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Journal articles on the topic 'Flue gas CO2 capture'

Author: Grafiati
Published: 4 June 2021
Last updated: 5 February 2022

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1

Chmielniak, Tadeusz, Paweł Mońka, and Paweł Pilarz. "Investigation of a combined gas-steam system with flue gas recirculation." Chemical and Process Engineering 37, no. 2 (June 1, 2016): 305–16. http://dx.doi.org/10.1515/cpe-2016-0025.

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Abstract This article presents changes in the operating parameters of a combined gas-steam cycle with a CO2 capture installation and flue gas recirculation. Parametric equations are solved in a purpose-built mathematical model of the system using the Ebsilon Professional code. Recirculated flue gases from the heat recovery boiler outlet, after being cooled and dried, are fed together with primary air into the mixer and then into the gas turbine compressor. This leads to an increase in carbon dioxide concentration in the flue gases fed into the CO2 capture installation from 7.12 to 15.7%. As a consequence, there is a reduction in the demand for heat in the form of steam extracted from the turbine for the amine solution regeneration in the CO2 capture reactor. In addition, the flue gas recirculation involves a rise in the flue gas temperature (by 18 K) at the heat recovery boiler inlet and makes it possible to produce more steam. These changes contribute to an increase in net electricity generation efficiency by 1%. The proposed model and the obtained results of numerical simulations are useful in the analysis of combined gas-steam cycles integrated with carbon dioxide separation from flue gases.
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2

Kim, Eugene J., Rebecca L. Siegelman, Henry Z. H. Jiang, Alexander C. Forse, Jung-Hoon Lee, Jeffrey D. Martell, Phillip J. Milner, et al. "Cooperative carbon capture and steam regeneration with tetraamine-appended metal–organic frameworks." Science 369, no. 6502 (July 23, 2020): 392–96. http://dx.doi.org/10.1126/science.abb3976.

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Natural gas has become the dominant source of electricity in the United States, and technologies capable of efficiently removing carbon dioxide (CO2) from the flue emissions of natural gas–fired power plants could reduce their carbon intensity. However, given the low partial pressure of CO2 in the flue stream, separation of CO2 is particularly challenging. Taking inspiration from the crystal structures of diamine-appended metal–organic frameworks exhibiting two-step cooperative CO2 adsorption, we report a family of robust tetraamine-functionalized frameworks that retain cooperativity, leading to the potential for exceptional efficiency in capturing CO2 under the extreme conditions relevant to natural gas flue emissions. The ordered, multimetal coordination of the tetraamines imparts the materials with extraordinary stability to adsorption-desorption cycling with simulated humid flue gas and enables regeneration using low-temperature steam in lieu of costly pressure or temperature swings.
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3

Li, Fang Qin, Ji Yong Liu, Xiao Feng Zhang, Jian Xing Ren, and Jiang Wu. "The Effects of Operation Parameters on CO2 Removal Efficiency by Membrane Method." Advanced Materials Research 955-959 (June 2014): 2326–29. http://dx.doi.org/10.4028/www.scientific.net/amr.955-959.2326.

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On the membrane contactor test unit, chose monoethanolamine (MEA) as absorption solution to absorb CO2 of simulated flue gases, studied effects of operating parameters on CO2 capture. Operating parameters included initial CO2 contents in flue gas, flue gas flow and absorption solution flow. Experimental results showed that: the greater the absorption of fluid flow, the higher the CO2 removal rate;While the greater the flue gas flow or the higher the initial CO2 concentration in flue gas, the lower the CO2 removal rate. In order to study the influence of the regeneration solution on CO2 absorption efficiency, regeneration experiments were done. Since the loss of solvent in regeneration solution, CO2 removal efficiency by regeneration solution was lower than that by original absorption solution.
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4

Peng, Pu, and Yi Zhuang. "The Evaluation and Comparison of Carbon Dioxide Capture Technologies Applied to FCC Flue Gas." Advanced Materials Research 347-353 (October 2011): 1479–82. http://dx.doi.org/10.4028/www.scientific.net/amr.347-353.1479.

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The CO2 capturing technologies as applied to FCC flue gas in order to reduce GHG (green house gases) were evaluated and compared in this review. Although the CCS (carbon capture and storage) idea has been proposed for more than 30 years, there has been little commercial success of CCS projects. The largest issue is where to store the massive amount of captured pure CO2 every year. Therefore, the review will focus on the efficient use of power or heat to reduce CO2 emission and how to recycle the use of produced CO2 before it is emitted to the atmosphere rather than being captured and stored. The scenarios with oxyfiring, microalgae-cofiring or biogas burning to treat FCC flue gas are introduced and discussed.
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5

Adu, Emmanuel, Y. D. Zhang, Dehua Liu, and Paitoon Tontiwachwuthikul. "Parametric Process Design and Economic Analysis of Post-Combustion CO2 Capture and Compression for Coal- and Natural Gas-Fired Power Plants." Energies 13, no. 10 (May 15, 2020): 2519. http://dx.doi.org/10.3390/en13102519.

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For the envisaged large number of commercial-scale carbon capture and storage (CCS) projects that are to be implemented in the near future, a number of issues still need to be resolved, the most prominent being the large capital and operational costs incurred for the CO2 capture and compression process. An economic assessment of the capture and compression system based on optimal design data is important for CCS deployment. In this paper, the parametric process design approach is used to optimally design coal and natural gas monoethanolamine (MEA)-based post-combustion CO2 absorption–desorption capture (PCC) and compression plants that can be integrated into large-scale 550 MW coal-fired and 555 MW natural gas combined cycle (NGCC) power plants, respectively, for capturing CO2 from their flue gases. The study then comparatively assesses the energy performance and economic viabilities of both plants to ascertain their operational feasibilities and relative costs. The parametric processes are presented and discussed. The results indicate that, at 90% CO2 capture efficiency, for the coal PCC plant, with 13.5 mol.% CO2 in the inlet flue gas, at an optimum liquid/gas ratio of 2.87 kg/kg and CO2 lean loading of 0.2082 mol CO2/mol MEA, the CO2 avoidance cost is about $72/tCO2, and, for the NGCC PCC plant, with 4.04 mol.% CO2 in the inlet flue gas, at an optimum liquid/gas ratio of 0.98 kg/kg and CO2 lean loading of 0.2307 mol CO2/mol MEA, the CO2 avoidance cost is about $94/tCO2.
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6

Wu, Guoqing, Ying Liu, Guangliang Liu, and Xiaoying Pang. "The CO2 Absorption in Flue Gas Using Mixed Ionic Liquids." Molecules 25, no. 5 (February 25, 2020): 1034. http://dx.doi.org/10.3390/molecules25051034.

