Relevant bibliographies by topics / Post-combustion system

Academic literature on the topic 'Post-combustion system'

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Published: 6 September 2023

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Journal articles on the topic "Post-combustion system"

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Zhaofeng, Xu, He Xin, Xue Yali, and Li Zheng. "Dynamic Simulation of Post-Combustion Capture System." Energy Procedia 37 (2013): 2164–71. http://dx.doi.org/10.1016/j.egypro.2013.06.095.

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Zhao, Li, Eko Primabudi, and Detlef Stolten. "Investigation of a Hybrid System for Post-Combustion Capture." Energy Procedia 63 (2014): 1756–72. http://dx.doi.org/10.1016/j.egypro.2014.11.183.

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Berger, Adam H., Yuqi Wang, Abhoyjit S. Bhown, Anthony Castrogiovanni, Robert Kielb, and Vladimir Balepin. "Thermodynamic Analysis of Post-combustion Inertial CO2 Extraction System." Energy Procedia 114 (July 2017): 7–16. http://dx.doi.org/10.1016/j.egypro.2017.03.1140.

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Hussain, Arshad, Sarah Farrukh, and Fozia T. Minhas. "Two-Stage Membrane System for Post-combustion CO2 Capture Application." Energy & Fuels 29, no. 10 (September 29, 2015): 6664–69. http://dx.doi.org/10.1021/acs.energyfuels.5b01464.

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Fernández, Javier, Maria Sotenko, Vladimir Derevschikov, Anton Lysikov, and Evgeny V. Rebrov. "A radiofrequency heated reactor system for post-combustion carbon capture." Chemical Engineering and Processing: Process Intensification 108 (October 2016): 17–26. http://dx.doi.org/10.1016/j.cep.2016.07.004.

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Raksajati, Anggit, Minh Ho, and Dianne Wiley. "Solvent Development for Post-Combustion CO2 Capture: Recent Development and Opportunities." MATEC Web of Conferences 156 (2018): 03015. http://dx.doi.org/10.1051/matecconf/201815603015.

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Chemical absorption is widely regarded as the most promising technology for post-combustion CO2 capture from large industrial emission sources with CO2 separation from natural gas using aqueous amine solvent system having been applied since the 1930s. The use of monoethanolamine (MEA) in CO2 absorption system possesses several drawbacks, such as high regeneration energy, high solvent loss, and high corrosion tendency. Various solvents have been developed for post-combustion CO2 capture application including the development of aqueous solvents and phase-change solvents. Some of these alternate solvents have been reported to have better solvent properties, which could improve the CO2 absorption system performance. This paper reviews key parameters involved in the design improvement of several chemical absorption process systems. In addition, some novel solvent systems are also discussed, for example encapsulated solvents systems. Some of the key solvent parameters that affect the capture performance, such as heat of reaction, absorption rate, solvent working capacity, solvent concentration, and solvent stability, are discussed in this paper, particularly in relation to the economic viability of the capture process. In addition, some guidelines for the future solvent development are discussed.
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Kawabata, Masako, Osamu Kurata, Norihiko Iki, Atsushi Tsutsumi, and Hirohide Furutani. "System modeling of exergy recuperated IGCC system with pre- and post-combustion CO2 capture." Applied Thermal Engineering 54, no. 1 (May 2013): 310–18. http://dx.doi.org/10.1016/j.applthermaleng.2013.01.029.

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Mulukutla, Tripura, Gordana Obuskovic, and Kamalesh K. Sirkar. "Novel scrubbing system for post-combustion CO2 capture and recovery: Experimental studies." Journal of Membrane Science 471 (December 2014): 16–26. http://dx.doi.org/10.1016/j.memsci.2014.07.037.

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Akinola, Toluleke E., Eni Oko, Yuanlin Gu, Hua-Liang Wei, and Meihong Wang. "Non-linear system identification of solvent-based post-combustion CO2 capture process." Fuel 239 (March 2019): 1213–23. http://dx.doi.org/10.1016/j.fuel.2018.11.097.

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Zhao, Li, Alexander Otto, Martin Robinius, and Detlef Stolten. "Investigation of the Cooling System of a Membrane-based Post-combustion Process." Energy Procedia 114 (July 2017): 666–85. http://dx.doi.org/10.1016/j.egypro.2017.03.1210.

