Relevant bibliographies by topics / Flue gas CO2 capture

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  1. Journal articles
  2. Dissertations / Theses
  3. Books
  4. Book chapters
  5. Conference papers
  6. Reports

Academic literature on the topic 'Flue gas CO2 capture'

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

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Journal articles on the topic "Flue gas CO2 capture"

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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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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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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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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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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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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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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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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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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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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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Dissertations / Theses on the topic "Flue gas CO2 capture"

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Hu, Yukun. "CO2 capture from oxy-fuel combustion power plants." Licentiate thesis, KTH, Energiprocesser, 2011. http://urn.kb.se/resolve?urn=urn:nbn:se:kth:diva-48666.

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To mitigate the global greenhouse gases (GHGs) emissions, carbon dioxide (CO2) capture and storage (CCS) has the potential to play a significant role for reaching mitigation target. Oxy-fuel combustion is a promising technology for CO2 capture in power plants. Advantages compared to CCS with the conventional combustion technology are: high combustion efficiency, flue gas volume reduction, low fuel consumption, near zero CO2 emission, and less nitrogen oxides (NOx) formation can be reached simultaneously by using the oxy-fuel combustion technology. However, knowledge gaps relating to large scale coal based and natural gas based power plants with CO2 capture still exist, such as combustors and boilers operating at higher temperatures and design of CO2 turbines and compressors. To apply the oxy-fuel combustion technology on power plants, much work is focused on the fundamental and feasibility study regarding combustion characterization, process and system analysis, and economic evaluation etc. Further studies from system perspective point of view are highlighted, such as the impact of operating conditions on system performance and on advanced cycle integrated with oxy-fuel combustion for CO2 capture. In this thesis, the characterization for flue gas recycle (FGR) was theoretically derived based on mass balance of combustion reactions, and system modeling was conducted by using a process simulator, Aspen Plus. Important parameters such as FGR rate and ratio, flue gas composition, and electrical efficiency etc. were analyzed and discussed based on different operational conditions. An advanced evaporative gas turbine (EvGT) cycle with oxy-fuel combustion for CO2 capture was also studied. Based on economic indicators such as specific investment cost (SIC), cost of electricity (COE), and cost of CO2avoidance (COA), economic performance was evaluated and compared among various system configurations. The system configurations include an EvGT cycle power plant without CO2 capture, an EvGT cycle power plant with chemical absorption for CO2 capture, and a combined cycle power plant. The study shows that FGR ratio is of importance, which has impact not only on heat transfer but also on mass transfer in the oxy-coal combustion process. Significant reduction in the amount of flue gas can be achieved due to the flue gas recycling, particularly for the system with more prior upstream recycle options. Although the recycle options have almost no effect on FGR ratio, flue gas flow rate, and system electrical efficiency, FGR options have significant effects on flue gas compositions, especially the concentrations of CO2 and H2O, and heat exchanger duties. In addition, oxygen purity and water/gas ratio, respectively, have an optimum value for an EvGT cycle power plant with oxy-fuel combustion. Oxygen purity of 97 mol% and water/gas ratio of 0.133 can be considered as the optimum values for the studied system. For optional operating conditions of flue gas recycling, the exhaust gas recycled after condensing (dry recycle) results in about 5 percentage points higher electrical efficiency and about 45 % more cooling water consumption comparing with the exhaust gas recycled before condensing (wet recycle). The direct costs of EvGT cycle with oxy-fuel combustion are a little higher than the direct costs of EvGT cycle with chemical absorption. However, as plant size is larger than 60 MW, even though the EvGT cycle with oxy-fuel combustion has a higher COE than the EvGT cycle with chemical absorption, the EvGT cycle with oxy-fuel combustion has a lower COA. Further, compared with others studies of natural gas combined cycle (NGCC), the EvGT system has a lower COE and COA than the NGCC system no matter which CO2 capture technology is integrated.
QC 20111123
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Khunsupat, Ratayakorn. "Poly(allylamine) and derivatives for co2 capture from flue gas or ultra dilute gas streams such as ambient air." Thesis, Georgia Institute of Technology, 2011. http://hdl.handle.net/1853/44909.