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Because of the appealing properties, ionic liquids (ILs) are believed to be promising alternatives for the CO2 absorption in the flue gas. Several ILs, such as [NH2emim][BF4], [C4mim][OAc], and [NH2emim[OAc], have been used to capture CO2 of the simulated flue gas in this work. The structural changes of the ILs before and after absorption were also investigated by quantum chemical methods, FTIR, and NMR technologies. However, the experimental results and theoretical calculation showed that the flue gas component SO2 would significantly weaken the CO2 absorption performance of the ILs. SO2 was more likely to react with the active sites of the ILs than CO2. To improve the absorption capacity, the ionic liquid (IL) mixture [C4mim][OAc]/ [NH2emim][BF4] were employed for the CO2 absorption of the flue gas. It is found that the CO2 absorption capacity would be increased by about 25%, even in the presence of SO2. The calculation results suggested that CO2 could not compete with SO2 for reacting with the IL during the absorption process. Nevertheless, SO2 might be first captured by the [NH2emim][BF4] of the IL mixture, and then the [C4mim][OAc] ionic liquid could absorb more CO2 without the interference of SO2.
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7

Majchrzak-Kucęba, Izabela, Dariusz Wawrzyńczak, Janusz Zdeb, Wojciech Smółka, and Artur Zajchowski. "Treatment of Flue Gas in a CO2 Capture Pilot Plant for a Commercial CFB Boiler." Energies 14, no. 9 (April 26, 2021): 2458. http://dx.doi.org/10.3390/en14092458.

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The problem of reducing carbon dioxide emissions from flue gas, particularly from flue gas originating from coal-firing CFB systems, is currently an important challenge. Many centers around the world have tested post-combustion CO2 capture systems. One of these systems, operated using DR-VPSA adsorption technology (dual-reflux vacuum pressure swing adsorption), was tested under the Strategic Project in Poland. The flue gas in this study originated from a supercritical CFB boiler (460 MWe). An important problem involved in capturing CO2 from flue gas is the occurrence of SO2 and NOx. These substances have a negative effect on the CO2 adsorption process. In this study, commercial impregnated activated carbon was used to remove SO2 and NOx from CFB flue gas in the pre-treatment section during the tests of a pilot CO2 capture unit in a large-scale CFB boiler at the Lagisza Power Plant (Poland). The spent activated carbon was analyzed using several different methods (N2 adsorption–desorption isotherms, SEM-EDX, XRD, FTIR, and TG) to evaluate the efficiency of the operation and life span of the adsorbent used in the SO2 and NOx removal unit. The results demonstrate that using commercial impregnated activated carbon in the pre-treatment section ensures sufficient flue gas purification and the removal of sulfur oxides but remains insufficient for nitrogen oxides.
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8

Sakpal, Kumar, Aman, and Kumar. "Carbon Dioxide Capture from Flue Gas Using Tri-Sodium Phosphate as an Effective Sorbent." Energies 12, no. 15 (July 26, 2019): 2889. http://dx.doi.org/10.3390/en12152889.

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Fossil fuels are dominant as an energy source, typically producing carbon dioxide (CO2) and enhancing global climate change. The present work reports the application of low-cost tri-sodium phosphate (TSP) to capture CO2 from model flue gas (CO2 + N2) mixture, in a batch mode and fixed-bed setup. It is observed that TSP has a high CO2 capture capacity as well as high CO2 selectivity. At ambient temperature, TSP shows a maximum CO2 capture capacity of 198 mg CO2/g of TSP. Furthermore, the CO2 capture efficiency of TSP over a flue gas mixture was found to be more than 90%. Fresh and spent materials were characterized using powder X-ray diffraction (PXRD), scanning electron microscopy (SEM), and Fourier transformed infrared spectroscopy (FTIR). Preliminary experiments were also conducted to evaluate the performance of regenerated TSP. The spent TSP was regenerated using sodium hydroxide (NaOH) and its recyclability was tested for three consecutive cycles. A conceptual prototype for post-combustion CO2 capture based on TSP material has also been discussed.
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9

Li, Pengli, Yongli Shen, Dandan Wang, Yanli Chen, and Yunfeng Zhao. "Selective Adsorption-Based Separation of Flue Gas and Natural Gas in Zirconium Metal-Organic Frameworks Nanocrystals." Molecules 24, no. 9 (May 11, 2019): 1822. http://dx.doi.org/10.3390/molecules24091822.

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Carbon capture from flue gas and natural gas offers a green path to construct a net-zero emissions economic system. Selective adsorption-based gas separation by employing metal-organic frameworks (MOFs) is regarded as a promising technology due to the advantages of simple processing, easy regeneration and high efficiency. We synthesized two Zirconium MOFs (UiO-66 and UiO-66-NH2) nanocrystals for selective capture and further removal of CO2 from flue gas and natural gas. In particular, UiO-66-NH2 nanocrystals have a smaller grain size, a large amount of defects, and pending –NH2 groups inside their pores which display effective CO2 selective adsorption abilities over CH4 and N2 with the theoretical separation factors of 20 and 7. This breakthrough experiment further verified the selective adsorption-based separation process of natural gas and flue gas. In one further step, we used the Monte Carlo simulation to investigate the optimized adsorption sites and energy of CO2, N2 and CH4 molecules in the gas mixture. The significantly large adsorption energy of CO2 (0.32 eV) over N2 (0.19 eV) and N2 (0.2 eV) may help us to reveal the selective adsorption mechanism.
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10

Cheng, Chu-Yun, Chia-Chen Kuo, Ming-Wei Yang, Zong-Yu Zhuang, Po-Wei Lin, Yi-Fang Chen, Hong-Sung Yang, and Cheng-Tung Chou. "CO2 Capture from Flue Gas of a Coal-Fired Power Plant Using Three-Bed PSA Process." Energies 14, no. 12 (June 16, 2021): 3582. http://dx.doi.org/10.3390/en14123582.

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The pressure swing adsorption (PSA) process was used to capture carbon dioxide (CO2) from the flue gas of a coal-fired power plant to reduce CO2 emissions. Herein, CO2 was captured from flue gas using the PSA process for at least 85 vol% CO2 purity and with the other exit stream from the process of more than 90 vol% N2 purity. The extended Langmuir–Freundlich isotherm was used for calculating the equilibrium adsorption capacity, and the linear driving force model was used to describe the gas adsorption kinetics. We compared the results of breakthrough curves obtained through experiments and simulations to verify the accuracy of the mass transfer coefficient. The flue gas obtained after desulphurization and water removal (13.5 vol% CO2 and 86.5 vol% N2) from a subcritical 1-kW coal-fired power plant served as the feed for the designed three-bed, nine-step PSA process. To determine optimal operating conditions for the process, the central composite design (CCD) was used. After CCD analysis, optimal operating conditions with a feed pressure of 3.66 atm and a vacuum pressure of 0.05 atm were obtained to produce a bottom product with a CO2 purity of 89.20 vol% and a recovery of 88.20%, and a top product with a N2 purity of 98.49 vol% and a recovery of 93.56%. The mechanical energy consumption was estimated to be 1.17 GJ/t-CO2.
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11

Drioli, Enrico, Adele Brunetti, and Giuseppe Barbieri. "Ceramic Membranes in Carbon Dioxide Capture: Applications and Potentialities." Advances in Science and Technology 72 (October 2010): 105–18. http://dx.doi.org/10.4028/www.scientific.net/ast.72.105.