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Dissertations / Theses on the topic "Post-combustion system"

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Abdul, Manaf Norhuda. "MANAGEMENT DECISION SUPPORT SYSTEM OF SOLVENT-BASED POST-COMBUSTION CARBON CAPTURE." Thesis, The University of Sydney, 2016. http://hdl.handle.net/2123/16567.

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A management decision-support framework for a coal-fired power plant with solvent based post combustion CO2 capture (PCC) (integrated plant) is proposed and developed in this thesis. A brief introduction pertaining to the solvent-based PCC technology, thesis motivations and objectives are given in Chapter 1. Chapter 2 comprises a comprehensive literature review of solvent-based PCC plant from the bottom level (PCC instrumentation level) until the top level (managerial decision of PCC system). Chapter 3 describes the development of solvent-based PCC dynamic model via empirical methods. Open-loop dynamic analyses are presented to provide a deeper understanding of the dynamic behaviour of key variables in solvent-based PCC plant. Chapter 4 presents the design of the control architecture for solvent-based PCC plant. Two control algorithms developed, which utilise conventional proportional, integral and derivative (PID) controller and advanced model predictive control (MPC). Chapter 5 proposes a conceptual framework for optimal operation of the integrated plant. The MPC scheme is chosen as the control algorithm while mixed integer non-linear programming (MINLP) using genetic algorithm (GA) function is employed in the optimization algorithm. Both algorithms are integrated to produce a hybrid MPC-MINLP algorithm. Capability and applicability of the algorithm is evaluated based on 24 hours and annual operation of integrated plant. Chapter 6 extends the scope of Chapter 5 by evaluating the relevance of solvent-based PCC technology in the operation of black coal-fired power plant in Australia. This chapter considers a prevailing climate policy established in Australia namely Emission Reduction Fund (ERF). Finally, the concluding remarks and future extensions of this research are presented in Chapter 7.
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Brasington, Robert David S. M. Massachusetts Institute of Technology. "Integration and operation of post-combustion capture system on coal-fired power generation: load following and peak power." Thesis, Massachusetts Institute of Technology, 2012. http://hdl.handle.net/1721.1/72878.

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Thesis (S.M. in Technology and Policy)-- Massachusetts Institute of Technology, Engineering Systems Division, Technology and Policy Program, 2012.
Cataloged from PDF version of thesis.
Includes bibliographical references (p. 85-87).
Coal-fired power plants with post combustion capture and sequestration (CCS) systems have a variety of challenges to integrate the steam generation, air quality control, cooling water systems and steam turbine with the capture system. A variety of engineering studies have been completed that cover these aspects when a plant is operating at full load while operating at a 90 percent capture rate. These studies investigate the basic integration of the these systems, the energy penalty and the effect of capital costs; however, none of these studies comprehensively explore the ability of the capture plant and the balance of the integrated system to respond dynamically to changes in load or capture rate. These load changes occur due to a change in demand for electricity in the system, generation by variable, intermittent resources, or if the plant is equipped with the ability to store solvent to implement price arbitrage. The integrated carbon capture system can be broken down into three general modes: full capacity, load following and peak power generation. Each of these modes presents unique challenges to integration with the CCS system. The load following mode requires the ability to accommodate different ramp rates that are reflected in flue gas flow and composition. Operation at partial load will affect the quality of steam sent to the solvent regeneration unit. Depending on the setup of the steam turbine system, at lower loads multiple extractions points may be necessary or an increase of the amount of extraction steam will be required due to the reduction in steam quality. Using Aspen Dynamics, a CO₂ capture system using a monoethanolamine (MEA) absorption process is simulated at various plant loads to determine the overall effects on the efficiency of the CCS unit and the balance of the system. In addition, the dynamic behavior of the CCS unit on power output and emissions is shown to demonstrate that the capability of a coal-fired power plant to load follow is not hindered by the addition of a carbon capture unit. The solvent storage mode can be further broken to two operation modes. The first is peak power production, which occurs when the solvent is capturing CO₂ from the flue gas, but is minimizing or delaying regeneration to a future time through storage. This mode is used to take advantage of peak power prices by maximizing power output of the plant and maintaining a 90 percent capture rate. The regeneration mode entails the solvent being released from the storage tanks and sent to the reboiler column. Solvent storage has been shown in previous studies to have the ability to increase operating profits, but these studies have neglected to incorporate the capital costs associated with this type of operation mode and the operational issues and complexity associated with the large swings in quantities of steam required for the solvent regeneration. By including the capital costs, this study determines that a system with large duration solvent storage is not economically viable given the flexible demands of the system and current electricity price spreads. This thesis presents a framework for considering the flexible operations of a coal-fired power plant with an integrated carbon capture and sequestration system. By exploring the operational limitations of the integrated system and the economic costs, an evaluation is made of the viability of different CCS operational schemes. This study finds that the CCS unit can match the dynamics of the base coal plant and also increase the operational flexibility of the system. The increased capital expenditure to meet peak demand is viable for larger steam turbine configurations in electricity systems with high peak prices and plants with short duration solvent storage.
by Robert David Brasington.
S.M.in Technology and Policy
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Samuelsson, Peter. "Management of technology in the process industries: Matching market and machine." Doctoral thesis, KTH, 2017. http://urn.kb.se/resolve?urn=urn:nbn:se:kth:diva-199705.

