2 capture is taken as the reference case, whereas the same NGCC designed with CO2 capture (using chemical absorption with aqueous monoethanolamine solvent) is used as a base case. In an additional benchmarking case, the same NGCC is equipped with aqueous piperazine (PZ) CO2 absorption, to assess the techno-economic perspective of an advanced amine solvent. The comparison highlights that a combined cycle integrated with MCFCs looks the most attractive technology, both in terms of energy penalty and economics, i.e., CO2 avoided cost of 49 $/tCO2 avoided, and the specific primary energy consumption per unit of CO2 avoided (SPECCA) equal to 0.31 MJLHV/kgCO2 avoided. The second-best capture technology is PZ scrubbing (SPECCA = 2.73 MJLHV/kgCO2 avoided and cost of CO2 avoided = 68 $/tCO2 avoided), followed by the monoethanolamine (MEA) base case (SPECCA = 3.34 MJLHV/kgCO2 avoided and cost of CO2 avoided = 75 $/tCO2 avoided), and the supersonic flow driven CO2 anti-sublimation and inertial separation system and CO2 permeable membranes. The analysis shows that the integrated MCFC–NGCC systems allow the capture of CO2 with considerable reductions in energy penalty and costs.
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Lee, Bong Jae, Jeong Il Lee, Soo Young Yun, Cheol-Soo Lim, and Young-Kwon Park. "Economic Evaluation of Carbon Capture and Utilization Applying the Technology of Mineral Carbonation at Coal-Fired Power Plant." Sustainability 12, no. 15 (July 31, 2020): 6175. http://dx.doi.org/10.3390/su12156175.
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Based on the operating data of a 40 tCO2/day (2 megawatt (MW)) class carbon capture and utilization (CCU) pilot plant, the scaled-up 400 tCO2/day (20 MW) class CCU plant at 500 MW power plant was economically analyzed by applying the levelized cost of energy analysis (LCOE) and CO2 avoided cost. This study shows that the LCOE and CO2 avoided cost for 400 tCO2/day class CCU plant of mineral carbonation technology were 26 USD/MWh and 64 USD/tCO2, representing low LCOE and CO2 avoided cost, compared to other carbon capture and storage CCS and CCU plants. Based on the results of this study, the LCOE and CO2 avoided cost may become lower by the economy of scale, even if the CO2 treatment capacity of the CCU plant could be extended as much as for similar businesses. Therefore, the CCU technology by mineral carbonation has an economic advantage in energy penalty, power plant construction, and operating cost over other CCS and CCU with other technology.
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Fimbres Weihs, G. A., and D. E. Wiley. "Steady-state design of CO2 pipeline networks for minimal cost per tonne of CO2 avoided." International Journal of Greenhouse Gas Control 8 (May 2012): 150–68. http://dx.doi.org/10.1016/j.ijggc.2012.02.008.
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Gładysz, Paweł, Anna Sowiżdżał, Maciej Miecznik, Maciej Hacaga, and Leszek Pająk. "Techno-Economic Assessment of a Combined Heat and Power Plant Integrated with Carbon Dioxide Removal Technology: A Case Study for Central Poland." Energies 13, no. 11 (June 3, 2020): 2841. http://dx.doi.org/10.3390/en13112841.
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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.
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Hamadeh, Hachem, Sannan Y. Toor, Peter L. Douglas, S. Mani Sarathy, Robert W. Dibble, and Eric Croiset. "Techno-Economic Analysis of Pressurized Oxy-Fuel Combustion of Petroleum Coke." Energies 13, no. 13 (July 4, 2020): 3463. http://dx.doi.org/10.3390/en13133463.
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Petroleum coke (petcoke) is a by-product of heavy petroleum refining, with heating values comparable to that of coal. It is readily available in oil-producing countries such as the United States of America (USA) and the Kingdom of Saudi Arabia (KSA) at minimum costs and can be used as an inexpensive fossil fuel for power generation. Oxy-petcoke combustion is an attractive CO2 capture option as it avoids the use of additional absorption units and chemicals, and results in a CO2 + H2O flue gas stream that is compressed and dehydrated in a CO2 capture and purification unit (CO2CPU). The additional cost of the CO2CPU can be reduced through high pressure combustion. Hence, this paper reports a techno-economic analysis of an oxy-petcoke plant with CO2 capture simulated at pressures between 1 and 15 bars in Aspen PlusTM based on USA and KSA scenarios. Operating at high pressures leads to reduced equipment sizes and numbers of units, specifically compressors in CO2CPU, resulting in increased efficiencies and decreased costs. An optimum pressure of ~10 bars was found to maximize the plant efficiency (~29.7%) and minimize the levelized cost of electricity (LCOE), cost of CO2 avoided and cost of CO2 captured for both the USA and KSA scenarios. The LCOE was found to be moderately sensitive to changes in the capital cost (~0.7% per %) and increases in cost of petcoke (~0.5% per USD/tonne) and insensitive to the costs of labour, utilities and waste treatment.
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Calili, Rodrigo F., Reinaldo C. Souza, Alain Galli, Margaret Armstrong, and André Luis M. Marcato. "Estimating the cost savings and avoided CO2 emissions in Brazil by implementing energy efficient policies." Energy Policy 67 (April 2014): 4–15. http://dx.doi.org/10.1016/j.enpol.2013.09.071.
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Gardarsdottir, Stefania, Edoardo De Lena, Matteo Romano, Simon Roussanaly, Mari Voldsund, José-Francisco Pérez-Calvo, David Berstad, et al. "Comparison of Technologies for CO2 Capture from Cement Production—Part 2: Cost Analysis." Energies 12, no. 3 (February 10, 2019): 542. http://dx.doi.org/10.3390/en12030542.
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This paper presents an assessment of the cost performance of CO2 capture technologies when retrofitted to a cement plant: MEA-based absorption, oxyfuel, chilled ammonia-based absorption (Chilled Ammonia Process), membrane-assisted CO2 liquefaction, and calcium looping. While the technical basis for this study is presented in Part 1 of this paper series, this work presents a comprehensive techno-economic analysis of these CO2 capture technologies based on a capital and operating costs evaluation for retrofit in a cement plant. The cost of the cement plant product, clinker, is shown to increase with 49 to 92% compared to the cost of clinker without capture. The cost of CO2 avoided is between 42 €/tCO2 (for the oxyfuel-based capture process) and 84 €/tCO2 (for the membrane-based assisted liquefaction capture process), while the reference MEA-based absorption capture technology has a cost of 80 €/tCO2. Notably, the cost figures depend strongly on factors such as steam source, electricity mix, electricity price, fuel price and plant-specific characteristics. Hence, this confirms the conclusion of the technical evaluation in Part 1 that for final selection of CO2 capture technology at a specific plant, a plant-specific techno-economic evaluation should be performed, also considering more practical considerations.
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Zhuang, Quan, Philip Geddis, and Bruce Clements. "The Impact of Coal and Biomass Co-Firing on the Economy of Power Plant Carbon Capture." Advances in Sciences and Engineering 12, no. 2 (December 25, 2020): 67–77. http://dx.doi.org/10.32732/ase.2020.12.2.67.
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A detailed economic evaluation was carried out to determine the impact of biomass and coal co-firing on power plant carbon capture by methods of plants equipment designing factors and performance, and the sum up of the associated breakdowns of CAPEX and OPEX. Based on the assumptions of the CO2 neutrality of biomass and likely governmental incentives to reduce CO2 emissions, the study results show that biomass and coal co-firing would result in both lower cost of carbon avoided (carbon capture) and lower incremental cost of electricity generation when MEA solvent carbon capture is applied. Two scenarios for co-firing with carbon capture, 30% biomass blending and 90% or 60% CO2 capture from stack, indicate different preference depending on lower or higher incentives.
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Mukundufite, Fabien, Jean Marie Vianney Bikorimana, Etienne Ntagwirumugara, and Alex Kyaruzi. "CO2 emission reduction and energy management for an integrated smart grid — Case of study: Rwandan electrical network." E3S Web of Conferences 181 (2020): 03002. http://dx.doi.org/10.1051/e3sconf/202018103002.
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Many scholars have been focusing on the energy management by Integrating a smart grid into a conventional electrical grid. They have showed that to meet a certain power demand of the consumers, using energy management, the electric utility can turn on some generators, which may have the least operation cost, while the generators with high operation cost are left to supply extra load demand in specific peak periods. Henceforth, the operation cost of its generation units is minimized. The issue remains at a level of relating the energy management to CO2 emission. The present paper briefly discusses the Rwandan electrical network that still integrates the use of diesel generators. It estimates the amount of CO2 emission that can be avoided once a PV system is integrated into the electrical network. The paper as well proposes an algorithm for energy management with consideration of CO2 emission.
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Chiesa, Paolo, and Stefano Consonni. "Natural Gas Fired Combined Cycles With Low CO2 Emissions." Journal of Engineering for Gas Turbines and Power 122, no. 3 (May 15, 2000): 429–36. http://dx.doi.org/10.1115/1.1287496.