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Polymers rich in primary amine groups are proposed to be effective adsorbents for the reversible adsorption of CO2 from moderately dilute gas streams (10% CO2) and ultra-dilute gas streams (e.g. ambient air, 400 ppm CO2), with their performance under ultra-dilute conditions being competitive with or exceeding the state-of-the-art adsorbents based on supported poly(ethyleneimine) (PEI). The CO2 adsorption capacity (mmol CO2/g sorbent) and amine efficiency (mmol CO2/mmol amine) of linear poly(allylamine) (PAA), cross-linked poly(allylamine) prepared by post-polymerization crosslinking with epichlorohydrin (PAAEPI), and branched poly(allylamine) prepared by branching of poly(allylamine) with divinylbenzene (PAADVB) are presented here and compared with state-of-the-art adsorbents based on supported PEI, specifically branched and linear, low molecular weight PEI. Silica mesocellular foam, MCF, serves as the support material for impregnation of the amine polymers. In general, branched polymers are found to yield more effective adsorbents materials. Overall, the results of this work show that linear PAA, cross-linked PAAEPI, and branched PAADVB are promising candidates for solid adsorbents with high capacity for CO2.
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Chen, Yuanxin. "POLYMER MEMBRANES FOR FLUE GAS CARBON CAPTURE AND FUEL CELL APPLICATION." The Ohio State University, 2015. http://rave.ohiolink.edu/etdc/view?acc_num=osu1440069742.

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Wang, Alan Yao. "Steam Reactivation and Separation of Limestone Sorbents for High Temperature Post-combustion CO2 Capture from Flue Gas." The Ohio State University, 2012. http://rave.ohiolink.edu/etdc/view?acc_num=osu1342457128.

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Salim, Witopo. "CO2-selective Membranes for Fuel Cell H2 Purification and Flue Gas CO2 Capture: From Lab Scale to Field Testing." The Ohio State University, 2018. http://rave.ohiolink.edu/etdc/view?acc_num=osu1514889154359659.

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Cheung, Ocean. "Narrow-pore zeolites and zeolite-like adsorbents for CO2 separation." Doctoral thesis, Stockholms universitet, Institutionen för material- och miljökemi (MMK), 2014. http://urn.kb.se/resolve?urn=urn:nbn:se:su:diva-101629.

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A range of porous solid adsorbents were synthesised and their ability to separate and capture carbon dioxide (CO2) from gas mixtures was examined. CO2 separation from flue gas – a type of exhaust gas from fossil fuel combustion that consists of CO2 mixed with mainly nitrogen and biogas (consists of CO2 mixed with mainly methane) were explicitly considered. The selected adsorbents were chosen partly due to their narrow pore sizes. Narrow pores can differentiate gas molecules of different sizes via a kinetic separation mechanism: a large gas molecule should find it more difficult to enter a narrow pore. CO2 has the smallest kinetic diameter in zeolites when compared with the other two gases in this study. Narrow pore adsorbents can therefore, show enhanced kinetic selectivity to adsorb CO2 from a gas mixture. The adsorbents tested in this study included mixed cation zeolite A, zeolite ZK-4, a range of aluminophosphates and silicoaluminophosphates, as well as two types of titanium silicates (ETS-4, CTS-1). These adsorbents were compared with one another from different aspects such as CO2 capacity, CO2 selectivity, cyclic performance, working capacity, cost of synthesis, etc. Each of the tested adsorbents has its advantages and disadvantages. Serval phosphates were identified as potentially good CO2 adsorbents, but the high cost of their synthesis must be addressed in order to develop these adsorbents for applications.

At the time of the doctoral defence the following papers were unpublished and had a status as follows: Papers 4-8: Manuscripts.

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Ramasubramanian, Kartik. "CO2 (H2S)-SELECTIVE MEMBRANES FOR FUEL CELL HYDROGEN PURIFICATION AND FLUE GAS CARBON CAPTURE:AN EXPERIMENTAL AND PROCESS MODELING STUDY." The Ohio State University, 2013. http://rave.ohiolink.edu/etdc/view?acc_num=osu1374193903.