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Today, CO2 capture from e.g. flue gas has becoming an emerging opportunity for membrane gas separation. The flue gas coming out from power plants contains about 10-15% CO2, which should be separated before its sequestration. The most used membranes for this application are polymeric but they cannot be used at a high temperature. The flue gas exits at ca. 200°C, depending on the specific locations in the plant and, thus, it is highly desirable to separate it at high temperature. An alternative class to polymeric membranes is represented by the ceramic one which comprises zeolites, carbons, silica, perovskites membranes, that exhibit high fluxes and thermal resistance. However, a great challenge is to fabricate them as thin layers, avoiding formation of cracks that compromise the separation. Today, new solutions are in progress for the production of ceramic membrane able to overcome these limitations. For example, hybrid membranes able to combine the properties of different materials are proposed. Moreover, new works are done on mixed-matrix membranes, comprising of a molecular sieve guest phase dispersed in a polymer host matrix [3] which combines the advantage offered by the two materials. This work proposes an overview on the main applications of ceramic membranes in CO2 capture processes.
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12

Qin, Hong Yan, Peng Zhi Zhang, Si Si Zhang, and Xiang Peng Wang. "Experimental Study on Regularities of Carbonation for CO2 Capture Using Ammonia Solution." Advanced Materials Research 800 (September 2013): 62–66. http://dx.doi.org/10.4028/www.scientific.net/amr.800.62.

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The regularities of carbonation in the process of CO2 capture were investigated using ammonia solution by laboratory-scale and bench-scale device. The research showed that the lower volatility of NH3 and higher rate of carbonization in solution could be achieved with ammonia concentration ranging from 10 to 16 wt%. The emission of ammonia accelerated with the increasing of flow of flue gas, and the bubbling function of air was apparent in a lower CO2 volume fraction, which has an adverse effect on carbonation of solution. Benefits of environment and economic could be achieved in CO2 capture using ammonia solution so long as appropriate ammonia concentration, the flue gas flow and volume fraction of CO2 were determined.
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13

Alexanda Petrovic, Ben, and Salman Masoudi Soltani. "Optimization of Post Combustion CO2 Capture from a Combined-Cycle Gas Turbine Power Plant via Taguchi Design of Experiment." Processes 7, no. 6 (June 12, 2019): 364. http://dx.doi.org/10.3390/pr7060364.

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The potential of carbon capture and storage to provide a low carbon fossil-fueled power generation sector that complements the continuously growing renewable sector is becoming ever more apparent. An optimization of a post combustion capture unit employing the solvent monoethanolamine (MEA) was carried out using a Taguchi design of experiment to mitigate the parasitic energy demands of the system. An equilibrium-based approach was employed in Aspen Plus to simulate 90% capture of the CO2 emitted from a 600 MW natural gas combined-cycle gas turbine power plant. The effects of varying the inlet flue gas temperature, absorber column operating pressure, amount of exhaust gas recycle, and amine concentration were evaluated using signal to noise ratios and analysis of variance. The optimum levels that minimized the specific energy requirements were a: flue gas temperature = 50 °C; absorber pressure = 1 bar; exhaust gas recirculation = 20% and; amine concentration = 35 wt%, with a relative importance of: amine concentration > absorber column pressure > exhaust gas recirculation > flue gas temperature. This configuration gave a total capture unit energy requirement of 5.05 GJ/tonneCO2, with an energy requirement in the reboiler of 3.94 GJ/tonneCO2. All the studied factors except the flue gas temperature, demonstrated a statistically significant association to the response.
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14

Hasan, Saman, Abubakar Jibrin Abbas, and Ghasem Ghavami Nasr. "Improving the Carbon Capture Efficiency for Gas Power Plants through Amine-Based Absorbents." Sustainability 13, no. 1 (December 23, 2020): 72. http://dx.doi.org/10.3390/su13010072.

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Environmental concern for our planet has changed significantly over time due to climate change, caused by an increasing population and the subsequent demand for electricity, and thus increased power generation. Considering that natural gas is regarded as a promising fuel for such a purpose, the need to integrate carbon capture technologies in such plants is becoming a necessity, if gas power plants are to be aligned with the reduction of CO2 in the atmosphere, through understanding the capturing efficacy of different absorbents under different operating conditions. Therefore, this study provided for the first time the comparison of available absorbents in relation to amine solvents (MEA, DEA, and DEA) CO2 removal efficiency, cost, and recirculation rate to achieve Climate change action through caron capture without causing absorbent disintegration. The study analyzed Flue under different amine-based solvent solutions (monoethanolamine (MEA), diethanolamine (DEA), and methyldiethanolamine (MDEA)), in order to compare their potential for CO2 reduction under different operating conditions and costs. This was simulated using ProMax 5.0 software modeled as a simple absorber tower to absorb CO2 from flue gas. Furthermore, MEA, DEA, and MDEA adsorbents were used with a temperature of 38 °C and their concentration varied from 10 to 15%. Circulation rates of 200–300 m3/h were used for each concentration and solvent. The findings deduced that MEA is a promising solvent compared to DEA and MDEA in terms of the highest CO2 captured; however, it is limited at the top outlet for clean flue gas, which contained 3.6295% of CO2 and less than half a percent of DEA and MDEA, but this can be addressed either by increasing the concentration to 15% or increasing the MEA circulation rate to 300 m3/h.
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15

Gazda-Grzywacz, Magdalena, Łukasz Winconek, and Piotr Burmistrz. "Carbon Footprint for Mercury Capture from Coal-Fired Boiler Flue Gas." Energies 14, no. 13 (June 25, 2021): 3844. http://dx.doi.org/10.3390/en14133844.

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Power production from coal combustion is one of two major anthropogenic sources of mercury emission to the atmosphere. The aim of this study is the analysis of the carbon footprint of mercury removal technologies through sorbents injection related to the removal of 1 kg of mercury from flue gases. Two sorbents, i.e., powdered activated carbon and the coke dust, were analysed. The assessment included both direct and indirect emissions related to various energy and material needs life cycle including coal mining and transport, sorbents production, transport of sorbents to the power plants, and injection into flue gases. The results show that at the average mercury concentration in processed flue gasses accounting to 28.0 µg Hg/Nm3, removal of 1 kg of mercury from flue gases required 14.925 Mg of powdered activated carbon and 33.594 Mg of coke dust, respectively. However, the whole life cycle carbon footprint for powdered activated carbon amounted to 89.548 Mg CO2-e·kg−1 Hg, whereas for coke dust this value was around three times lower and amounted to 24.452 Mg CO2-e·kg−1 Hg. Considering the relatively low price of coke dust and its lower impact on GHG emissions, it can be found as a promising alternative to commercial powdered activated carbon.
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16

Hou, Shuhn-Shyurng, Chiao-Yu Chiang, and Ta-Hui Lin. "Oxy-Fuel Combustion Characteristics of Pulverized Coal under O2/Recirculated Flue Gas Atmospheres." Applied Sciences 10, no. 4 (February 17, 2020): 1362. http://dx.doi.org/10.3390/app10041362.