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This paper assesses performances and economic viability of CO2 removal by chemical absorption from the flue gases of natural gas-fired Combined Cycles, more specifically for two configurations: one where CO2 is removed ahead of the stack without modifying the power cycle; the other where part of the flue gases is recirculated to the gas turbine, thereby reducing the flow to be treated by chemical absorption. In both cases sequestered CO2 is made available at conditions suitable to storage into deep oceanic waters. Performances and cost of electricity are evaluated for systems based on large, heavy-duty turbines representative of state-of-the-art “FA” technology. Carbon sequestration reduces net plant efficiency and power output by about 10 percent and increases the cost of electricity from 36 to about 50 mills/kWh. Flue gas recirculation warrants slightly higher efficiencies and lower costs. CO2 removal is eventually compared with other strategies for the reduction of CO2 emissions, like switching existing coal-fired steam plants to natural gas or replacing existing steam plants with conventional CCs. At current fuel prices the latter appears the option of choice, with a cost of about $25 per tonn of avoided CO2 emission. [S0742-4795(00)02803-9]
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Châtel-Pélage, Fabienne, Rajani Varagani, Pavol Pranda, Nicolas Perrin, Hamid Farzan, Stanley Vecci, LU Yongqi, Scott Chen, Massoud Rostam-Abadi, and Arun Bose. "Applications of oxygen for NOx control and CO2 capture in coal-fired power plants." Thermal Science 10, no. 3 (2006): 119–42. http://dx.doi.org/10.2298/tsci0603119c.
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Two promising combustion modification approaches applicable to pulverized coal fired boilers are presented: "Oxygen-Enriched Combustion" (OEC) for NOx control and "Oxy-Combustion" (PC-OC) for CO2 capture. Oxygen-enriched air rather than air is used as an oxidizer in the OEC technology. Unlike flue gas treatment technologies, OEC directly impacts the NOx formation process by significantly reducing the conversion of coal bound nitrogen to NOx. Pilot-scale and full-scale tests have shown 20 to 30% NOx reduction from an optimized staged-air baseline. In addition to the overall cost competitiveness and the reduced capital requirements, other significant advantages of the O2-enriched technology vs. existing low NOx technologies are presented. The PC-OC technology is shown as a cost-effective technology for CO2 capture from existing or new coal-fired power plants. Pure oxygen diluted in recycled flue gases is used as an oxidizer. The process has been successfully demonstrated and extensively characterized at pilot-scale level (1.5 MWt). The tests have shown substantial benefits of the PC-OC technology, in terms of NOx reduction (60-70% from air-baseline), overall plant efficiency, etc. The cost effectiveness of this capture technology compared to competitive amine scrubbing technology was investigated. The cost of CO2 avoided was around $36/ton for the new PC-OC cases, about $48/ton on a retrofit PC-OC case, which is about 25 to 40% cheaper than the amine scrubbing system. Those numbers were calculated for sub-critical units and include the cost of CO2 compression up to 80 bar. .
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Mikhailova, Elena A., Garth R. Groshans, Christopher J. Post, Mark A. Schlautman, and Gregory C. Post. "Valuation of Soil Organic Carbon Stocks in the Contiguous United States Based on the Avoided Social Cost of Carbon Emissions." Resources 8, no. 3 (August 29, 2019): 153. http://dx.doi.org/10.3390/resources8030153.
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Soil organic carbon (SOC) generates several ecosystem services (ES), including a regulating service by sequestering carbon (C) as SOC. This ES can be valued based on the avoided social cost of carbon (SC-CO2) from the long-term damage resulting from emissions of carbon dioxide (CO2). The objective of this study was to assess the value of SOC stocks, based on the avoided SC-CO2 ($42 per metric ton of CO2 in 2007 U.S. dollars), in the contiguous United States (U.S.) by soil order, soil depth (0–20, 20–100, 100–200 cm), land resource region (LRR), state, and region using information from the State Soil Geographic (STATSGO) database. The total calculated monetary value for SOC storage in the contiguous U.S. was between $4.64T (i.e., $4.64 trillion U.S. dollars, where T = trillion = 1012) and $23.1T, with a midpoint value of $12.7T. Soil orders with the highest midpoint SOC storage values were 1): Mollisols ($4.21T), 2) Histosols ($2.31T), and 3) Alfisols ($1.48T). The midpoint values of SOC normalized by area within soil order boundaries were ranked: 1) Histosols ($21.58 m−2), 2) Vertisols ($2.26 m−2), and 3) Mollisols ($2.08 m−2). The soil depth interval with the highest midpoint values of SOC storage and content was 20–100 cm ($6.18T and $0.84 m−2, respectively), while the depth interval 100–200 cm had the lowest midpoint values of SOC storage ($2.88T) and content ($0.39 m−2). The depth trends exemplify the prominence of SOC in the upper portions of soil. The LRRs with the highest midpoint SOC storage values were: 1) M – Central Feed Grains and Livestock Region ($1.8T), 2) T – Atlantic and Gulf Coast Lowland Forest and Crop Region ($1.26T), and 3) K – Northern Lake States Forest and Forage Region ($1.16T). The midpoint values of SOC normalized by area within LRR boundaries were ranked: 1) U – Florida Subtropical Fruit, Truck Crop, and Range Region ($6.10 m−2), 2) T – Atlantic and Gulf Coast Lowland Forest and Crop Region ($5.44 m−2), and 3) K – Northern Lake States Forest and Forage Region ($3.88 m−2). States with the highest midpoint values of SOC storage were: 1) Texas ($1.08T), 2) Minnesota ($834B) (i.e., $834 billion U.S. dollars, where B = billion = 109), and 3) Florida ($742B). Midpoint values of SOC normalized by area within state boundaries were ranked: 1) Florida ($5.44 m−2), 2) Delaware ($4.10 m−2), and 3) Minnesota ($3.99 m−2). Regions with the highest midpoint values of SOC storage were: 1) Midwest ($3.17T), 2) Southeast ($2.44T), and 3) Northern Plains ($2.35T). Midpoint values of SOC normalized by area within region boundaries were ranked: 1) Midwest ($2.73 m−2), 2) Southeast ($2.31 m−2), and 3) East ($1.82 m−2). The reported values and trends demonstrate the need for policies with regards to SOC management, which requires incentives within administrative boundaries but informed by the geographic distribution of SOC.
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Groshans, Mikhailova, Post, Schlautman, and Zhang. "Determining the Value of Soil Inorganic Carbon Stocks in the Contiguous United States Based on the Avoided Social Cost of Carbon Emissions." Resources 8, no. 3 (June 29, 2019): 119. http://dx.doi.org/10.3390/resources8030119.
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Carbon sequestered as soil inorganic carbon (SIC) provides a regulating ecosystem service, which can be assigned a monetary value based on the avoided social cost of carbon (SC-CO2). By definition, the SC-CO2 is a measure, in dollars, of the long-term damage resulting from the emission of a metric ton of carbon dioxide (CO2). Therefore, this dollar figure also represents the value of damages avoided due to an equivalent reduction or sequestration of CO2. The objective of this study was to assess the value of SIC stocks in the contiguous United States (U.S.) by soil order, soil depth (0–20, 20–100, 100–200 cm), land resource region (LRR), state, and region using information from the State Soil Geographic (STATSGO) database together with a reported SC-CO2 of $42 (U.S. dollars). With this approach, the calculated monetary value for total SIC storage in the contiguous U.S. was between $3.48T (i.e., $3.48 trillion U.S. dollars, where T = trillion = 1012) and $14.4T, with a midpoint value of $8.34T. Soil orders with the highest (midpoint) values for SIC storage were: 1) Mollisols ($3.57T), 2) Aridisols ($1.99T), and 3) Alfisols ($841B) (i.e., $841B is 841 billion U.S. dollars, where B = billion = 109). When normalized by land area, the soil orders with the highest (midpoint) values for SIC storage were: 1) Vertisols ($3.57 m−2), 2) Aridisols ($2.45 m−2), and 3) Mollisols ($1.77 m−2). Most of the SIC value was associated with the 100–200 cm depth interval, with a midpoint value of $4T and an area-normalized value of $0.54 m−2. The LRRs with the highest (midpoint) values of SIC storage were: 1) D—Western Range and Irrigated Region ($1.77T), 2) H—Central Great Plains Winter Wheat and Range Region ($1.49T), and 3) M—Central Feed Grains and Livestock Region ($1.02T). When normalized by land area, the LRRs were ranked: 1) I—Southwest Plateaus and Plains Range and Cotton Region ($5.36 m−2), 2) J—Southwestern Prairies Cotton and Forage Region ($4.56 m−2), and 3) H—Central Great Plains Winter Wheat and Range Region ($2.56 m−2). States with the highest (midpoint) values for SIC storage were: 1) Texas ($2.96T), 2) New Mexico ($572B), and 3) Montana ($524B). When normalized by land area, the states were ranked: 1) Texas ($4.47 m−2), 2) Utah ($2.77 m−2), and 3) Minnesota ($2.17 m−2). Lastly, regions with the highest (midpoint) values for SIC storage were: 1) South Central ($3.13T), 2) West ($1.98T), and 3) Northern Plains ($1.62T). When normalized by land area, the regions were ranked: 1) South Central ($2.90 m−2), 2) Midwest ($1.32 m−2), and 3) West ($1.02 m−2). Results from this study demonstrate a new approach for assigning monetary values to SIC stocks at various scales based on their role in providing ecosystem services for climate regulation and carbon sequestration.
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Doreau, M., L. Bamière, S. Pellerin, M. Lherm, and M. Benoit. "Mitigation of enteric methane for French cattle: potential extent and cost of selected actions." Animal Production Science 54, no. 9 (2014): 1417. http://dx.doi.org/10.1071/an14207.