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Islamoglu, Timur. "SYSTEMATIC POSTSYNTHETIC MODIFICATION OF NANOPOROUS ORGANIC FRAMEWORKS AND THEIR PERFORMANCE EVALUATION FOR SELECTIVE CO2 CAPTURE." VCU Scholars Compass, 2016. http://scholarscompass.vcu.edu/etd/4264.

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Porous organic polymers (POPs) with high physicochemical stability have attracted significant attention from the scientific community as promising platforms for small gas separation adsorbents. Although POPs have amorphous morphology in general, with the help of organic chemistry toolbox, ultrahigh surface area materials can be synthesized. In particular, nitrogen-rich POPs have been studied intensively due to their enhanced framework-CO2 interactions. Postsynthetic modification (PSM) of POPs has been instrumental for incorporating different functional groups into the pores of POPs which would increase the CO2 capture properties. We have shown that functionalizing the surface of POPs with nitro and amine groups increases the CO/N2 and CO2/CH4 selectivity significantly due to selective polarization of CO2 molecule. In addition, controlled postsynthetic nitration of NPOF-1, a nanoporous organic framework constructed by nickel(0)-catalyzed Yamamoto coupling of 1,3,5-tris(4-bromophenyl)benzene, has been performed and is proven to be a promising route to introduce nitro groups and to convert mesopores to micropores without compromising surface area. Reduction of the nitro groups yields aniline-like amine-functionalized NPOF-1-NH2. Adequate basicity of the amine functionalities leads to modest isosteric heats of adsorption for CO2, which allow for high regenerability. The unique combination of high surface area, microporous structure, and amine-functionalized pore walls enables NPOF-1-NH2 to have remarkable CO2 working capacity values for removal from landfill gas and flue gas. Benzimidazole-linked polymers have also been shown to have promising CO2 capture properties. Here, an amine functionalized benzimidazole-linked polymer (BILP-6-NH2) was synthesized via a combination of pre- and postsynthetic modification techniques in two steps. Experimental studies confirm enhanced CO2 uptake in BILP-6-NH2 compared to BILP-6, and DFT calculations were used to understand the interaction modes of CO2 with BILP-6-NH2. Using BILP-6-NH2, higher CO2 uptake and CO2/CH4 selectivity was achieved compared to BILP-6 showing that this material has a very promising working capacity and sorbent selection parameter for landfill gas separation under VSA settings. Additionally, the sorbent evaluation criteria of different classes of organic polymers have been compared in order to reveal structure-property relationships in those materials as solid CO2 adsorbents.
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Iyer, Mahesh Venkataraman. "High temperature reactive separation process for combined carbon dioxide and sulfur dioxide capture from flue gas and enhanced hydrogen production with in-situ carbon dioxide capture using high reactivity calcium and biomineral sorbents." The Ohio State University, 2006. http://rave.ohiolink.edu/etdc/view?acc_num=osu1135961929.

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Schallert, Bernd [Verfasser], and Günter [Akademischer Betreuer] Scheffknecht. "Leaching of fly ash particulate matter in MEA solutions and its relevance to the CO2 capture process with flue gas of coal-fired power plants / Bernd Schallert ; Betreuer: Günter Scheffknecht." Stuttgart : Universitätsbibliothek der Universität Stuttgart, 2020. http://d-nb.info/1222515490/34.

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Books on the topic "Flue gas CO2 capture"

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Budzianowski, Wojciech M., ed. Energy Efficient Solvents for CO2 Capture by Gas-Liquid Absorption. Cham: Springer International Publishing, 2017. http://dx.doi.org/10.1007/978-3-319-47262-1.

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Oxy-fuel combustion for power generation and carbon dioxide (CO2) capture. Oxford: Woodhead Pub., 2011.

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Holwerda, Marijn. EU regulation of cross-border carbon capture and storage: Legal issues under the directive on the geological storage of CO2 in the light of primary EU law. Cambridge: Intersentia, 2014.

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Zheng, L., and Ligang Zheng. Oxy-Fuel Combustion for Power Generation and Carbon Dioxide (Co2) Capture. Elsevier Science & Technology, 2016.

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Captage et stockage du CO2. Enjeux techniques et sociaux en France. Versailles, France: éditions Quae, 2010.