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Oxy-fuel combustion is an effective technology for carbon capture and storage (CCS). Oxy-combustion for coal-fired power stations is a promising technology by which to diminish CO2 emissions. Unfortunately, little attention has been paid to the oxy-combustion characteristics affected by the combustion atmosphere. This paper is aimed at investigating the oxy-fuel combustion characteristics of Australian coal in a 0.3 MWth furnace. In particular, the influences of various oxygen flow rates and recirculated flue gas (RFG) on heating performance and pollutant emissions are examined in O2/RFG environments. The results show that with increases in the secondary RFG flow rate, the temperatures in the radiative and convective sections decrease and increase, respectively. At a lower oxygen flow rate, burning Australian coal emits lower residual oxygen and NO concentrations. In the flue gas, a high CO2 concentration of up to 94.8% can be achieved. Compared to air combustion, NO emissions are dramatically reduced up to 74% for Australian coal under oxy-combustion. Note that the high CO2 concentrations in the flue gas under oxy-coal combustions suggest great potential for reducing CO2 emissions through carbon capture and storage.
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17

Wilk, Andrzej, Lucyna Więcław-Solny, Dariusz Śpiewak, Tomasz Spietz, and Hanna Kierzkowska-Pawlak. "A Selection of Amine Sorbents for CO2 Capture from Flue Gases." Chemical and Process Engineering 36, no. 1 (March 1, 2015): 49–57. http://dx.doi.org/10.1515/cpe-2015-0004.

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Abstract Amine absorption processes are widely used in the industry to purify refinery gases, process gases or natural gas. Recently, amine absorption has also been considered for CO2 removal from flue gases. It has a number of advantages, but there is one major disadvantage - high energy consumption. This can be reduced by using an appropriate sorbent. From a group of several dozen solutions, three amine sorbents were selected based on primary, tertiary and sterically hindered amines. The solutions were used to test CO2 absorption capacity, absorption kinetics and heat of CO2 absorption. Additional tests were performed on the actual absorber-desorber system to indicate the most appropriate sorbent for capturing CO2 from flue gases.
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18

Lv, Yue Xia, Chong Qing Xu, Gui Huan Yan, Dong Yan Guo, and Qi Xiao. "A Review on CO2 Capture Using Membrane Gas Absorption Technology." Advanced Materials Research 616-618 (December 2012): 1541–45. http://dx.doi.org/10.4028/www.scientific.net/amr.616-618.1541.

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Membrane gas absorption technology is a promising technology for CO2 removal from flue gases produced by fossil fuels combustion, which has the potential of enhancing the separation efficiency and reducing the costs associated with CO2 capture. In the present paper, important aspects of CO2 removal by membrane gas absorption technology, including liquid absorbents, membrane materials, membrane-absorbent compatibility, membrane wetting and corresponding solutions have been reviewed. Furthermore, future potential in research and development of gas-liquid membrane contactors for CO2 removal has also been briefly discussed.
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19

Nikolaeva, D., I. Azcune, E. Sheridan, Marius Sandru, A. Genua, M. Tanczyk, M. Jaschik, K. Warmuzinski, J. C. Jansen, and I. F. J. Vankelecom. "Poly(vinylbenzyl chloride)-based poly(ionic liquids) as membranes for CO2 capture from flue gas." Journal of Materials Chemistry A 5, no. 37 (2017): 19808–18. http://dx.doi.org/10.1039/c7ta05171a.

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20

McGaughy, Kyle, and M. Toufiq Reza. "Systems Analysis of SO2-CO2 Co-Capture from a Post-Combustion Coal-Fired Power Plant in Deep Eutectic Solvents." Energies 13, no. 2 (January 16, 2020): 438. http://dx.doi.org/10.3390/en13020438.

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In this study, CO2 and SO2 captures from post-combustion flue gas from a pulverized coal-fired power plant were evaluated using deep eutectic solvents (DES) to replace existing mono-ethanol amine (MEA) and CanSolv technologies. The system design of the DES-based CO2 and SO2 capture was based on the National Energy Technology Laboratory’s (NETL) 550 MWe pulverized coal-fired power plant model using Illinois #06 coal. Two of the most studied DES (choline chloride and urea at a 1:2 molar ratio and methyltriphenylphosphonium bromide (METPB) and ethylene glycol at a 1:3 molar ratio) for CO2 and SO2 capture were evaluated for this system analysis. Physical properties of DES were evaluated using both density functional theory (DFT)-based modeling as well as with documented properties from the literature. A technoeconomic assessment (TEA) was completed to assess DES ability to capture CO2 and SO2. Both solvents were able to fully dissolve and capture all SO2 present in the flue gas. It was also found from the system analyses that choline chloride and urea outperformed METPB and ethylene glycol (had a lower final cost) when assessed at 10–30% CO2 capture at high operating pressures (greater than 10 bar). At high system sizes (flow rate of greater than 50,000 kmoles DES per hour), choline chloride:urea was more cost effective than METPB:ethylene glycol. This study also establishes a modeling framework to evaluate future DES for physical absorption systems by both thermophysical and economic objectives. This framework can be used to greatly expedite DES candidate screening in future studies.
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21

Ahmad, Mohd Aizad, Muhammad Fahmi Nizam, and Zulkifli Abdul Rashid. "Evaluation of Renewable Methanol Production Plant Design Using Tri-Pressure Stripper Configuration." Key Engineering Materials 797 (March 2019): 342–50. http://dx.doi.org/10.4028/www.scientific.net/kem.797.342.

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Over the past years in the industry, the emissions of carbon dioxide (CO2) waste into the atmosphere have been rapidly increasing. The carbon capture technology is used in a few power plants to capture CO2molecules from the flue gas. Researchers have established method to use CO2and convert into valuable products. Therefore, this study is aim to simulate the reaction between captured CO2with hydrogen to produce renewable methanol. In order to achieve objective of designing the renewable methanol plant, the Aspen Hysys is used as modelling and simulation tool to obtain about 50k tonnes per year of renewable methanol production. Then, the amount of CO2is evaluated based on the amount of CO2in flue gas, CO2capture and renewable methanol produced. The results of the simulation that obtained is about 16510 kg/h of captured CO2and 6049 kg/h of methanol produced from the 17936 kg/h of CO2contained in flue gas. Three different coal-fired power plant capacities have been studied to evaluate their methanol production capacity. A small 110 MW power plant could produce 12705 kg/h of methanol, while 1400 MW and 2420 MW power plant will achieve 161,703 kg/h and 279515 kg/h respectively.
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22

Rahimi, Mohammad, Giulia Catalini, Monica Puccini, and T. Alan Hatton. "Bench-scale demonstration of CO2 capture with an electrochemically driven proton concentration process." RSC Advances 10, no. 29 (2020): 16832–43. http://dx.doi.org/10.1039/d0ra02450c.