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The purpose of this study was (i) to select options for enteric methane abatement in French conditions, while maintaining production and changing practices but not systems, and (ii) to evaluate the extent of abatement and its cost from 2010 to 2030. Two options were selected: supplying unsaturated fats, and using nitrates as a dietary additive in the diet. Unsaturated fats resulted in a higher abatement, because a greater number of animals were concerned by the option, but incurred a higher total cost and a higher cost per ton of CO2-equivalent avoided. The results were sensitive to methodology, and to variations in the choice of fats and in the cost of ingredients, among other factors. Given their cost, evaluated in the frame of a marginal abatement cost curve, these options will require strong public policies for their application.
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Cinar, Yildiray, Peter R. Neal, William G. Allinson, and Jacques Sayers. "Geoengineering and Economic Assessment of a Potential Carbon Capture and Storage Site in Southeast Queensland, Australia." SPE Reservoir Evaluation & Engineering 12, no. 05 (October 27, 2009): 660–70. http://dx.doi.org/10.2118/108924-pa.
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Summary This paper presents geoengineering and economic sensitivity analyses and assessments of the Wunger Ridge flank carbon capture and storage (CCS) site. Both geoengineering and economics are needed to derive the number of wells required to inject a certain amount of CO2 for a given period. A numerical reservoir simulation examines injection rates ranging from 0.5 to 1.5 million tonnes of CO2 year for 25 years of injection. Primary factors affecting the ability to inject CO2 include permeability, formation fracture gradient, aquifer strength, and multiphase flow functions. Secondary factors include the solubility of CO2 in the formation brine, injection well location with respect to the flow barriers/low-permeability aquifers, model geometry including faults, grid size and refinement, and injection well type. Less significant factors include hydrodynamic effects. The economics are assessed using an internally developed technoeconomic model. The model optimizes the CO2 injection cost on the basis of geoengineering data and recent equipment costs. The overall costs depend on the initial costs of CO2 separation and source-to-sink distances and their associated pipeline costs. Secondary cost variations are highly dependent on fracture gradient, permeability, and CO2 injection rates. Depending on the injection characteristics, the specific cost of CO2 avoided is between AUS 62 and 80 per tonne. Introduction Australia's fossil-fuel fired power plants emit 194 million tonnes of CO2 each year (Mt CO2/yr), and approximately 26 Mt/yr of this comes from southeast Queensland. A multidisciplinary study has recently identified the onshore Bowen basin as having potential for geological storage of CO2 (Sayers et al. 2006a). In that paper, geological containment and injectivity and reservoir engineering simulation sensitivities showed that a target injection rate of 1.2 Mt CO2/yr over a 25-year project life span could be achieved (i.e., equivalent to injecting the emissions from a 400 MW gas based power station). This study further examines reservoir engineering and economics sensitivities.
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Castaneda, Monica, Sebastian Zapata, and Andres Aristizabal. "Assessing the Effect of Incentive Policies on Residential PV Investments in Colombia." Energies 11, no. 10 (October 1, 2018): 2614. http://dx.doi.org/10.3390/en11102614.
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As the cost of solar photovoltaic (PV) falls, their potential for transforming modern electricity generation increases. Solar PV provides a simpler way of producing clean and affordable energy, which makes it an attractive investment. Great investments in solar PV have occurred in industrialized countries, but government efforts to promote this technology have not been effective in nonindustrialized countries. Despite this, some of these countries may have a high solar PV potential, such as Colombia, where policies to encourage solar PV are only just starting to take place. Therefore, this paper proposes a simulation model to assess different policies—feed-in tariff, net metering, and capital subsidy—to promote solar PV investments in the Colombian residential sector. Policies are assessed considering the criteria of efficiency and effectiveness. Simulation results suggest that (i) net metering is the most efficient policy with a cost indicator of 20,298 USD/MW; (ii) feed-in tariff is the most effective policy as it reaches the highest level of avoided CO2 emissions—4,792,823 million tons of CO2—and a meaningful PV installed capacity of 7522 MW; (iii) capital subsidy is the least efficient policy as it has the highest cost indicator of 509,616 USD/MW.
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Restrepo-Valencia, Sara, and Arnaldo Walter. "Techno-Economic Assessment of Bio-Energy with Carbon Capture and Storage Systems in a Typical Sugarcane Mill in Brazil." Energies 12, no. 6 (March 22, 2019): 1129. http://dx.doi.org/10.3390/en12061129.
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For significantly reducing greenhouse gas emissions, those from electricity generation should be negative by the end of the century. In this sense, bio-energy with carbon capture and storage (BECCS) technology in sugarcane mills could be crucial. This paper presents a technical and economic assessment of BECCS systems in a typical Brazilian sugarcane mill, considering the adoption of advanced—although commercial—steam cogeneration systems. The technical results are based on computational simulations, considering CO2 capture both from fermentation (released during ethanol production) and due to biomass combustion. The post combustion capture technology based on amine was considered integrated to the mill and to the cogeneration system. A range of energy requirements and costs were taken from the literature, and different milling capacities and capturing rates were considered. Results show that CO2 capture from both flows is technically feasible. Capturing CO2 from fermentation is the alternative that should be prioritized as energy requirements for capturing from combustion are meaningful, with high impacts on surplus electricity. In the reference case, the cost of avoided CO2 emissions was estimated at 62 €/t CO2, and this can be reduced to 59 €/t CO2 in case of more efficient technologies, or even to 48 €/t CO2 in case of larger plants.
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Petersen, Ann Kristin, and Birger Solberg. "Substitution between floor constructions in wood and natural stone: comparison of energy consumption, greenhouse gas emissions, and costs over the life cycle." Canadian Journal of Forest Research 33, no. 6 (June 1, 2003): 1061–75. http://dx.doi.org/10.1139/x03-020.
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This paper compares two floor constructions used at the new airport outside Oslo, one made of solid oak and one made of natural stone, to (i) make an inventory of energy consumption and greenhouse gas (GHG) emissions over the life cycle of the two constructions, (ii) calculate the differences regarding GHG emissions and cost, and (iii) determine which factors have the strongest influence on the results. Manufacturing the wood floor required 1.6 times more energy and produced one-third of the GHG emissions compared with the natural stone floor. Over the life cycle, net GHG emissions can be avoided only if the wood is used as a biofuel after the replacement or demolition of the floor. The wooden floor must be competitive on price to be a cost-efficient action against global warming. Per cubic metre of wood floor, emissions of up to 1.263 t of CO2 equivalents can be avoided by a substitution between the two floor constructions. The factors that have the most influence on the result are carbon fixation on forest land, waste handling of wood, and discount rate, the latter reflecting the relative importance over time given to a unit of GHG emissions.
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Limmeechokchai, Bundit, Somporn Tanatvan, and Ram M. Shrestha. "MITIGATING CO EMISSIONS FROM THE POWER SECTOR: LEAST-COST ANALYSIS OF POLICY OPTIONS IN THAILAND." ASEAN Journal on Science and Technology for Development 19, no. 1 (December 10, 2017): 69–76. http://dx.doi.org/10.29037/ajstd.331.
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Traditionally, the method used in the electricity generation expansion planning has concentrated only on the supply-side options to identify the sequence of generation additions meet the forecasted demand at a minimum cost. Electricity generation expansion planning with both supply- and demand-side options, commonly known as integrated resource planning are also being used in some developed countries. With growing environmental concerns, especially the emission of air-pollutants from the power generation, demand-side management and clean and efficient generation technology options in the power sector development are getting increasing attention. In this paper, we compare the traditional planning approach with integrated resource planning. We also analyze the implications of CO2 reduction targets for the power sector development in the framework of supply side planning by including clean supply-side technologies as candidate plants. During the planning horizon, generation capacity of 365 MW and a cumulative electricity generation or 61,681 GWh would be avoided through the use of efficient demand-side technologies compared to the business-as-usual (BAU) case. When the clean supply-side options considered in the least-cost planning process, three units of 100-MW biomass-based plants are selected. The long run average cost of generation is found to increase by 0.32, 0.65 and 1.61% at the level of CO2 emission reduction target of 5, 10, and 20%, respectively.
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Migo-Sumagang, Maria Victoria P., Monet Concepcion Maguyon-Detras, Martin Gummert, Catalino G. Alfafara, Myra G. Borines, Jewel A. Capunitan, and Nguyen Van Hung. "Rice-Straw-Based Heat Generation System Compared to Open-Field Burning and Soil Incorporation of Rice Straw: An Assessment of Energy, GHG Emissions, and Economic Impacts." Sustainability 12, no. 13 (July 1, 2020): 5327. http://dx.doi.org/10.3390/su12135327.
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Rice is a staple food crop, and its production generates large volumes of agricultural waste, rice straw. Several studies have proven that open-field burning and soil incorporation are unsustainable practices of managing rice straw, but remain as prevalent methods of treating and disposing of rice straw. An alternative solution is to harness the energy from rice straw via a small-scale heat conversion system for paddy drying applications, which can reduce rice grain post-processing costs and improve paddy storage conditions. This study investigated the energy flow, Greenhouse Gas (GHG) emissions, and cost of a small-scale rice-straw-based heat generation (RBHG) system using a downdraft furnace and a dryer simulator setup. The highest input energy and GHG emissions of 92% and 68%, respectively, were from the heat generation stage. The RBHG energy ratio was between 1.4 and 1.7, and the percent net energy was between 39 and 67%. The best case of RBHG offers a possibility of a net GHG avoided (−61 kg CO2-eq Mg−1), while the worst case (856 kg CO2-eq Mg−1) has a net GHG emission comparable with soil incorporation. The average total cost of RBHG is 0.096 USD kWh−1. Overall, RBHG technology has the potential to improve energy flow, GHG emissions, and the cost of rice production systems.