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Budzianowski, Wojciech M. Energy Efficient Solvents for CO2 Capture by Gas-Liquid Absorption: Compounds, Blends and Advanced Solvent Systems. Springer, 2018.

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Budzianowski, Wojciech M. Energy Efficient Solvents for CO2 Capture by Gas-Liquid Absorption: Compounds, Blends and Advanced Solvent Systems. Springer, 2016.

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Cook, Peter J. Clean Energy, Climate and Carbon. CSIRO Publishing, 2012. http://dx.doi.org/10.1071/9780643106826.

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With the general reader in mind, Clean Energy, Climate and Carbon outlines the global challenge of decreasing greenhouse gas emissions. It covers the changing concentration of atmospheric carbon dioxide through time and its causes, before considering the promise and the limitations of a wide range of energy technologies for decreasing carbon dioxide emissions. Despite the need to decrease carbon dioxide, the fact is that the global use of fossil fuels is increasing and is likely to continue to do so for some decades to come. With this in mind, the book considers in detail, what for many people is the unfamiliar clean energy technology of carbon capture and storage (CCS). How can we capture carbon dioxide from flue gases? How do we transport it? How do we store it in suitable rocks? What are suitable rocks and where do we find them? How do we know the carbon dioxide will remain trapped once it is injected underground? What does CCS cost and how do those costs compare with other technology options? The book also explores the political environment in which the discussion on clean energy technology options is occurring. What will a price on carbon do for technology uptake and what are the prospects of cutting our emissions by 2020 and of making even deeper cuts by 2050? What will the technology mix look like by that time? For people who are concerned about climate change, or who want to learn more about clean energy technologies, including CCS, this is the definitive view of the opportunities and the challenges we face in decreasing emissions despite a seemingly inexorable global increase in energy demand.
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Book chapters on the topic "Flue gas CO2 capture"

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He, Xuezhong. "Membranes for CO2 Capture from Flue Gas." In Encyclopedia of Membranes, 1–3. Berlin, Heidelberg: Springer Berlin Heidelberg, 2015. http://dx.doi.org/10.1007/978-3-642-40872-4_1333-12.

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Majchrzak-Kucęba, I., and W. Nowak. "Development of Fly Ash-Based Sorbent to Capture CO2 from Flue Gas." In Proceedings of the 20th International Conference on Fluidized Bed Combustion, 596–602. Berlin, Heidelberg: Springer Berlin Heidelberg, 2009. http://dx.doi.org/10.1007/978-3-642-02682-9_90.

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Ahmad, A. L., Y. O. Salaudeen, and Z. A. Jawad. "Polymeric Membrane for Flue Gas Separation and Other Minor Components in Carbon Dioxide Capture." In Membrane Technology for CO2 Sequestration and Separation, 39–73. Boca Raton, FL : CRC Press, Taylor & Francis Group, [2018] | “A science publishers book.”: CRC Press, 2019. http://dx.doi.org/10.1201/b22409-3.

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Zhang, Lin, Bin Hu, Hao Wu, Xia Wang, Rui Liu, and Linjun Yang. "CO2 Capture Using Hollow Fiber Membrane Under Wet Ammonia-Based Desulfurization Flue Gas Conditions." In Clean Coal Technology and Sustainable Development, 365–71. Singapore: Springer Singapore, 2016. http://dx.doi.org/10.1007/978-981-10-2023-0_49.

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Pirngruber, Gerhard D., and Philip L. Llewellyn. "Opportunities for MOFs in CO2 Capture from Flue Gases, Natural Gas, and Syngas by Adsorption." In Metal-Organic Frameworks, 99–119. Weinheim, Germany: Wiley-VCH Verlag GmbH & Co. KGaA, 2011. http://dx.doi.org/10.1002/9783527635856.ch5.

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Bandyopadhyay, Amitava. "Aqueous NH3 in CO2 Capture from Coal-Fired Thermal Power Plant Flue Gas: N-Fertilizer Production Potential and GHG Emission Mitigation." In Green Energy and Technology, 269–97. Singapore: Springer Singapore, 2017. http://dx.doi.org/10.1007/978-981-10-3352-0_19.