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The process industries span multiple industrial sectors and constitute a substantial part of the entire manufacturing industry. Since companies belonging to this family of industries are often very asset intensive, their ability to respond to changes is often limited in the short term. The adaptation of the capabilities of existing processes, and conversely finding products and market segments to match the production system capabilities, are an important part of product- and market development activities in the process industry. The importance to companies in the process industry of having a well-articulated manufacturing strategy congruent with the business strategy is second to none. However, to facilitate manufacturing strategy developments, it is essential to start with an improved characterization and understanding of the material transformation system. To that end an extensive set of variables was developed and related measures and scales were defined. The resulting configuration model, focusing on company generic process capabilities in the process industries, is to be regarded as a conceptual taxonomy and as a proposition available for further testing. The usability of the model was subsequently assessed using “mini-cases” in the forestry industry, where the respondents confirmed that the company’s overall strategy could benefit from this kind of platform as a possible avenue to follow. The model was deployed as an instrument in the profiling of company material transformation systems to facilitate the further development of companies' functional and business strategies. The use of company-generic production capabilities was studied in three case companies representing the mineral, food and steel industries. The model was found by the respondents to be usable as a knowledge platform to develop production strategies. In the final analysis of the research results, a new concept emerged called “production capability configuration": A process-industrial company’s alignment of its generic production capabilities in the areas of raw materials, process technology and products to improve the consistency among the variable elements that define operations and improve the congruence between operations and its environment. From the perspective of value creation and capture, firms must be able to manufacture products in a competitive cost structure within the framework of a proper business model. By using the configuration model, the relationship between manufacturing and innovation activities has been studied in the previously mentioned three case studies. In many cases the gap in capability appears as a limitation in the production system, requiring development efforts and sometimes investments to overcome. This is illustrated with two examples from the steel industry, where development efforts of the production system capabilities are initiated to better match the market demands. One example is the increase the volume- and product flexibility of an existing stainless steel melt shop, resulting in a proposed oblong Argon Oxygen Decarburisation (AOD) converter configuration that was subsequently verified using water modelling. The second example is from a carbon steel mill, where the target was to increase the raw material- and volume flexibility of another melt shop, by modifying the capabilities of the Electric Arc Furnace (EAF). Enabling EAF technologies are further described and evaluated using operational data and engineering type of estimates.

QC 20170116

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Glier, Justin C. "Assessment of Solid Sorbent Systems for Post - Combustion Carbon Dioxide Capture at Coal - Fired Power Plants." Research Showcase @ CMU, 2015. http://repository.cmu.edu/dissertations/741.