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Arévalo, Paul, Darío Benavides, Juan L. Espinoza, and Francisco Jurado. "Optimal Design and Energy Management for a Grid Connected Renewable Hybrid System (PV-HKT-GRID)." E3S Web of Conferences 173 (2020): 02001. http://dx.doi.org/10.1051/e3sconf/202017302001.
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The integration of renewable energy is transcendental for sustainable development. This article analyses a hybrid grid-connected system composed of renewable energy technologies (photovoltaichydrokinetic), where several scenarios for energy management are proposed. They include a battery system as energy storage and a system without storage but with resale fee to grid, with the aim of determining the best economic and environmental balance. The results show that, by having a (PV-HKT-GRID) system with energy storage and no resale fee to the grid, the Net Present Cost (NPC) is increased by USD $ 132, 760 and the Cost of Energy (COE) decreases $ 0.013/kWh when compared to the grid. In addition, the same hybrid system without energy storage and no resale fee to grid, presents an energy cost savings of $ 0.043/kWh, and an additional cost of USD $ 43, 630. Finally, if a grid resale rate is included in the renewable hybrid system, then the difference is noticeable, the savings in the Cost of Energy is $ 0.073/kWh and presents a saving in the NPC of USD $ 39, 930. In all cases, CO2 emissions have been avoided.
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Erans, María, Dawid Hanak, Jordi Mir, Edward Anthony, and Vasilije Manovic. "Process modelling and techno-economic analysis of natural gas combined cycle integrated with calcium looping." Thermal Science 20, suppl. 1 (2016): 59–67. http://dx.doi.org/10.2298/tsci151001209e.
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Calcium looping (CaL) is promising for large-scale CO2 capture in the power generation and industrial sectors due to the cheap sorbent used and the relatively low energy penalties achieved with this process. Because of the high operating temperatures the heat utilisation is a major advantage of the process, since a significant amount of power can be generated from it. However, this increases its complexity and capital costs. Therefore, not only the energy efficiency performance is important for these cycles, but also the capital costs must be taken into account, i.e. techno-economic analyses are required in order to determine which parameters and configurations are optimal to enhance technology viability in different integration scenarios. In this study the integration scenarios of CaL cycles and natural gas combined cycles (NGCC) are explored. The process models of the NGCC and CaL capture plant are developed to explore the most promising scenarios for NGCC-CaL integration with regards to efficiency penalties. Two scenarios are analysed in detail, and show that the system with heat recovery steam generator (HRSG) before and after the capture plant exhibited better performance of 49.1% efficiency compared with that of 45.7% when only one HRSG is located after the capture plant. However, the techno-economic analyses showed that the more energy efficient case, with two HRSGs, implies relatively higher cost of electricity (COE), 44.1?/MWh, when compared to that of the reference plant system (33.1?/MWh). The predicted cost of CO2 avoided for the case with two HRSGS is 29.3 ?/ton CO2.
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Olczak, Piotr, Małgorzata Olek, Dominika Matuszewska, Artur Dyczko, and Tomasz Mania. "Monofacial and Bifacial Micro PV Installation as Element of Energy Transition—The Case of Poland." Energies 14, no. 2 (January 18, 2021): 499. http://dx.doi.org/10.3390/en14020499.
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The several government subsidies available in Poland contributed to an increased interest in PV installations. Installed PV capacity increased from 100 MW in 2016 up to 2682.7 MW in July 2020. In 2019 alone, 104,000 microinstallations (up to 50 kWp) were installed in Poland. The paper determines the energy gain and the associated reduction of CO2 emissions for two types of solar installation located in Poland. The monofacial solar modules with a power of 5.04 kWp (located in Leki) and bifacial solar modules with a power of 6.1 kWp (located in Bydgoszcz). Both installations use mono-crystalline Si-based 1st generation PV cells. With comparable insolation, a bifacial installation produces approx. 10% (for high insolation) to 28% (for low insolation) more energy than a monofacial PV installation. Avoided annual CO2 emission in relation to the installation capacity ranges from 0.58 to 0.64 Mg/kWp for monofacial and from 0.68 to 0.74 Mg/kWp for bifacial and is on average approx. 16% higher for bifacial installations. Cost-benefit analyses were made. For different electricity prices, the NPV for monofacial and bifacial was determined.
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Hu, Yue, Yachi Gao, Hui Lv, Gang Xu, and Shijie Dong. "A New Integration System for Natural Gas Combined Cycle Power Plants with CO2 Capture and Heat Supply." Energies 11, no. 11 (November 7, 2018): 3055. http://dx.doi.org/10.3390/en11113055.
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Although carbon mitigation in power industry is attracting more and more attention around the world, the large scale application of carbon capture technology is obstructed because of the enormous energy consumption and huge capital investment required. In this study, an integrated system with power generation, CO2 capture and heat supply are proposed, which adopts three measures to reutilize the waste heat released from the CO2 capture process, including extracted steam recirculation, a CO2 Rankine cycle and a radiant floor heat subsystem. Amongst these measures, the radiant floor heat subsystem can efficiently reuse the relatively low temperature waste energy in the absorbent cooler. Through thermodynamic analysis, it is determined that the power output of the new integrated system is 19.48 MW higher compared with the decarbonization Natural Gas Combined Cycle (NGCC) power plant without system integration. On the other hand, 247.59 MW of heat can be recovered through the radiant floor heat subsystem, leading to an improved overall energy efficiency of 73.6%. In terms of the economic performance, the integration requires only 2.6% more capital investment than a decarbonization NGCC power plant without system integration and obtains extra revenue of 3.40 $/MWh from the simultaneous heat supply, which reduces the cost of CO2 avoided by 22.3%. The results prove the economic and efficiency potential of a NGCC power plant integrated with carbon capture, which may promote the industrial demonstration of carbon capture theology.
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Szima, Szabolcs, Carlos Arnaiz del Pozo, Schalk Cloete, Szabolcs Fogarasi, Ángel Jiménez Álvaro, Ana-Maria Cormos, Calin-Cristian Cormos, and Shahriar Amini. "Techno-Economic Assessment of IGCC Power Plants Using Gas Switching Technology to Minimize the Energy Penalty of CO2 Capture." Clean Technologies 3, no. 3 (August 10, 2021): 594–617. http://dx.doi.org/10.3390/cleantechnol3030036.
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Cost-effective CO2 capture and storage (CCS) is critical for the rapid global decarbonization effort recommended by climate science. The increase in levelized cost of electricity (LCOE) of plants with CCS is primarily associated to the large energy penalty involved in CO2 capture. This study therefore evaluates three high-efficiency CCS concepts based on integrated gasification combined cycles (IGCC): (1) gas switching combustion (GSC), (2) GSC with added natural gas firing (GSC-AF) to increase the turbine inlet temperature, and (3) oxygen production pre-combustion (OPPC) that replaces the air separation unit (ASU) with more efficient gas switching oxygen production (GSOP) reactors. Relative to a supercritical pulverized coal benchmark, these options returned CO2 avoidance costs of 37.8, 22.4 and 37.5 €/ton (including CO2 transport and storage), respectively. Thus, despite the higher fuel cost and emissions associated with added natural gas firing, the GSC-AF configuration emerged as the most promising solution. This advantage is maintained even at CO2 prices of 100 €/ton, after which hydrogen firing can be used to avoid further CO2 cost escalations. The GSC-AF case also shows lower sensitivity to uncertain economic parameters such as discount rate and capacity factor, outperforms other clean energy benchmarks, offers flexibility benefits for balancing wind and solar power, and can achieve significant further performance gains from the use of more advanced gas turbine technology. Based on all these insights, the GSC-AF configuration is identified as a promising solution for further development.
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CARON, JUSTIN, STUART M. COHEN, MAXWELL BROWN, and JOHN M. REILLY. "EXPLORING THE IMPACTS OF A NATIONAL U.S. CO2 TAX AND REVENUE RECYCLING OPTIONS WITH A COUPLED ELECTRICITY-ECONOMY MODEL." Climate Change Economics 09, no. 01 (February 2018): 1840015. http://dx.doi.org/10.1142/s2010007818400158.
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This paper provides a comprehensive exploration of the impacts of economy-wide CO2 taxes in the U.S. simulated using a detailed electric sector model [the National Renewable Energy Laboratory’s Regional Energy Deployment System (ReEDS)] linked with a computable general equilibrium model of the U.S. economy [the Massachusetts Institute of Technology’s U.S. Regional Energy Policy (USREP) model]. We implement various tax trajectories and options for using the revenue collected by the tax and describe their impact on household welfare and its distribution across income levels. Overall, we find that our top-down/bottom-up models affects estimates of the distribution and cost of emission reductions as well as the amount of revenue collected, but that these are mostly insensitive to the way the revenue is recycled. We find that substantial abatement opportunities through fuel switching and renewable penetration in the electricity sector allow the economy to accommodate extensive emissions reductions at relatively low cost. While welfare impacts are largely determined by the choice of revenue recycling scheme, all tax levels and schemes provide net benefits when accounting for the avoided global climate change benefits of emission reductions. Recycling revenue through capital income tax rebates is more efficient than labor income tax rebates or uniform transfers to households. While capital tax rebates substantially reduce the overall costs of emission abatement, they profit high income households the most and are regressive. We more generally identify a clear trade-off between equity and efficiency across the various recycling options. However, we show through a set of hybrid recycling schemes that it is possible to limit inequalities in impacts, particularly those on the lowest income households, at relatively little incremental cost.