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Chiang, Pen-Chi, and Shu-Yuan Pan. "Carbon Capture with Flue Gas Purification." In Carbon Dioxide Mineralization and Utilization, 337–59. Singapore: Springer Singapore, 2017. http://dx.doi.org/10.1007/978-981-10-3268-4_17.

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Blythe, Gary. "Mercury Capture in Wet Flue Gas Desulfurization Systems." In Mercury Control, 261–76. Weinheim, Germany: Wiley-VCH Verlag GmbH & Co. KGaA, 2014. http://dx.doi.org/10.1002/9783527658787.ch16.

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Ali, Liaqat, and Russell E. Bentley. "Well Modeling Aspects of CO2 Sequestration." In Carbon Dioxide Capture and Acid Gas Injection, 199–219. Hoboken, NJ, USA: John Wiley & Sons, Inc., 2017. http://dx.doi.org/10.1002/9781118938706.ch11.

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Lee, S., and R. A. Marriott. "Sulfur Recovery in High Density CO2 Fluid." In Carbon Dioxide Capture and Acid Gas Injection, 63–69. Hoboken, NJ, USA: John Wiley & Sons, Inc., 2017. http://dx.doi.org/10.1002/9781118938706.ch4.

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Conference papers on the topic "Flue gas CO2 capture"

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GARCIA, C., C. A. HABERT, and C. P. BORGES. "CO2 CAPTURE FROM FLUE GAS USING MEMBRANE CONTACTORS." In XXII Congresso Brasileiro de Engenharia Química. São Paulo: Editora Blucher, 2018. http://dx.doi.org/10.5151/cobeq2018-co.067.

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Rivera de la Ossa, Juan Eduardo, Alberto Bejarano, Alberto Flórez, and Nicolás Santos. "Experimental Evaluation of the Flue-Gas Injection of Barrancabermeja Refinery as EOR Method." In SPE International Conference on CO2 Capture, Storage, and Utilization. Society of Petroleum Engineers, 2010. http://dx.doi.org/10.2118/139715-ms.

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Akram, Muhammad, Bhupendra Khandelwal, Simon Blakey, and Christopher W. Wilson. "Preliminary Calculations on Post Combustion Carbon Capture From Gas Turbines With Flue Gas Recycle." In ASME Turbo Expo 2013: Turbine Technical Conference and Exposition. American Society of Mechanical Engineers, 2013. http://dx.doi.org/10.1115/gt2013-94968.

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Carbon capture is getting increased attention recently due to the fact that it seems to be the only answer to decrease emissions. Gas turbines exhaust have 3–5 % concentration of CO2 which is very low to be captured by an amine carbon capture plant effectively. The amine based plants are most effective at around 10 – 15% CO2 in the flue gas. In order to increase the concentration of CO2 in the exhaust of the gas turbine, part of the exhaust gas needs to be recycled back to the air inlet. On reaching the concentration of CO2 around 10% it can be fed to the amine capture plant for effective carbon capture. A 100 kWe (plus 150 kW hot water) CHP gas turbine Turbec T100 is installed at the Low Carbon Combustion Centre of the University of Sheffield. The turbine set up will be modified to make it CO2 capture ready. The exhaust gases obtained will be piped to amine capture plant for testing capture efficiency. Preliminary calculations have been done and presented in this paper. The thermodynamic properties of CO2 are different from nitrogen and will have an effect on compressor, combustor and turbine performance. Preliminary calculations of recycle ratios and other performance based parameters have been presented in this paper. This paper also covers the aspects of turbine set up machinery which needs to be modified and what kind of modifications may be needed.
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Narula, Ram G., and Harvey Wen. "The Battle of CO2 Capture Technologies." In ASME Turbo Expo 2010: Power for Land, Sea, and Air. ASMEDC, 2010. http://dx.doi.org/10.1115/gt2010-22921.