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In an effort to lower future CO2 emissions, a wide range of technologies are being developed to scrub CO2 from the flue gases of fossil fuel-based electric power and industrial plants. This thesis models one of several early-stage post-combustion CO2 capture technologies, solid sorbent-based CO2 capture process, and presents performance and cost estimates of this system on pulverized coal power plants. The spreadsheet-based software package Microsoft Excel was used in conjunction with AspenPlus modelling results and the Integrated Environmental Control Model to develop performance and cost estimates for the solid sorbent-based CO2 capture technology. A reduced order model also was created to facilitate comparisons among multiple design scenarios. Assumptions about plant financing and utilization, as well as uncertainties in heat transfer and material design that affect heat exchanger and reactor design were found to produce a wide range of cost estimates for solid sorbent-based systems. With uncertainties included, costs for a supercritical power plant with solid sorbent-based CO2 capture ranged from $167 to $533 per megawatt hour for a first-of-a-kind installation (with all costs in constant 2011 US dollars) based on a 90% confidence interval. The median cost was $209/MWh. Post-combustion solid sorbent-based CO2 capture technology is then evaluated in terms of the potential cost for a mature system based on historic experience as technologies are improved with sequential iterations of the currently available system. The range costs for a supercritical power plant with solid sorbent-based CO2 capture was found to be $118 to $189 per megawatt hour with a nominal value of $163 per megawatt hour given the expected range of technological improvement in the capital and operating costs and efficiency of the power plant after 100 GW of cumulative worldwide experience. These results suggest that the solid sorbent-based system will not be competitive with currently available liquid amine-systems in the absence of significant new improvements in solid sorbent properties and process system design to reduce the heat exchange surface area in the regenerator and cross-flow heat exchanger. Finally, the importance of these estimates for policy makers is discussed.
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Tait, Paul. "Pilot-scale testing of dynamic operation and measurement of interfacial wave dynamics in post-combustion carbon dioxide capture." Thesis, University of Edinburgh, 2018. http://hdl.handle.net/1842/29544.

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Flexible carbon capture and storage (CCS) has the potential to play a significant part in the decarbonisation of electricity generation portfolios which have significant penetration from intermittent renewable sources. Post-combustion capture (PCC) with amine solvents is a mature technology and is currently the state-of-the-art for CO2 emissions reduction from power stations. However, knowledge of the dynamic capture process is currently limited due to a dearth of dynamic datasets which reflect real plant operation, lack of a robust in-situ solvent analysis method for plant control and uncertainty about how changing plant design affects the response to dynamic operations. In addition, the nature of interfacial gas-liquid dynamics inside the absorber column are not well known and rely on correlations for effective mass transfer area and liquid holdup which may have uncertainties of up to +/- 13%. This could result in absorption columns being improperly sized for CCS operations. Two pilot-scale test campaigns are implemented in order to gain an understanding of how the capture plant responds to dynamic operations, the first on natural gas combined cycle (NGCC)-equivalent flue gas, the second on pulverised coal (PC)-equivalent. Changes in flue gas flow rates and steam supply which are designed to be representative of PCC operation on real NGCC and PC plant are implemented, using 30%wt monoethanolamine (MEA) as absorbent in both cases. Dynamic datasets are obtained for 5 scenarios with NGCC and 8 with PC flue gas. The test campaigns are carried out using two separate pilot-scale facilities and highlight the effect of plant design on hydrodynamics and hence, the response of the capture plant to dynamic operations. Finally, a novel solvent sensor is used to demonstrate, for the first time, control of the capture facility using in-situ measurements of solvent composition, combined with knowledge of test facility hydrodynamics and response times. Results from the pilot-scale test campaign are then used along with a mathematical NGCC capture plant scale up to investigate the potential effects of dynamic operations on total yearly CO2 emissions and the associated environmental penalties, depending on CO2 price. Manufacturers of column internals for CCS often rely on computational fluid dynamic (CFD) software tools for design, but existing commercial codes are unable to handle complex two-phase flows such as those encountered in the absorber column of a CO2 capture plant. An open-source direct numerical simulation (DNS) tool which will be capable of rigorously modelling two-phase flow with turbulence and mass transfer has been developed and could eventually replace the empirical methods currently used in packing design. The DNS code requires validation by experiment. For the purpose of validation a dual-purpose wetted-wall column is constructed, which in addition to mass transfer measurements can be used to determine liquid film thickness using an optical method. Measurements of average film thickness, wave amplitude, frequency, velocity and growth rate are provided for three liquid flow rates of fresh 30%wt MEA solution. Wave measurements are made with quiescent, laminar and turbulent gas flow, with and without mass transfer. These measurements can be used to validate the DNS code at its existing level of complexity, and in the future when turbulence and mass transfer are added.
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Wang, Yuan Verfasser], Detlef [Akademischer Betreuer] [Stolten, and Manfred [Akademischer Betreuer] Wirsum. "Techno-economic assessment of hybrid post-combustion carbon capture systems in coal-fired power plants and steel plants / Yuan Wang ; Detlef Stolten, Manfred Wirsum." Aachen : Universitätsbibliothek der RWTH Aachen, 2020. http://d-nb.info/1240838603/34.