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Qvist, Staffan, Paweł Gładysz, Łukasz Bartela, and Anna Sowiżdżał. "Retrofit Decarbonization of Coal Power Plants—A Case Study for Poland." Energies 14, no. 1 (December 28, 2020): 120. http://dx.doi.org/10.3390/en14010120.
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Out of 2 TWe of coal power plant capacity in operation globally today, more than half is less than 14 years old. Climate policy related to limiting CO2-emissions makes the longer-term operation of these plants untenable. In this study, we assess the spectrum of available options for the future of both equipment and jobs in the coal power sector by assessing the full scope of “retrofit decarbonization” options. Retrofit decarbonization is an umbrella term that includes adding carbon capture, fuel conversion, and the replacement of coal boilers with new low-carbon energy sources, in each case re-using as much of the existing equipment as economically practicable while reducing or eliminating emissions. This article explores this idea using the Polish coal power fleet as a case study. Retrofit decarbonization in Poland was shown to be most attractive using high-temperature small modular nuclear reactors (SMRs) to replace coal boilers, which can lower upfront capital costs by ~28–35% and levelized cost of electricity by 9–28% compared to a greenfield installation. If retrofit decarbonization is implemented globally by the late 2020s, up to 200 billion tons of otherwise-committed CO2-emissions could be avoided.
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Chazdon, Robin L., Eben N. Broadbent, Danaë M. A. Rozendaal, Frans Bongers, Angélica María Almeyda Zambrano, T. Mitchell Aide, Patricia Balvanera, et al. "Carbon sequestration potential of second-growth forest regeneration in the Latin American tropics." Science Advances 2, no. 5 (May 2016): e1501639. http://dx.doi.org/10.1126/sciadv.1501639.
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Regrowth of tropical secondary forests following complete or nearly complete removal of forest vegetation actively stores carbon in aboveground biomass, partially counterbalancing carbon emissions from deforestation, forest degradation, burning of fossil fuels, and other anthropogenic sources. We estimate the age and spatial extent of lowland second-growth forests in the Latin American tropics and model their potential aboveground carbon accumulation over four decades. Our model shows that, in 2008, second-growth forests (1 to 60 years old) covered 2.4 million km2 of land (28.1% of the total study area). Over 40 years, these lands can potentially accumulate a total aboveground carbon stock of 8.48 Pg C (petagrams of carbon) in aboveground biomass via low-cost natural regeneration or assisted regeneration, corresponding to a total CO2 sequestration of 31.09 Pg CO2. This total is equivalent to carbon emissions from fossil fuel use and industrial processes in all of Latin America and the Caribbean from 1993 to 2014. Ten countries account for 95% of this carbon storage potential, led by Brazil, Colombia, Mexico, and Venezuela. We model future land-use scenarios to guide national carbon mitigation policies. Permitting natural regeneration on 40% of lowland pastures potentially stores an additional 2.0 Pg C over 40 years. Our study provides information and maps to guide national-level forest-based carbon mitigation plans on the basis of estimated rates of natural regeneration and pasture abandonment. Coupled with avoided deforestation and sustainable forest management, natural regeneration of second-growth forests provides a low-cost mechanism that yields a high carbon sequestration potential with multiple benefits for biodiversity and ecosystem services.
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Dorrian, Cathy, Jim Ferguson, Kim Ah-See, Catriona Barr, Kushik Lalla, Marjon van der Pol, Lynda McKenzie, and Richard Wootton. "Head and neck cancer assessment by flexible endoscopy and telemedicine." Journal of Telemedicine and Telecare 15, no. 3 (April 2009): 118–21. http://dx.doi.org/10.1258/jtt.2009.003004.
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We have conducted a feasibility study to establish whether ENT tele-endoscopy would be a suitable method of service delivery for patients who live in the Shetland Islands. Ten clinics were conducted over a period of 17 months using ISDN-based videoconferencing at a bandwidth of 384 kbit/s. A total of 42 patients were seen in Aberdeen via videoconferencing for a head and neck cancer assessment. Feasibility was confirmed after the first 20 patients, following positive feedback from all concerned and the absence of any significant clinical or technical problems. A total of 42 journeys was avoided, each journey saving 123 kg CO2 per person. A preliminary cost analysis showed that the threshold at which tele-ENT became cheaper than travel was a workload of 35 patients/year. The actual workload during the pilot study was 29 patients/year. A national telemedicine service for the initial assessment of potential malignancy has the potential to reduce unnecessary transfers to specialist centres, with accompanying reductions in carbon emissions.
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CHEN, XUEYE, YUE TIAN, and SHUAI ZHANG. "CO2 LASER ABLATION MICROCHANNEL BASED ON KOCH FRACTAL PRINCIPLE." Surface Review and Letters 27, no. 05 (July 31, 2019): 1950141. http://dx.doi.org/10.1142/s0218625x19501415.
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In this paper, we focussed on the processing power of CO2 laser systems and the impact of scanning speed, scanning power and number of scans on the quality of microchannels. We created microchannels which are based on the Koch fractal principle through a flexible and low-cost CO2 laser system. The processing and manufacturing method of Koch fractal micromixer on polymethyl methacrylate (PMMA) substrate was also studied. The microchannel structure based on the Koch fractal principle can increase the contact area and mixing time of the fluid and improve the mixing efficiency of the micromixer. In the experiment, our speed is 2, 4 and 6[Formula: see text]mm/s, the number of scans is 2/3/4 times and the power is 4, 8 and 12[Formula: see text]W. As the power and number of scans increase and the speed decreases, the width and depth of the microchannel are changed more clearly, which contributes to the successful thermal bonding of the Koch fractal micromixer and avoids thermal bonding due to overvoltage. By comparing the experimental data, we found that the width and depth of the channel are ideal when the speed is 2[Formula: see text]mm/s, the number of scans is 4 and the power is 12[Formula: see text]W. Because of the lower cost of PMMA, the use of CO2 laser systems to fabricate microchannels on PMMA substrates will have broad application value, reduce cost and be easier to manufacture.
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Barelli, Linda, Gianni Bidini, Panfilo Andrea Ottaviano, and Michele Perla. "Liquefied Synthetic Natural Gas Produced through Renewable Energy Surplus: Impact Analysis on Vehicular Transportation by 2040 in Italy." Gases 1, no. 2 (April 21, 2021): 80–91. http://dx.doi.org/10.3390/gases1020007.
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Time mismatch between renewable energy production and consumption, grid congestion issues, and consequent production curtailment lead to the need for energy storage systems to allow for a greater renewable energy sources share in future energy scenarios. A power-to-liquefied synthetic natural gas system can be used to convert renewable energy surplus into fuel for heavy duty vehicles, coupling the electric and transportation sectors. The investigated system originates from power-to-gas technology, based on water electrolysis and CO2 methanation to produce a methane rich mixture containing H2, coupled with a low temperature gas upgrading section to meet the liquefied natural gas requirements. The process uses direct air CO2 capture to feed the methanation section; mol sieve dehydration and cryogenic distillation are implemented to produce a liquefied natural gas quality mixture. The utilization of this fuel in heavy duty vehicles can reduce greenhouse gases emissions if compared with diesel and natural gas, supporting the growth of renewable fuel consumption in an existing market. Here, the application of power-to-liquefied synthetic natural gas systems is investigated at a national level for Italy by 2040, assessing the number of plants to be installed in order to convert the curtailed energy, synthetic fuel production, and consequent avoided greenhouse gases emissions through well-to-wheel analysis. Finally, plant investment cost is preliminarily investigated.
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Abdel-hamed, Alaa M., Kamel Ellissy, Ahmed R. Adly, and H. Abdelfattah. "Optimal Sizing and Design of Isolated Micro-Grid systems." International Journal of Environmental Science & Sustainable Development 4, no. 3 (December 30, 2019): 1. http://dx.doi.org/10.21625/essd.v4i3.673.
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Micro-grid and standalone schemes are emerging as a viable mixed source of electricity due to interconnected costly central power plants and associated faults as well as brownouts and blackouts in additions to costly fuels. Micro-Grid (MG) is gaining very importance to avoid or decrease these problems. The objective of this paper is to design an optimal sizing and energy management scheme of an isolated MG. The MG is suggested to supply load located in El-shorouk Academy, Egypt between 30.119 latitudes and 31.605 longitudes. The components of the MG are selected and designed for achieving minimum Total Investment Cost (TIC) with CO2 emissions limitations. This is accomplished by a search and optimization MATLAB code used with Particle Swarm Optimization (PSO) and Genetic Algorithm (GA) techniques. The use of Diesel Generators (DGs) is minimized by limiting the gaseous CO2 emissions as per targeted allowable amount. A comparison is accomplished for investigating the CO2 emissions constraints effects on the TIC in $/year and annual cost of energy in $/kWh. The obtained results verified and demonstrated that the designed MG configuration scheme is able to feed the energy entailed by the suggested load cost effectively and environmental friendly.
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Arena, Claudio, Mario Genco, Alessio Lombardo, Ignazio Meli, and Mario Mazzola. "A Cost–Benefit Based, Parametric Procedure to Screen Existing Irrigation and Municipal Supply Reservoirs for Wind Energy Storage." Water 10, no. 12 (December 9, 2018): 1813. http://dx.doi.org/10.3390/w10121813.