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Coal is an abundant, widespread, cheap energy source and contributes to 39% of the world’s electric power generation. Coal releases large amounts of carbon dioxide (CO2), which is believed to play a major role in global warming and climate change. To de-carbonize power generation, three distinct carbon capture technologies are in varying stages of development. These include pre-combustion carbon capture through the use of integrated coal gasification combined cycle (IGCC), post-combustion carbon capture from a pulverized-coal (PC)-fired power plant flue gas using monoethanolamine (MEA) or ammonia (NH3), and oxy-combustion technology. In the latter technology, oxygen is first separated from nitrogen in an air separator unit and used for combustion of coal in a conventional PC boiler. With oxy-combustion technology, the resulting flue gas is predominantly CO2, which makes CO2 capture easier than in the PC-MEA case. This paper discusses the development status as well as the advantages, limitations, performance and economics of each technology in regard to the capture and non-capture cases.
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Sander, Frank, Richard Carroni, Stefan Rofka, and Eribert Benz. "Flue Gas Recirculation in a Gas Turbine: Impact on Performance and Operational Behavior." In ASME 2011 Turbo Expo: Turbine Technical Conference and Exposition. ASMEDC, 2011. http://dx.doi.org/10.1115/gt2011-45608.

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The rigorous reduction of greenhouse gas emissions in the upcoming decades is only achievable with contribution from the following strategies: production efficiency, demand reduction of energy and carbon dioxide (CO2) capture from fossil fueled power plants. Since fossil fueled power plants contribute largely to the overall global greenhouse gas emissions (> 25% [1]), it is worthwhile to capture and store the produced CO2 from those power generation processes. For natural-gas-fired power plants, post-combustion CO2 capture is the most mature technology for low emissions power plants. The capture of CO2 is achieved by chemical absorption of CO2 from the exhaust gas of the power plant. Compared to coal fired power plants, an advantage of applying CO2 capture to a natural-gas-fired combined cycle power plant (CCPP) is that the reference cycle (without CO2 capture) achieves a high net efficiency. This far outweighs the drawback of the lower CO2 concentration in the exhaust. Flue Gas Recirculation (FGR) means that flue gas after the HRSG is partially cooled down and then fed back to the GT intake. In this context FGR is beneficial because the concentration of CO2 can be significantly increased, the volumetric flow to the CO2 capture unit will be reduced, and the overall performance of the CCPP with CO2 capture is increased. In this work the impact of FGR on both the Gas Turbine (GT) and the Combined Cycle Power Plant (CCPP) is investigated and analyzed. In addition, the impact of FGR for a CCPP with and without CO2 capture is investigated. The fraction of flue gas that is recirculated back to the GT, need further to be cooled, before it is mixed with ambient air. Sensitivity studies on flue gas recirculation ratio and temperature are conducted. Both parameters affect the GT with respect to change in composition of working fluid, the relative humidity at the compressor inlet, and the impact on overall performance on both GT and CCPP. The conditions at the inlet of the compressor also determine how the GT and water/steam cycle are impacted separately due to FGR. For the combustion system the air/fuel-ratio (AFR) is an important parameter to show the impact of FGR on the combustion process. The AFR indicates how close the combustion process operates to stoichiometric (or technical) limit for complete combustion. The lower the AFR, the closer operates the combustion process to the stoichiometric limit. Furthermore, the impact on existing operational limitations and the operational behavior in general are investigated and discussed in context of an operation concept for a GT with FGR.
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Guntuka, Sathish Kumar, Rama Rao Vemula, Ricky Nilam, Faruque Hassan, Paul Sharratt, Mohammad Amanullah, Iftekhar A. Karimi, Arvind Rajendran, and Shamsuzzaman Farooq. "Adsorptive Capture of CO2 from Post-Combustion Flue Gas: A Pilot Plant Study." In 14th Asia Pacific Confederation of Chemical Engineering Congress. Singapore: Research Publishing Services, 2012. http://dx.doi.org/10.3850/978-981-07-1445-1_717.

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Zhang, Zhien, Yunfei Yan, Junlei Wang, Li Zhang, Yanrong Chen, and Shunxiang Ju. "Analysis of CO2 Capture From Power-Plant Flue Gas Using the Membrane Gas Absorption (MGA) Method." In ASME 2015 Power Conference collocated with the ASME 2015 9th International Conference on Energy Sustainability, the ASME 2015 13th International Conference on Fuel Cell Science, Engineering and Technology, and the ASME 2015 Nuclear Forum. American Society of Mechanical Engineers, 2015. http://dx.doi.org/10.1115/power2015-49026.