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23

Wu, Xiao Na, Liang Wang, Zhao Hui Zhang, Wen Yang Li, and Xing Fei Guo. "Experimental Studies on CO2 Absorption in Immersed Hollow Fiber Membrane Contactor." Applied Mechanics and Materials 209-211 (October 2012): 1571–75. http://dx.doi.org/10.4028/www.scientific.net/amm.209-211.1571.

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Carbon dioxide (CO2) absorption performance from flue gas was investigated using monoethanolamine (MEA) solution in porous hydrophobic polyvinylidene fluoride (PVDF) hollow fiber membranes contactor. The influence of operating parameters on CO2 removal efficiency and flux were studied in the immersion operating mode. The experimental results indicated that the CO2 removal efficiency and flux decreased with the increase of flue gas load and carbonization degrees, but the increase of the absorbent concentration and temperature promoted membrane performance of CO2 capture. An increase of 84 m3•m-2•h-1 in the flue gas load resulted in a 68% decrease in the removal efficiency. Absorbent carbonation degree increased to 0.45 mol CO2•mol-1MEA led to the decrease of active ingredient amounts in the absorption solution, and the corresponding removal efficiency and membrane flux dropped by 50% of the initial amounts, respectively. The increase of concentration and temperature of absorbent also benefited membrane absorption performance of CO2 absorption, so that the concentration and temperature of the solvent increased lead to the CO2 removal efficiency and flux increased.
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Elsaidi, Sameh K., Mona H. Mohamed, Herbert T. Schaef, Amrit Kumar, Matteo Lusi, Tony Pham, Katherine A. Forrest, et al. "Hydrophobic pillared square grids for selective removal of CO2 from simulated flue gas." Chemical Communications 51, no. 85 (2015): 15530–33. http://dx.doi.org/10.1039/c5cc06577a.

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Han, Yang, Yutong Yang, and W. S. Winston Ho. "Recent Progress in the Engineering of Polymeric Membranes for CO2 Capture from Flue Gas." Membranes 10, no. 11 (November 23, 2020): 365. http://dx.doi.org/10.3390/membranes10110365.

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CO2 capture from coal- or natural gas-derived flue gas has been widely considered as the next opportunity for the large-scale deployment of gas separation membranes. Despite the tremendous progress made in the synthesis of polymeric membranes with high CO2/N2 separation performance, only a few membrane technologies were advanced to the bench-scale study or above from a highly idealized laboratory setting. Therefore, the recent progress in polymeric membranes is reviewed in the perspectives of capture system energetics, process synthesis, membrane scale-up, modular fabrication, and field tests. These engineering considerations can provide a holistic approach to better guide membrane research and accelerate the commercialization of gas separation membranes for post-combustion carbon capture.
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D'Alessandro, Deanna M., and Thomas McDonald. "Toward carbon dioxide capture using nanoporous materials." Pure and Applied Chemistry 83, no. 1 (November 19, 2010): 57–66. http://dx.doi.org/10.1351/pac-con-10-09-18.

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The development of more efficient processes for CO2 capture from the flue streams of power plants is considered a key to the reduction of greenhouse gas emissions implicated in global warming. Indeed, several U.S. and international climate change initiatives have identified the urgent need for improved materials and methods for CO2 capture. Conventional CO2 capture processes employed in power plants world-wide are typically postcombustion “wet scrubbing” methods involving the absorption of CO2 by amine-containing solvents such as methanolamine (MEA). These present several disadvantages, including the considerable heat required in regeneration of the solvent and the necessary use of inhibitors for corrosion control, which lead to reduced efficiencies and increased costs for electricity production. This perspective article seeks to highlight the most recent advances in new materials for CO2 capture from power plant flue streams, with particular emphasis on the rapidly expanding field of metal–organic frameworks. Ultimately, the development of new classes of efficient, cost-effective, and industrially viable capture materials for application in carbon capture and storage (CCS) systems offers an immense opportunity to reduce atmospheric emissions of greenhouse gases on a national and international scale.
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Duan, Yong Hua, Hui Li, De Long Xu, Le Le Zhang, and Xiao Fan. "Oxygen-Enriched Combustion Technology Application and Economical Forecast in Cement Industry Kiln." Advanced Materials Research 645 (January 2013): 505–10. http://dx.doi.org/10.4028/www.scientific.net/amr.645.505.

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Using combustion theory to research on the technical theoretical features of oxygen-enriched combustion technology application to the cement industry kiln. On the basis of this, engineering projects of that, a certain enterprise 3000 t/d cement clinker production line applied oxygen-enriched combustion technology, and its economic evaluation were calculated. The results showed that: applying Oxygen-enriched combustion technology to the existing cement clinker calcined equipments, the coal powder consumption, the volume of flue gas and CO2 concentration in the flue gas of unit cement clinker occurred regular changes, When the O2 concentration increased from 21% to 30%, the coal powder consumption decreased by 17.78%, the flue gas volume was reduced by 12.73% and the CO2 concentration in the flue gas increased to 76.57%. If the enterprise used the oxygen-enriched atmosphere of O2 concentration for 30% to form the coal combustion, it can save coal about 71.87 t/d, equipment production capacity increase by 41.75% and capture CO2 products about 2662 t. Every year, this resulted in the profit increasing 103 million yuan.
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Marco-Lozar, Juan Pablo, Mirko Kunowsky, Fabián Suárez-García, and Angel Linares-Solano. "Sorbent design for CO2 capture under different flue gas conditions." Carbon 72 (June 2014): 125–34. http://dx.doi.org/10.1016/j.carbon.2014.01.064.

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Shi, Zhaolin, Yu Tao, Jiasheng Wu, Cuizheng Zhang, Hailong He, Liuliu Long, Yongjin Lee, Tao Li, and Yue-Biao Zhang. "Robust Metal–Triazolate Frameworks for CO2 Capture from Flue Gas." Journal of the American Chemical Society 142, no. 6 (January 23, 2020): 2750–54. http://dx.doi.org/10.1021/jacs.9b12879.

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Wang, Xia, Dongying Wang, Mingjun Song, Chunling Xin, and Wulan Zeng. "Tetraethylenepentamine-Modified Activated Semicoke for CO2 Capture from Flue Gas." Energy & Fuels 31, no. 3 (February 14, 2017): 3055–61. http://dx.doi.org/10.1021/acs.energyfuels.6b03177.

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31

Su, Fengsheng, Chungsying Lu, Wenfa Cnen, Hsunling Bai, and Jyh Feng Hwang. "Capture of CO2 from flue gas via multiwalled carbon nanotubes." Science of The Total Environment 407, no. 8 (April 2009): 3017–23. http://dx.doi.org/10.1016/j.scitotenv.2009.01.007.

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32

Luo, Liangfei, Fangqin Li, Haigang Ji, and Haiwen Wang. "Technology Research for CO2 Capture from Coal-fired Flue Gas." International Journal of Energy and Power 5 (2016): 48. http://dx.doi.org/10.14355/ijep.2016.05.007.