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Pumped hydro storage (PHS) is one of the more suitable energy storage technologies to provide bulk storage of intermittent renewable energy sources (RES) such as wind. Since the main limiting factors to the expansion of this mature technology are environmental and financial concerns, the use of an existing reservoir can help mitigate both types of impacts. In addition, the high number of reservoirs for municipal and irrigation supply in many areas of the world makes the idea of using PHS as a relatively diffuse, open-market, technology for RES management attractive. These arguments in favor of PHS must, however, be convincing for investors and regulators from an economic standpoint. To this end, this paper presents a methodological tool to screen the feasibility of a PHS facility around an existing reservoir based on the principles of cost–benefit analysis, calibrated with data from Sicily, Italy. Each potential plant is characterized by two locational and two plant-specific parameters. Costs and benefits are assessed through a simulation model of the storage–release process on an hourly basis. Costs include both investment, and operation and maintenance expenditures, while the benefits considered include the opportunity cost of the current energy mix substituted by the stored energy, and the avoided CO2 emissions. The evaluation exercise is carried out parametrically, i.e., looking at a large number of combinations of the four parameters, in order to explore a wide range of possible plant configurations and to identify optimal ones under different locational conditions. A sensitivity analysis performed on models’ parameters points out the sensitivity of results to benefit, rather than cost-related, input parameters, such as the efficiency of the generating and pumping system and the opportunity cost of energy.
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Griscom, Bronson W., Justin Adams, Peter W. Ellis, Richard A. Houghton, Guy Lomax, Daniela A. Miteva, William H. Schlesinger, et al. "Natural climate solutions." Proceedings of the National Academy of Sciences 114, no. 44 (October 16, 2017): 11645–50. http://dx.doi.org/10.1073/pnas.1710465114.
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Better stewardship of land is needed to achieve the Paris Climate Agreement goal of holding warming to below 2 °C; however, confusion persists about the specific set of land stewardship options available and their mitigation potential. To address this, we identify and quantify “natural climate solutions” (NCS): 20 conservation, restoration, and improved land management actions that increase carbon storage and/or avoid greenhouse gas emissions across global forests, wetlands, grasslands, and agricultural lands. We find that the maximum potential of NCS—when constrained by food security, fiber security, and biodiversity conservation—is 23.8 petagrams of CO2 equivalent (PgCO2e) y−1 (95% CI 20.3–37.4). This is ≥30% higher than prior estimates, which did not include the full range of options and safeguards considered here. About half of this maximum (11.3 PgCO2e y−1) represents cost-effective climate mitigation, assuming the social cost of CO2 pollution is ≥100 USD MgCO2e−1 by 2030. Natural climate solutions can provide 37% of cost-effective CO2 mitigation needed through 2030 for a >66% chance of holding warming to below 2 °C. One-third of this cost-effective NCS mitigation can be delivered at or below 10 USD MgCO2−1. Most NCS actions—if effectively implemented—also offer water filtration, flood buffering, soil health, biodiversity habitat, and enhanced climate resilience. Work remains to better constrain uncertainty of NCS mitigation estimates. Nevertheless, existing knowledge reported here provides a robust basis for immediate global action to improve ecosystem stewardship as a major solution to climate change.
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Matsui, Akihisa, Naoya Ogiyama, Takumi Endo, Jun Arakawa, and Takao Nakagaki. "Performance Evaluation of Phase Separation Process Using High-concentration AMP Promoted by MAPA for CO2 Capture." MATEC Web of Conferences 333 (2021): 16001. http://dx.doi.org/10.1051/matecconf/202133316001.
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Reduction of the energy penalty and cost of CO2 capture from concentrated gas streams using amine-based solutions can be achieved by minimizing the energy penalty in the solvent regeneration process. High concentration 2-Amino-2-methyl-1-propanol (AMP) solution precipitates as a carbonate when enough CO2 has been absorbed. By sending the separated carbonate to the stripper, the sensible heat of regeneration can be reduced. However, previous testing using 50 weight percent AMP solution mixed with Piperazine (PZ) with solid-liquid separation showed that the CO2 recovery rate was limited to 65% due to the lack of PZ regeneration. To improve the CO2 recovery rate, a novel solution and injection process were developed. N-Methyl-1,3-diaminopropane (MAPA) was selected as an alternative promoter based on reaction rate testing. Various tests were employed to characterize the behaviour of the AMP/MAPA solution under CO2 capture and recovery conditions. The injection point was relocated to avoid the inhibition of CO2 absorption observed when CO2 semi-lean liquid was sent to the upper portion of the absorber. The CO2 recovery rate and the precipitation quantity were simulated using a model built in Aspen Plus®. The novel solution and injection set-up were evaluated experimentally by a bench-scale apparatus.
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Matsui, Akihisa, Naoya Ogiyama, Takumi Endo, Jun Arakawa, and Takao Nakagaki. "Performance Evaluation of Phase Separation Process Using High-concentration AMP Promoted by MAPA for CO2 Capture." MATEC Web of Conferences 333 (2021): 16001. http://dx.doi.org/10.1051/matecconf/202133316001.
Full textAbstract:
Reduction of the energy penalty and cost of CO2 capture from concentrated gas streams using amine-based solutions can be achieved by minimizing the energy penalty in the solvent regeneration process. High concentration 2-Amino-2-methyl-1-propanol (AMP) solution precipitates as a carbonate when enough CO2 has been absorbed. By sending the separated carbonate to the stripper, the sensible heat of regeneration can be reduced. However, previous testing using 50 weight percent AMP solution mixed with Piperazine (PZ) with solid-liquid separation showed that the CO2 recovery rate was limited to 65% due to the lack of PZ regeneration. To improve the CO2 recovery rate, a novel solution and injection process were developed. N-Methyl-1,3-diaminopropane (MAPA) was selected as an alternative promoter based on reaction rate testing. Various tests were employed to characterize the behaviour of the AMP/MAPA solution under CO2 capture and recovery conditions. The injection point was relocated to avoid the inhibition of CO2 absorption observed when CO2 semi-lean liquid was sent to the upper portion of the absorber. The CO2 recovery rate and the precipitation quantity were simulated using a model built in Aspen Plus®. The novel solution and injection set-up were evaluated experimentally by a bench-scale apparatus.
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Guarino, Stefania, Pietro Catrini, Alessandro Buscemi, Valerio Lo Brano, and Antonio Piacentino. "Assessing the Energy-Saving Potential of a Dish-Stirling Con-Centrator Integrated Into Energy Plants in the Tertiary Sector." Energies 14, no. 4 (February 22, 2021): 1163. http://dx.doi.org/10.3390/en14041163.
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Energy consumed for air conditioning in residential and tertiary sectors accounts for a large share of global use. To reduce the environmental impacts burdening the covering of such demands, the adoption of renewable energy technologies is increasing. In this regard, this paper evaluates the energy and environmental benefits achievable by integrating a dish-Stirling concentrator into energy systems used for meeting the air conditioning demand of an office building. Two typical reference energy plants are assumed: (i) a natural gas boiler for heating purposes and air-cooled chillers for the cooling periods, and (ii) a reversible heat pump for both heating and cooling. For both systems, a dish-Stirling concentrator is assumed to operate first in electric-mode and then in a cogenerative-mode. Detailed models are adopted for plant components and implemented in the TRNSYS environment. Results show that when the concentrator is operating in electric-mode the electricity purchased from the grid decreases by about 72% for the first plant, and 65% for the second plant. Similar reductions are obtained for CO2 emissions. Even better performance may be achieved in the case of the cogenerative-mode. In the first plant, the decrease in natural gas consumption is about 85%. In the second plant, 66.7% is the percentage increase in avoided electricity purchase. The integration of the dish-Stirling system allows promising energy-saving and reduction in CO2 emissions. However, both a reduction in capital cost and financial support are needed to encourage the diffusion of this technology.
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Barrella, Roberto, Irene Priego, José Ignacio Linares, Eva Arenas, José Carlos Romero, and Efraim Centeno. "Feasibility Study of a Centralised Electrically Driven Air Source Heat Pump Water Heater to Face Energy Poverty in Block Dwellings in Madrid (Spain)." Energies 13, no. 11 (May 28, 2020): 2723. http://dx.doi.org/10.3390/en13112723.
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Energy poverty can be defined as the inability to pay the bills that are required for maintaining the comfort conditions (usually in winter) in dwellings. The use of energy efficient systems is one way forward to mitigate this problem, with one option being the electrically driven air source heat pump water heater. This paper assesses the performance of a centralised heat pump (200 kW of heating capacity) to meet the space heating demand of block dwellings in Madrid (tier four out of five in winter severity in Spain). Two models have been developed to obtain the following variables: the hourly thermal energy demand and the off-design heat pump performance. The proposed heat pump is driven by a motor with variable rotational speed to modulate the heating capacity in an efficient way. A back-up system is also considered to meet the peak demand. A levelised cost of heating of 92.22 €/MWh is obtained for a middle-level energy efficiency in housing (class E, close to D). Moreover, the following energy-environmental parameters have been achieved: more than 74% share of renewable energy in primary energy and 131.7 g CO2 avoided per kWh met. A reduction of 60% in the heating cost per dwelling is obtained if an energy retrofit is carried out, improving the energy performance class from E to C. These results prove that the proposed technology is among the most promising measures for addressing energy poverty in vulnerable households.
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Brown, Marilyn A., Puneet Dwivedi, Sudhagar Mani, Daniel Matisoff, Jacqueline E. Mohan, Jeffrey Mullen, Michael Oxman, et al. "A framework for localizing global climate solutions and their carbon reduction potential." Proceedings of the National Academy of Sciences 118, no. 31 (July 26, 2021): e2100008118. http://dx.doi.org/10.1073/pnas.2100008118.