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Currently membrane gas absorption (MGA) is a novel approach for gas separation. In the present work, a wide-ranging 2D mathematical model for CO2 absorption from the N2/CO2 mixture is proposed. Single solvents [H2O, ethylenediamine (EDA), diethanolamine (DEA), monoethanolamine (MEA), piperazine (PZ)] and blended solvents [DEA/PZ] were used as the absorbents. The non-wetting mode for the membrane contactor was considered in the calculations. The effects of gas concentration and velocity, and liquid concentration and velocity on CO2 removal were observed. The simulation results were verified with the experimental data showing a good agreement. The modeling results indicate that gas concentration and velocity have a negative effect on the capture process, while liquid concentration and velocity enhance CO2 capture. Also, it is noted that PZ has the best absorption performance than other single absorbents. The chemical solvents are much better than the physical solvent for the absorption of CO2. For mixed absorbents based on amine solutions, the CO2 removal efficiency could be about 20% higher than that of the single solutions. Thus, this model could provide the optimum operating conditions for acid gas absorption in the hollow fiber membrane module. It is also proved that the MGA approach exhibits a good potential in power-plant waste gas purification.
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Carapellucci, Roberto, Roberto Cipollone, and Davide Di Battista. "MCFC-Based System for Active CO2 Capture From Flue Gases." In ASME 2018 International Mechanical Engineering Congress and Exposition. American Society of Mechanical Engineers, 2018. http://dx.doi.org/10.1115/imece2018-86881.

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Carbon dioxide emissions reduction in the atmosphere is the major driver of technological innovations, in particular in energy and industrial sectors. Those sectors are dominated by the use of fossil fuels whose main concern on the combustion gases is the presence of CO2. Their emission in atmosphere accumulates Carbon, the main cause of global warming. The only way to continue to make reference to fossil fuel in the medium-long term and to avoid the carbon accumulation in the atmosphere is to use technologies capable to capture and sequester the carbon in the flue gases (CCS). In the sector of electricity production, several technologies have been proposed for the capture CO2, including absorption, adsorption, cryogenic distillation or membrane separation. All of them offer flexibility and easiness of application, but they need external energy to operate. On the other hand, particular interest is reversed to those technological options that are able to remove CO2 without energy consumption; even more attention is reserved to those technologies which, suitably integrated with other conversion systems, can produce electrical energy at the same time, so increasing the electricity production with respect to the original plant. They are defined active systems and one of these is represented by Molten Carbonate Fuel Cells (MCFCs). In fact, MCFCs are fuel cell capable to concentrate CO2 at anode exhaust, making easier its capture, separation and storage and in parallel to contribute to the electricity production. In this paper, a comprehensive model of the MCFC is used to assess the opportunity related to its use as a CO2 remover from a flue gas as a CCS active device, without energy penalties related to traditional carbon capture methods (MEA, pre and post-combustion, oxy-combustion, etc.). Hence, it has been integrated in a wider system with auxiliary components: compressors to overcome pressure drops, steam generator (also using heat recovered from MCFC exhausts) for fuel dilution, fresh air integration in cathode inlet section, heat exchangers for thermal management and recovery. A CO2 compression and drying section has been considered and represented as a multi-step intercooled compression. The so-defined system can be used as a plug-in device able to be coupled to flue gases with different compositions and thermodynamic operating parameters (temperature, pressure, flow rates). Finally, it has been applied to a case study (a Natural Gas Combined Cycle power plant - NGCC) and the performance of the MCFC in terms of CO2 removal capacity, electrical power generation and size have been evaluated as well the energetic and environmental impact on the reference NGCC power plant.
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Setiawan, Yusup, Prima Besty Asthary, and Saepulloh. "CO2 flue gas capture for cultivation of Spirulina platensis in paper mill effluent medium." In INTERNATIONAL CONFERENCE ON BIOLOGY AND APPLIED SCIENCE (ICOBAS). AIP Publishing, 2019. http://dx.doi.org/10.1063/1.5115643.

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Li, H., and J. Yan. "Preliminary Study on CO2 Processing in CO2 Capture From Oxy-Fuel Combustion." In ASME Turbo Expo 2007: Power for Land, Sea, and Air. ASMEDC, 2007. http://dx.doi.org/10.1115/gt2007-27845.