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Wei, Chiao-Chien, Graeme Puxty, and Paul Feron. "Amino acid salts for CO2 capture at flue gas temperatures." Chemical Engineering Science 107 (April 2014): 218–26. http://dx.doi.org/10.1016/j.ces.2013.11.034.

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34

Wei, Steven Chiao-Chien, Graeme Puxty, and Paul Feron. "Amino acid salts for CO2 capture at flue gas temperatures." Energy Procedia 37 (2013): 485–93. http://dx.doi.org/10.1016/j.egypro.2013.05.134.

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35

Scholes, Colin A., Minh T. Ho, Alita A. Aguiar, Dianne E. Wiley, Geoff W. Stevens, and Sandra E. Kentish. "Membrane gas separation processes for CO2 capture from cement kiln flue gas." International Journal of Greenhouse Gas Control 24 (May 2014): 78–86. http://dx.doi.org/10.1016/j.ijggc.2014.02.020.

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36

Fernández, Josefa, and M. J. Renedo. "Sulfation and Carbonation Competition in the Treatment of Flue Gas from a Coal-Based Power Plant by Calcium Hydroxide." International Journal of Chemical Reactor Engineering 13, no. 2 (June 1, 2015): 177–82. http://dx.doi.org/10.1515/ijcre-2014-0182.

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Abstract In this work, a gas containing CO2 and SO2 at the usual concentrations on the coal combustion flue gas reacted with calcium hydroxide to evaluate and quantify the influence of SO2 on the CO2 capture and vice versa. This influence was quantified with a continuous gas analyzer and by thermogravimetry (TG). Results show that the CO2 retained increases in general as its concentration does and decreases as the SO2 concentration increases. A similar behavior was found for the SO2 retention at different CO2 concentrations being more relevant the influence of the presence of SO2 on the CO2 capture than the opposite one. Results suggest that for a high CO2 capture, SO2 should be eliminated previously. With respect to the reaction process it was found that the desulfurization product clearly identified was CaSO3·½H2O; in the reaction between Ca(OH)2 and CO2, CaCO3 is mainly obtained, the complex CaO·CO2 being another possible product synthesized in low amount. Gas analyzer shows that SO2 and CO2 react simultaneously and that a part of the CaCO3 reacts with the SO2 and releases CO2. Sulfation values calculated by TG and from the gas analyzer are very similar but the amount of CO2 captured is not possible to know clearly by TG due to the synthesis and decomposition of CaCO3 during the process. The study of the evolution of the sorbent porosity in the process reveals that the presence of both acid gases produces a lower blockage of the pores than when only one gas is present probably due to the generation of new pores in the reaction of CaCO3 and SO2.
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Chen, Shujun, Min Zhu, Yingchun Tang, Yue Fu, Wenliang Li, and Bo Xiao. "Molecular simulation and experimental investigation of CO2 capture in a polymetallic cation-exchanged 13X zeolite." Journal of Materials Chemistry A 6, no. 40 (2018): 19570–83. http://dx.doi.org/10.1039/c8ta05647a.

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38

Javed, M. Tayyeb, and Bill Nimmo. "Oxygen Enriched and Oxyfuel Combustion - Promising Trends for Low Carbon Future." Applied Mechanics and Materials 145 (December 2011): 11–15. http://dx.doi.org/10.4028/www.scientific.net/amm.145.11.

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The escalation of ambient CO2 concentration due excessive use of coal in power generation has put impetus on the development of technologies for utilization of vast and cheap resources available through out the world. Eco-scrub, Oxygen enriched and oxyfuel combustion are among the promising technologies guaranteeing the low carbon future. In our recent investigations, pulverized coal (Russian) was fired in a 20 kW down fired combustion rig under simulated exhaust gas recirculation. The effect of CO2 at burner inlet on the combustion efficiency, flue gas CO2 and NO emission was studied. The test conditions were essentially achieved by replacing the secondary air with a mixture of O2 and CO2 in different proportion. The test conditions do imitate the four key conditions for eco-scrub project. The basic theme under eco-scrub project is to use limited oxygen addition to reduce the volume of flue gas for processing, increase the efficiency of post combustion scrubbing due to higher CO2 levels and reduced the size and cost of post combustion capture. The exhaust gas CO2 was observed to increase linearly with increasing the CO2 at burner inlet. The flue gas concentration for 35% and 45% flue gas recycle was recorded to be 24% and 30% respectively. The NO emission was most of the time under the base line emission of 818 ppm. A maximum of 66% reduction was observed when the burner inlet CO2 was 45% and 21% O2. How ever an increase of 37% was seen when 80% of the secondary air was replaced with a 50%O2-50%CO2 mixture.
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39

Han, Yang, and W. S. Winston Ho. "Recent developments on polymeric membranes for CO2 capture from flue gas." Journal of Polymer Engineering 40, no. 6 (July 28, 2020): 529–42. http://dx.doi.org/10.1515/polyeng-2019-0298.

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AbstractPolymeric membranes have been widely considered as one of the next-generation technologies for CO2 capture from fossil fuel-derived flue gases. This separation modality requires novel polymeric materials that possess efficient CO2/N2 separation properties, as well as chemical and mechanical stability for a multiyear membrane lifetime. In this paper, recent developments in polymeric membranes tailored for post-combustion carbon capture are reviewed. The selected polymeric materials encompass ether oxygen-rich polymers, polynorbornenes, ionic liquid membranes, and facilitated transport membranes. In each of the selected materials, noteworthy research efforts for material design and membrane formation are highlighted. The performances of the selected materials are compared in the CO2/N2 selectivity-CO2 permeance plot. As the only class of materials reviewed herein that have demonstrated the fabrication of thin-film composite membranes in scale, facilitated transport membranes have shown both high selectivity and permeance at relevant conditions for post-combustion carbon capture. However, comprehensive field tests are needed to resolve the technical gap between the material development and the commercial application.
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40

Asendrych, Dariusz, Paweł Niegodajew, and Stanisław Drobniak. "CFD Modelling of CO2 Capture in a Packed Bed by Chemical Absorption." Chemical and Process Engineering 34, no. 2 (June 1, 2013): 269–82. http://dx.doi.org/10.2478/cpe-2013-0022.

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The paper deals with numerical modelling of carbon dioxide capture by amine solvent from flue gases in post-combustion technology. A complex flow system including a countercurrent two-phase flow in a porous region, chemical reaction and heat transfer is considered to resolve CO2 absorption. In order to approach the hydrodynamics of the process a two-fluid Eulerian model was applied. At the present stage of model development only the first part of the cycle, i.e. CO2 absorption was included. A series of parametric simulations has shown that carbon dioxide capture efficiency is mostly influenced by the ratio of liquid (aqueous amine solution) to gas (flue gases) mass fluxes. Good consistency of numerical results with experimental data acquired at a small-scale laboratory CO2 capture installation (at the Institute for Chemical Processing of Coal, Zabrze, Poland) has proved the reliability of the model.
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41

Sarauta, Abdulkadir, and Ibrahim Ali Mohammed Dabo. "Novel Pilot-Scale Technology for Refinery Flare Flue Gas Carbon Capture and Storage Using Cost-Effective Adsorbents." Symmetry 13, no. 5 (May 5, 2021): 807. http://dx.doi.org/10.3390/sym13050807.