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Localized carbon reduction strategies are especially critical in states and regions that lack top-down climate leadership. This paper illustrates the use of coupled systems in assessments of subnational climate solutions with a case study of Georgia, a state located in the southeastern United States that does not have statewide climate goals or plans. The paper illustrates how robust place-specific plans for climate action could be derived from foundational global and national work and by embedding that research into the context of socio-ecological-technological systems. Our replicable methodology advances the traditional additive sectoral wedge analysis of carbon abatement potential by incorporating solution interdependencies and by spanning both carbon sources and sinks. We estimate that a system of 20 solutions could cut Georgia’s carbon footprint by 35% in 2030 relative to a business-as-usual forecast and by 50% relative to Georgia’s emissions in 2005. We also produce a carbon abatement cost curve that aligns private and social costs as well as benefits with units of avoided CO2-e. The solutions are affiliated with various social co-costs and co-benefits that highlight societal concerns extending beyond climate impacts, including public health, environmental quality, employment, and equity.
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Zhan, Tung Sheng. "Dynamic Economic Dispatch Incorporating Wind Power with Carbon Trading Scheme." Advanced Materials Research 487 (March 2012): 94–98. http://dx.doi.org/10.4028/www.scientific.net/amr.487.94.
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This paper proposed an issue aiming at the goal of pierces the relationship between the emission trading scheme and dynamic economic dispatch (DED) problem for the electricity utility. A model of the CO2 emission trading market will be investigated and introduced into DED problem incorporating wind power plant and independent power providers (IPPs). Then, an accelerated particle swarm optimization (APSO) algorithm is introduced in order to avoid prematurity convergence of the original PSO and improve searching efficiency. Thus, APSO was used to determine the DED strategy of the utility with incorporation of wind power generation and contribution of IPPs. The CO2 emission trading is treated as the inner-cost, and the superfluous CO2 quotas will be resale into the market, whereas the shortage quotas can be purchased from the market.
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Hooper, B., B. Koppe, and L. Murray. "COMMERCIAL AND TECHNICAL ISSUES FOR LARGE-SCALE CARBON CAPTURE AND STORAGE PROJECTS—A GIPPSLAND BASIN STUDY." APPEA Journal 46, no. 1 (2006): 435. http://dx.doi.org/10.1071/aj05025.
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The Latrobe Valley in Victoria’s Gippsland Basin is the location of one of Australia’s most important energy resources—extremely thick, shallow brown coal seams constituting total useable reserves of more than 50,000 million tonnes. Brown coal has a higher moisture content than black coal and generates more CO2 emissions per unit of useful energy when combusted. Consequently, while the Latrobe Valley’s power stations provide Australia’s lowest- cost bulk electricity, they are also responsible for over 60 million tonnes of CO2 emissions per year—over half of the Victorian total. In an increasingly carbon constrained world the ongoing development of the Latrobe Valley brown coal resource is likely to require a drastic reduction in the CO2 emissions from new coal use projects—and carbon capture and storage (CCS) has the potential to meet such deep cuts. The offshore Gippsland Basin, the site of major producing oil and gas fields, has the essential geological characteristics to provide a high-volume, low-cost site for CCS. The importance of this potential to assist the continuing use of the nation’s lowest-cost energy source prompted the Australian Government to fund the Latrobe Valley CO2 Storage Assessment (LVCSA).The LVCSA proposal was initiated by Monash Energy (formerly APEL, and now a 100% subsidiary of Anglo American)—the proponent of a major brown coal-to-liquids plant in the Latrobe Valley. Monash Energy’s plans for the 60,000 BBL per day plant include CCS to store about 13 million tonnes of CO2 per year. The LVCSA, undertaken for Monash Energy by the Cooperative Research Centre for Greenhouse Gas Technologies (CO2CRC), provides a medium to high-level technical and economic characterisation of the volume and cost potential for secure geosequestration of CO2 produced by the use of Latrobe Valley brown coal (Hooper et al, 2005a). The assessment’s scope includes consideration of the interaction between CO2 injection and oil and gas production, and its findings have been publicly released for use by CCS proponents, oil and gas producers and all other interested parties as an executive summary, (Hooper et al, 2005b), a fact sheet (Hooper et al, 2005c) and a presentation (Hooper et al, 2005d)).The LVCSA identifies the key issues and challenges for implementing CCS in the Latrobe Valley and provides a reference framework for the engagement of stakeholders. In effect the LVCSA constitutes a pre-feasibility study for the implementation of geosequestration in support of the continuing development of Victoria’s brown coal resources.The LVCSA findings indicate that the Gippsland Basin has sufficient capacity to safely and securely store large volumes of CO2 and may provide a viable means of substantially reducing greenhouse gas emissions from coal-fired power plants and other projects using brown coal in the Latrobe Valley. The assessment also indicates that CO2 injection could well be designed to avoid any adverse impact on adjacent oil and gas production, so that CO2 injection can begin near fields that have not yet come to the end of their productive lives. However, CCS proposals involving adjacent injection and production will require more detailed risk management strategies and continuing cooperation between prospective injectors and existing producers.
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de Vries, I. E., M. Janssens, and S. J. Hulshoff. "A specialised delivery system for stratospheric sulphate aerosols (part 2): financial cost and equivalent CO2 emission." Climatic Change 162, no. 1 (May 6, 2020): 87–103. http://dx.doi.org/10.1007/s10584-020-02686-6.
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Abstract Temporary stratospheric aerosol injection (SAI) using sulphate compounds could help avoid some of the adverse and irreversible impacts of global warming, but comprises many risks and uncertainties. Among these, the direct financial cost and carbon emissions of potential SAI delivery systems have hitherto received only modest attention. Therefore, this paper quantifies the initial and operating financial costs and initial and operating equivalent CO2 (CO2eq) emissions of the specialised aircraft-based SAI delivery system developed with relatively high-fidelity tools in part 1 of this series. We analyse an interval of operating conditions, within which we devote special attention to four injection scenarios outlined in part 1: Three scenarios where H2SO4 vapour is directly injected at several dispersion rates and one SO2 injection scenario. We estimate financial cost through Raymer’s adjustment of Rand Corporation’s Development and Production Costs for Aircraft (DAPCA) model, augmented by additional data. CO2eq emission is computed from existing data and the computed fuel consumption for each of the scenarios. The latter estimates include an emission weighting factor to account for non-CO2 aircraft combustion products at altitude. For direct H2SO4 injection, both financial cost and CO2eq emission are sensitive to the design dispersion rate. For scenarios where higher dispersion rates are achieved, the delivery system’s cost and CO2eq are relatively small compared with the presumed benefits of SAI. The most optimistic H2SO4 scenario is found to have a financial cost and CO2eq emission similar to that of SO2 injection, while potentially allowing for reductions in the annual mass of sulphur injected to achieve a target negative radiative forcing. The estimates of financial cost and CO2eq emission were subjected to sensitivity analyses in several key parameters, including aircraft operational empty weight, engine specific fuel consumption, fuel price and aerosol price. The results indicate that the feasibility of the considered scenarios is robust.
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Luisetto, Igor, Maria Rita Mancini, Livia Della Seta, Rosa Chierchia, Giuseppina Vanga, Maria Luisa Grilli, and Stefano Stendardo. "CaO–CaZrO3 Mixed Oxides Prepared by Auto–Combustion for High Temperature CO2 Capture: The Effect of CaO Content on Cycle Stability." Metals 10, no. 6 (June 5, 2020): 750. http://dx.doi.org/10.3390/met10060750.
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Cycling high temperature CO2 capture using CaO–based solid sorbents, known as the calcium looping (CaL) process, is gaining considerable scientific and industrial interest due to the high theoretical sorbent capacity (0.78 gCO2/gCaO), the low specific cost, and the negligible environmental impact of the employed materials. In this work, we investigated the self–combustion synthesis of CaO–CaZrO3 sorbents with different CaO contents (40, 60, and 80 wt%) for use in the CaL process. CaZrO3 was used as a spacer to avoid CaO grains sintering at high temperature and to reduce the diffusional resistances of CO2 migrating towards the inner grains of the synthetic sorbent. Samples were characterized by X–ray diffraction (XRD), Brunauer–Emmett–Teller (BET), and scanning electron microscopy (SEM) analyses. The reaction between CO2 and CaO (i.e., carbonation) was carried out in 20 vol% CO2 at 650 °C and calcination (i.e., decomposition of CaCO3 to CaO and CO2) at 900 °C in pure Ar or with 85 vol% CO2 using a thermogravimetric analyzer (thermogravimetric/differential thermal analysis (TG–DTA)). The most stable sorbent was with 40 wt% of CaO showing a CO2 uptake of up to 0.31 g CO2/gsorbent and 0.26 g CO2/gsorbent operating under mild and severe conditions, respectively. The experimental data corroborated the prediction of the shrinking core spherical model in the first phase of the carbonation. A maximum reaction rate of 0.12–0.13 min−1 was evaluated in the first cycle under mild and severe conditions of regeneration.
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Montes, María José, José Ignacio Linares, Rubén Barbero, and Beatriz Yolanda Moratilla. "Optimization of a New Design of Molten Salt-to-CO2 Heat Exchanger Using Exergy Destruction Minimization." Entropy 22, no. 8 (August 12, 2020): 883. http://dx.doi.org/10.3390/e22080883.