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Oxy-fuel combustion is one of promising technologies for CO2 capture, which uses simple flue gas processing normally including compression, dehydration and purification/liquefaction (non-condensable gas separation). However relatively high levels of impurities in the flu gas present more challenges for the gas processing procedure. This paper studied the sensitivity of operating parameters to inlet composition, the effects of impurities on energy consumption, and the relationship between energy consumption and operating parameters. Results show that comparatively the total compression work is more sensitive to the composition of SO2 if the total mass flow is constant; while the operating temperature of purification is more sensitive to N2. To pursue the minimum energy consumption, from the viewpoint of impurity, the content of O2, N2, Ar and H2O should be lowered as much as possible, which means the amount of air leakage into the system and excess oxygen should be controlled at a low level in the combustion; as to SO2, if it is possible to co-deposit with CO2, its existence may be helpful to decrease compression work. From the viewpoint of operating parameters, low intermediate pressure, high intercooling temperature and high outlet pressure are favorable to achieve high energy utilization, if heat recovery is considered.
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Reports on the topic "Flue gas CO2 capture"

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Michael C. Trachtenberg. Biomimetic Membrane for CO2 Capture from Flue Gas. Office of Scientific and Technical Information (OSTI), May 2007. http://dx.doi.org/10.2172/926669.

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Liang Hu. CO2 Capture from Flue Gas by Phase Transitional Absorption. Office of Scientific and Technical Information (OSTI), June 2009. http://dx.doi.org/10.2172/975092.

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M. Mercedes Maroto-Valer, John M. Andresen, Yinzhi Zhang, and Zhe Lu. Development of Fly Ash Derived Sorbents to Capture CO2 from Flue Gas of Power Plants. Office of Scientific and Technical Information (OSTI), December 2003. http://dx.doi.org/10.2172/924619.

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Toy, Lora, Atish Kataria, and Raghubir Gupta. CO₂ Capture Membrane Process for Power Plant Flue Gas. Office of Scientific and Technical Information (OSTI), April 2012. http://dx.doi.org/10.2172/1062652.

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Fillerup, Eric, Zhonghua Zhang, Emanuela Peduzzi, Dongxiang Wang, Jiahua Guo, Xiaoliang Ma, Xiaoxing Wang, and Chunshan Song. CO{sub 2} Capture from Flue Gas Using Solid Molecular Basket Sorbents. Office of Scientific and Technical Information (OSTI), August 2012. http://dx.doi.org/10.2172/1084482.

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Merkel, Tim, Xiaotong Wei, Bilgen Firat, Jenny He, Karl Amo, Saurabh Pande, Richard Baker, Hans Wijmans, and Abhoyjit Bhown. Membrane Process to Capture CO{sub 2} from Coal-Fired Power Plant Flue Gas. Office of Scientific and Technical Information (OSTI), March 2012. http://dx.doi.org/10.2172/1089151.

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Chaubey, Trapti, Sudhir Kulkarni, David Hasse, and Alex Augustine. CO2 Capture by Cold Membrane Operation with Actual Power Plant Flue Gas. Office of Scientific and Technical Information (OSTI), July 2017. http://dx.doi.org/10.2172/1373105.

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Carroll, John. Demonstration of Advanced CO2 Capture Process Improvements for Coal-Fired Flue Gas. Office of Scientific and Technical Information (OSTI), October 2017. http://dx.doi.org/10.2172/1394632.

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Zhou, Shaojun, and Marty Lail. Large Bench-Scale Development of a Non-Aqueous Solvent (NAS) CO2 Capture Process for Coal-fired Power Plants Utilizing Real Coal-Derived Flue Gas. Office of Scientific and Technical Information (OSTI), November 2019. http://dx.doi.org/10.2172/1579191.

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Chen, Eric, Steven Fulk, Matt Beaudry, Yu-Jeng Lin, Darshan Sachde, Yue Zhang, Kent Stevens, et al. Evaluation of Concentrated Piperazine for CO2 Capture from Coal-Fired Flue Gas (Final Report, REV0). Office of Scientific and Technical Information (OSTI), March 2019. http://dx.doi.org/10.2172/1512446.

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