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This paper introduced the use of two new adsorbents, Akrosorb soda-lime and Bentonite clay, for refinery flare flue gas capture and storage. This study also developed a novel pilot plant model with 409.7149 kg/h capacity refinery flare emission capture with a novel adsorption column configuration using Akrosorb soda-lime and Bentonite clay adsorbents. The flare flue gas adsorption unit was designed, fabricated, test run, and commissioned. The adsorption column temperature is 28 ± 10 °C and has a pressure of 131.7 kPa. The novel plant RSM optimization result shows that 93.24% of CO2 and 62.18% of CO were absorbed, while 86.14% of NOx and 55.87% of HC were absorbed. The established optimum conditions of CO2, NOx, HC, and CO removal efficiency are 22 °C, 2 atm, and 60 min. The variation in flare gas emission could impact the removal efficiency of the plant. The results show the maximum adsorption ability or capacity of 314.30 mg/g, and 68.90 mg/g was reached at 60 min for Akrosorb soda-lime and molded Bentonite adsorbents. Therefore, the developed novel technology for CO2 and other GHG capture is technically feasible and friendly. The combined usage of both adsorbents will enhance the capture of GHG at a low cost compared to using Akrosorb alone as an adsorbent.
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42

Witasek, Roman, and Petr Pánek. "New Trends in the Separation of Significant Greenhouse Gases from Flue Gas Streams." Advanced Materials Research 1020 (October 2014): 573–78. http://dx.doi.org/10.4028/www.scientific.net/amr.1020.573.

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The paper is closely related to the challenge of the most important greenhouse gas - carbon dioxide. Both, the effective capture and secure storage of CO2, is an urgent environmental problem. Approximately ¾ of all anthropogenic emissions of CO2are related to the use of fossil fuels. Great attention is given to the absorption processes for the capture of the gas. Carbon Capture and Storage (CCS) is a promising solution for achieving a significant reduction in CO2- emissions. Capture of combustion gases using standard volatile organic solvents are the source of numerous problems like environmental pollution, instability and corrosivity of such solvents. An effective solution seems to be the use of ionic liquids. Ionic liquids are a relatively new class of compounds, which are chemically and thermally stable and are able to dissolve a wide range of substances. The negligible volatility of ionic liquids is their most important property. Research and development of the CO2- capture technology has not yet reached the stage of commercial exploitation under economically acceptable conditions. The aim of this article is to show the possibilities of use of ionic liquids in the absorption separation processes for CO2-capture.
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43

McGlashan, N. R., and A. J. Marquis. "Availability analysis of post-combustion carbon capture systems: Minimum work input." Proceedings of the Institution of Mechanical Engineers, Part C: Journal of Mechanical Engineering Science 221, no. 9 (September 1, 2007): 1057–65. http://dx.doi.org/10.1243/09544062jmes424.

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This paper describes the availability analysis of a generic, post-combustion carbon capture plant. The analysis first establishes the minimum work input required in an ideal plant with a flue gas inlet temperature equal to the sink temperature. The analysis shows that the ideal work input is surprisingly low and that, roughly equal amounts of work are required to first separate and then compress the CO2 contained in a typical flue gas stream. The analysis is then extended to include the effects of variable inlet temperature and extraction efficiency. This extended analysis shows that there is a considerable quantity of available energy in the flue gas of a normal power station. Indeed, in principle, carbon capture is theoretically possible without any external work input for fuels of low carbon/hydrogen ratio such as heavy fuel oil and natural gas. When burning coal, the minimum work input would be significantly reduced if the flue gases' availability were utilized. The final section of the paper compares the actual work input of a variety of carbon capture schemes found in the literature, with the minimum work input for an ideal process. This comparison shows that the techniques presently found in the literature have a low second-law efficiency.
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44

Andreasen, Anders. "Optimisation of carbon capture from flue gas from a Waste-to-Energy plant using surrogate modelling and global optimisation." Oil & Gas Science and Technology – Revue d’IFP Energies nouvelles 76 (2021): 55. http://dx.doi.org/10.2516/ogst/2021036.

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The optimisation of Post Carbon Capture (PCC) from a Waste-to-Energy plant has been studied using Kriging surrogate models trained from a set of rigorous process simulations. The surrogate models allow fast and efficient calculation of model responses required for the optimisation of operating parameters. Optimisation is performed using Differential Evolution (DE) requiring a vast amount of function calculations (>1000) which would be extremely time consuming if done with a rigorous process simulation model. It is found that for meeting a CO2 removal efficiency of 85% for a flue gas containing 12.6 mole % CO2 and a reboiler temperature limited to max. 120 °C, a L/G ratio of approx. 2.2 (kg/kg) is optimal. This is accompanied by a stripper/regenerator pressure of 1.85 bara, a temperature of the flue gas at the lower bound, a temperature approach of the lean amine entering the absorber of 6.5 °C (to the flue gas temperature), and a temperature approach in the L/R heat exchanger of 5 °C. The optimal lean and rich amine loading is approx. 0.21 and 0.52 (mole CO2/mole MEA).
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45

Dinca, Cristian, Adrian Badea, and Horia Necula. "High Performance of the CFBC Pilot Plant with CO2 Chemical Absorption by Optimizing the Absorber Parameters." Advanced Materials Research 746 (August 2013): 3–8. http://dx.doi.org/10.4028/www.scientific.net/amr.746.3.

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The objective of this paper consists to identify the influence of absorption process temperature and pressure on the energy requirement of the CO2 chemical capture process. The study aimed to reducing CO2 emissions from coal combustion process in the circulating fluidized bed combustion (CFBC). The post-combustion CO2 capture process was analyzed using primary amine MEA in the following conditions: the ratio L/G was varied between 0.45..1.6 kgliquid/kggas keeping constant the flue gas flow and varying the solvent flow between 500 .. 1 600 kg/h. The CO2 capture process efficiency was maintained constant around 90%. For a concentration of 30% MEA in solution, it was observed that when the absorber solution temperature increasing from 32 to 49 °C, the amount of heat required for the solvent regeneration increased from 2.1 to 3.3 GJ/tCO2 according to the solvent pressure and flue gas pressure respectively. On the other hand, for varying the absorber solvent pressure in the range 1.1 .. 2.1 atm, the heat required by the process was not significantly influenced. Considering the same variation of the absorber solvent temperature, the rich loading solvent was increased from 0.43 to 0.57 mol CO2/mol MEA and consequently the MEA capacity of CO2 absorption from 0.3 to 0.422 molCO2/mol MEA.
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46

Goel, Chitrakshi, Haripada Bhunia, and Pramod K. Bajpai. "Resorcinol–formaldehyde based nanostructured carbons for CO2 adsorption: kinetics, isotherm and thermodynamic studies." RSC Advances 5, no. 113 (2015): 93563–78. http://dx.doi.org/10.1039/c5ra16255f.