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One of the ways to make cost-competitive electricity, from concentrated solar thermal energy, is increasing the thermoelectric conversion efficiency. To achieve this objective, the most promising scheme is a molten salt central receiver, coupled to a supercritical carbon dioxide cycle. A key element to be developed in this scheme is the molten salt-to-CO2 heat exchanger. This paper presents a heat exchanger design that avoids the molten salt plugging and the mechanical stress due to the high pressure of the CO2, while improving the heat transfer of the supercritical phase, due to its compactness with a high heat transfer area. This design is based on a honeycomb-like configuration, in which a thermal unit consists of a circular channel for the molten salt surrounded by six smaller trapezoidal ducts for the CO2. Further, an optimization based on the exergy destruction minimization has been accomplished, obtained the best working conditions of this heat exchanger: a temperature approach of 50 °C between both streams and a CO2 pressure drop of 2.7 bar.
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BARRON, ALEXANDER R., ALLEN A. FAWCETT, MARC A. C. HAFSTEAD, JAMES R. MCFARLAND, and ADELE C. MORRIS. "POLICY INSIGHTS FROM THE EMF 32 STUDY ON U.S. CARBON TAX SCENARIOS." Climate Change Economics 09, no. 01 (February 2018): 1840003. http://dx.doi.org/10.1142/s2010007818400031.
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The Stanford Energy Modeling Forum exercise 32 (EMF 32) used 11 different models to assess emissions, energy, and economic outcomes from a plausible range of economy-wide carbon price policies to reduce carbon dioxide (CO[Formula: see text] emissions in the United States. Here we discuss the most policy-relevant results of the study, mindful of the strengths and weaknesses of current models. Across all models, carbon prices lead to significant reductions in CO2 emissions and conventional pollutants, with the vast majority of the reductions occurring in the electricity sector. Importantly, emissions reductions do not significantly depend on the rebate or tax cut used to return revenues to the economy. Expected economic costs, as modeled by either GDP or welfare, are modest, but vary across models. These costs are offset by benefits from avoided climate damages and health benefits from reductions in conventional air pollution. Using revenues to reduce preexisting capital or labor taxes reduces costs in most models relative to lump-sum rebates, but the size of the cost reductions varies significantly. Devoting at least some revenue to household rebates can significantly reduce adverse impacts on low income households. Carbon prices at $25/ton or even lower levels cause significant shifts away from coal as an energy source with responses of other energy sources highly dependent upon technology cost assumptions. Beyond 2030, we conclude that model uncertainties are too large to make quantitative results useful for near-term policy design. We close by describing recommendations for policymakers on interacting with model results in the future.
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Shu, Yong Bao, Wen Jun Li, and Zhong Xue Li. "The Technology of Liquid CO2 Used for Fire Prevention and the Related Device." Advanced Materials Research 347-353 (October 2011): 1642–46. http://dx.doi.org/10.4028/www.scientific.net/amr.347-353.1642.
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In order to avoid spontaneous combustion of coal, reduce cost and improve the effect of fire prevention and extinction, this essay brings about the technology and related device to prevent and control the spontaneous combustion of coal based on the properties of fire prevention and extinction of the liquid CO2 toward fire area, such as: asphyxiation oxygen, cooling down and inerting. The technical difficulties such as the safety packing, transportation and perfusion to the fire area underground of liquid CO2 are solved. The liquid CO2 is transported safely to the fire area underground and are infused to fire area in the form of liquid. The on site operation and test proved that the fire-fighting technology and device has the following advantages: high speed, simple operation, adjusted continuously, stable operation, and significant and reliable fire prevention effect. It accords with the actual application and has great practical value.
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Harding, Frances C., Alan T. James, and Hazel E. Robertson. "The engineering challenges of CO2 storage." Proceedings of the Institution of Mechanical Engineers, Part A: Journal of Power and Energy 232, no. 1 (February 2018): 17–26. http://dx.doi.org/10.1177/0957650918756542.
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The permanent underground storage of large quantities of anthropogenic carbon dioxide from thermal energy and industrial plant is widely recognised as a fundamental tool which can help to avoid the worst impacts of climate change. To achieve this effectiveness, it will require widespread global deployment in a new industry which would rival the current oil and gas industry in its scale and ambition. Many of the technologies for carbon dioxide storage are the adaptations of oil and gas technology, but there are some important differences. These arise from: 1. the thermodynamic properties of carbon dioxide, 2. the essential requirement for long-term storage site integrity, 3. the absence of an established and mature business model for the industry and 4. the contrasting regulatory environments between carbon capture and storage and oil and gas extraction. Whilst the underground injection of carbon dioxide can truly be considered a proven technology, there are a range of engineering challenges to achieve this in a safe and cost effective manner. This paper sets out to explore some of these challenges and concludes with a view of what next steps are required to progress carbon dioxide storage effectively within the UK. • The challenges of injecting carbon dioxide into offshore subsurface reservoirs: ^ Arrival processing (heating before injection) ^ Injectivity assessment – how many wells? ^ Platform or subsea? ^ Well design for long service operations and monitoring • The challenges of forecasting reservoir and injection performance within porous and permeable storage reservoirs: ^ Issues influencing carbon dioxide storage capacity ^ Assuring storage site containment integrity ^ Geology and engineering – uncertainty and risk • Where has the industry got to and what are the practical next steps?
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Qi, Chao, and Yongrok Choi. "A Study of the Feasibility of International ETS Cooperation between Shanghai and Korea from Environmental Efficiency and CO2 Marginal Abatement Cost Perspectives." Sustainability 11, no. 16 (August 18, 2019): 4468. http://dx.doi.org/10.3390/su11164468.
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With the worldwide spread of emissions trading schemes (ETSs) and the need for international cooperation on climate change, there is growing interest in linking ETSs. Along with sustainable development, preventing and controlling pollution, is now regarded as an urgent priority by China and Korea. In the context of the willingness of the Chinese and Korean governments to cooperate on ETS, this paper examines the feasibility of a pilot ETS cooperation between Shanghai and Korea from environmental efficiency and CO2 marginal abatement cost (MAC) perspectives. We apply a directional distance function (DDF) and stochastic frontier analysis (SFA) to estimate the environmental efficiency and the CO2 MAC of coal-fueled power plants in Shanghai and Korea using cross-sectional data from 2015. The results indicate that the group frontier environmental efficiency of Shanghai and Korea reached a similarly high score. However, as to meta-frontier environmental efficiency, the coal-fueled power plants in Korea performed better than those in Shanghai. The CO2 MAC results indicate that, despite the small gap in efficiency performance, the CO2 MAC of coal-fueled power plants is much higher than that in Shanghai due to the big feed-in tariff difference. This is because the MAC not only relates to the environmental efficiency, but also to the feed-in tariff. A higher feed-in tariff leads to higher MAC. To tackle this serious problem, which has also been addressed in previous studies, we suggest that policymakers should focus on the huge CO2 MAC differences caused by feed-in tariff differences to avoid equity problems when building the structure of the Shanghai-Korea ETS cooperation. For instance, compared with power plants in Shanghai, policymakers should set a looser cap and a higher offset for Korean plants. To reduce the impact of feed-in tariff on carbon trading in the market, it would also be effective to arrange a higher quota or a lower carbon tax for coal-fueled power plants in Korea. In addition, policymakers should fill the gaps of 85.15% and 67.6% between the realistic market price and the MAC results of coal-fueled power plants in Shanghai and Korea, respectively, by introducing stricter regulations.
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Park, CS, JG Kwak, C. Lee, C.-H. Lee, SK Lee, and YL Kim. "Near-infrared spectroscopy as a possible device for continuous monitoring of arterial carbon dioxide tension during cardiac surgery." Perfusion 26, no. 6 (August 15, 2011): 524–28. http://dx.doi.org/10.1177/0267659111419034.
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Background: Insufflation of carbon dioxide (CO2) to the operative field has been used to prevent major organ injury attributed to air embolisms in cardiac surgery. However, it may be preferable to avoid hypercapnia induced by CO2 insufflation, owing to its potentially harmful effect. To investigate the effectiveness of near-infrared spectroscopy (NIRS) as a possible method for continuous monitoring of arterial CO2 tension during cardiac surgery, we evaluated the correlation between the change in arterial CO2 tension and the change in regional cerebral oxygen saturation (rScO2) obtained from NIRS in as controlled a condition as possible. Methods: Thirty patients who underwent surgical correction for atrial or ventricular septal defects were enrolled in this study. Patients who had pulmonary hypertension or other intracardiac anomalies were excluded. Anesthetic and cardiopulmonary bypass (CPB) management were conducted according to our standard institutional practice. Data obtained from arterial blood gas analyses and corresponding regional cerebral oxygen saturation (rScO2) recorded from NIRS before and after the insufflations of CO2 during CPB were used for analysis. Results: The change in arterial CO2 tension correlated with the change in rScO2 in the left hemisphere (r = 0.681, p <0.001, y = −1.393 + 0.547x) and right hemisphere (r = 0.690, p <0.001, y = −1.999 + 0.486x). To control the effects of other variables, including hematocrit and temperature, these relationship were not reduced (left hemisphere: r=0.678, p<0.001; right hemisphere: r=0.634, p<0.001). Conclusions: Since the change in regional cerebral oxygen saturation was correlated with the change in arterial CO2 tension during mild hypothermic CPB, NIRS might be a possible non-invasive method for monitoring of arterial CO2 tension without incurring additional cost in this setting.