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Silica templated nanostructured carbons were developed from a resorcinol–formaldehyde polymeric precursor by varying the carbonization temperature for capture of CO2 from simulated flue gas under dynamic flow conditions.
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47

Dębowski, Marcin, Mirosław Krzemieniewski, Marcin Zieliński, and Joanna Kazimierowicz. "Immobilized Microalgae-Based Photobioreactor for CO2 Capture (IMC-CO2PBR): Efficiency Estimation, Technological Parameters, and Prototype Concept." Atmosphere 12, no. 8 (August 12, 2021): 1031. http://dx.doi.org/10.3390/atmos12081031.

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Microalgae-mediated CO2 sequestration has been a subject of numerous research works and has become one of the most promising strategies to mitigate carbon dioxide emissions. However, feeding flue and exhaust gas into algae-based systems has been shown to destroy chloroplasts, as well as disrupt photosynthesis and other metabolic processes in microalgae, which directly limits CO2 uptake. CO2 biosequestration in existing photobioreactors (PBRs) is also limited by the low biomass concentration in the growth medium. Therefore, there is a real need to seek alternative solutions that would be competitive in terms of performance and cost-effectiveness. The present paper reports the results of experiments aimed to develop an innovative trickle bed reactor that uses immobilized algae to capture CO2 from flue and exhaust gas (IMC-CO2PBR). In the experiment, ambient air enriched with technical-grade CO2 to a CO2 concentration of 25% v/v was used. The microalgae immobilization technology employed in the experiment produced biomass yields approximating 100 g DM/dm3. A relationship was found between CO2 removal rates and gas volume flux: almost 40% of CO2 was removed at a feed of 25 dm3 of gas per hour, whereas in the 200 dm3/h group, the removal efficiency amounted to 5.9%. The work includes a determination of basic process parameters, presentation of a developed functional model and optimized lighting system, proposals for components to be used in the system, and recommendations for an automation and control system for a full-scale implementation.
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48

He, Li Juan, Jie Qiong Li, Yan Ling Ni, Jun Hua Yi, and Wen Fei Wu. "Experimental Study on Mass Transfer Performances in a New Rotating Packed Bed." Advanced Materials Research 726-731 (August 2013): 2182–85. http://dx.doi.org/10.4028/www.scientific.net/amr.726-731.2182.

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Based on the vapor-liquid equilibrium principle, a new rotating packed absorption tower was presented against some traditional gas-liquid countercurrent tower defects. An experimental device was built to test CO2 absorption efficiency in the packed absorption tower under the given experimental conditions. The experimental results show that the new packed absorption tower can capture the simulated flue gas CO2 and have a higher efficiency 87.8%.
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49

Lian, Xinbo, Leilei Xu, Mindong Chen, Cai-e. Wu, Wenjing Li, Bingbo Huang, and Yan Cui. "Carbon Dioxide Captured by Metal Organic Frameworks and Its Subsequent Resource Utilization Strategy: A Review and Prospect." Journal of Nanoscience and Nanotechnology 19, no. 6 (June 1, 2019): 3059–78. http://dx.doi.org/10.1166/jnn.2019.16647.

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The carbon dioxide (CO2) is notorious as the greenhouse gas, which could cause the global warming and climate change. Therefore, the reduction of the atmospheric CO2 emissions from power plants and other industrial facilities has become as an increasingly urgent concern. In the recent years, CO2 capture and storage technologies have received a worldwide attention. Adsorption is considered as one of the efficient options for CO2 capture because of its cost advantage, low energy requirement and extensive applicability over a relatively wide range of temperature and pressure. The metal organic frameworks (MOFs) show widely potential application prospects in CO2 capture and storage owing to their outstanding textural properties, such as the extraordinarily high specific surface area, tunable pore size, ultrahigh porosity (up to 90%), high crystallinity, adjustable internal surface properties, and controllable structure. Herein, the most important research progress of MOFs materials on the CO2 capture and storage in recent years has been comprehensively reviewed. The extraordinary characteristics and CO2 capture performance of Zeolitic Imidazolate Frameworks (ZIFs), Bio-metal organic frameworks (bio-MOFs), IL@MOFs and MOF-composite materials were highlighted. The promising strategies for improving the CO2 adsorption properties of MOFs materials, especially the low-pressure adsorption performance under actual flue gas conditions, are also carefully summarized. Besides, CO2 is considered as an abundant, nontoxic, nonflammable, and renewable C1 resource for the synthesis of useful chemicals and fuels. The potential routes for resource utilization of the captured CO2 are briefly proposed.
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Osagie, EI. "Evaluation of Emissions of 2-Amino-2-Methyl-1-Propanol Degradation Products by adding Degradation Reactions to the Carbon Dioxide Capture Unit." Journal of Applied Sciences and Environmental Management 24, no. 11 (January 11, 2021): 1993–98. http://dx.doi.org/10.4314/jasem.v24i11.21.

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Degradation is a major problem which poses lots of emission risk during chemical absorption process with amine solvents. Degradation occurs through irreversible side reactions with CO2 and other flue gas components, forming into products that cannot easily regenerate. The degradation products then react with amines to form thermally stable salts, which accumulate in the system over time. The problems associated with degradation include decreased plant equipment life, foaming, corrosion, high solution viscosity, and increased operating cost. Amines capture about 70 90% CO2 from commercial power stations. These high removal rates have many environmental impacts due to their degradation products. Researchers have therefore shown interest in characterising and quantifying atmospheric emissions of amines and their degradation products. In this study, 2-Amino-2-Methyl-1-Propanol (AMP) degradation reactions were included into a largescale capture plant model to evaluate the influence of process variables, the emissions of AMP and its degradation products. Steadystate simulations were performed using Aspen Plus® V8.4 software to provide a full assessment of the degradation products and their impact on the capture process. This assessment is important because it identifies and quantifies all pollutants emitted from the process plant. The results of the simulation indicate that AMP emissions are 3.04E+03mg/Nm3 of CO2 lean flue gas, while the quantity of AMP lost due to degradation was 37.88kg/s for the largescale capture plant. The results further showed that among the gases emitted, ammonia was highest, while acetone was the highest gas formed. In this study, 2-amino-2-methyl-1-propanol (AMP) degradation reactions were included into a largescale carbon dioxide (CO2) capture plant model to evaluate the influence of process variables, AMP emissions and its degradation products. Steadystate simulations were performed using Aspen Plus® V8.4 software to provide a full assessment of the degradation products and their impact on the largescale AMP capture process. The results of the equilibrium model developed in this study revealed that AMP emissions are 3.04E+03mg/Nm3 of CO2 lean flue gas, while the quantity of AMP lost due to degradation was 37.88kg/s for the largescale capture plant. More importantly, the emissions obtained from the PWOD and PWD are 7.80E+03 mg/Nm3 and 9.82E+03 mg/Nm3 of CO2 respectively. Keywords: oxidative degradation, 2amino2methyl1 propanol, emissions, modelling
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