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Villar, I. Comajoan Laia. "Simulation of stripper modifications for bioenergy carbon capture by absorption." Thesis, KTH, Kemiteknik, 2021. http://urn.kb.se/resolve?urn=urn:nbn:se:kth:diva-299891.

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Att koldioxidutsläppen neutraliseras är avgörande för att begränsa klimatförändringarna. Bioenergi i kombination med separation och lagring av koldioxid (BECCS) är en Teknik som kan generera negativa utsläpp. Det största hindret för dess storskaliga genomförande är de höga energikraven för processen. Detta projekt syftar till att kvantifiera energistraffen för lean solvent flash och modifikationer för multitrycksstrippning för att förbättra prestandan av koldioxidavskiljning (CC) i en kraftvärmeverksanläggning för förbränning av biomassa.  En jämviktsmodell utvecklades och validerades för att simulera en fullskalig CC genom kemisk absorption i Aspen Plus med kaliumkarbonat som lösningsmedel. Båda layoutändringarna resulterar i energipåföljder på 18-21 % för en kraftvärmeverk, medan energistraffet för baslinjeprocessen är 5 %. För ett kraftverk går straffen från 32 till 62 %. Detta visar hur en förbättring av processen kan minska kostnaderna för CCS, särskilt om värme anses vara en värdefull produkt. CCS i kraftvärmeverk har en mycket lägre energipåverkan än i kraftverk där värme inte återvinns.
Bio-energy with carbon capture and storage (BECCS) is a technology that can generate negative emissions. Hence it is recognized as a solution for becoming carbon neutral, which is essential for climate change mitigation. The main obstacle for its large scale implementation is the high energy requirements of the process. This thesis aims at quantifying the energy penalties for lean solvent flash and multi-pressure stripper layout modifications to improve the performance of carbon capture (CC) by means of absorption with a liquid solvent in a biomass-fired CHP plant. The work focuses on K2CO3 based solvents operated in a mixed temperature swing/pressure swing cycle witch is deemed advantageous for heat recovery.  An equilibrium model was developed and validated to simulate a full-scale CC by chemical absorption in Aspen Plus using potassium carbonate as solvent. Both layout modifications result in energy penalties of 18-21 % for a CHP plant, while the energy penalty for the baseline process is 28 %. For a power plant, the penalties go from 32 % to 62 % for the lean solvent flash and the multi-pressure stripper respectively. This shows how improving the process can reduce the costs of CCS, especially if heat is considered a valuable product. CCS in CHP plants has a much lower energy impact than in power plants where heat is not recovered.
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Jian-Syun-Li and 李建勳. "Post-combustion CO2 capture in a dry sorbent injection system." Thesis, 2015. http://ndltd.ncl.edu.tw/handle/24235645898048680655.

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碩士
國立中興大學
環境工程學系所
103
Powder 13X zeolite was employed as the adsorbent for CO2 capture from flue gas by the dry sorbent injection and the feasibility of this process was evaluated. Research results were divided into the following two phases.The first phase was the comparison of the efficiency of capturing carbon dioxide between concurrent and countercurrent dry sorbent injection with powder 13X zeolite. The results indicate that the best of adsorption capacity was obtained under 30°C with 15 vol% CO2 inlet using powder 13X zeolite by the countercurrent dry sorbent injection. The adsorption capacity (q) of powder 13X zeolite reached 11.8 mg/g under 0.33 m/s of superficial velocity with gas-solid feed ratio of 20 g/L.The second phase was the comparison of CO2 adsorption/desorption with powder 13X zeolite between dry and wet flue gas inflow by countercurrent dry sorbent injection . The results indicated that after 50 cycles, the average q ,the AI (adsorption index) and the CO2 removal efficiency(RE) respectively reached 11.49 mg/g, 99.12% and 82.2% with dry flue gas and 11.1 mg/g, 99.12% and 81.5% with wet flue gas. Above results reveal that the powder 13X zeolite with countercurrent dry sorbent injection system has feasibility on CO2 capture from both dry and wet flue gas.
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Chen, Jia-Xian, and 陳嘉賢. "Post-combustion CO2 capture in a Dry Sorbent Injection system." Thesis, 2016. http://ndltd.ncl.edu.tw/handle/85586514884678742723.

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碩士
國立中興大學
環境工程學系所
104
The aim of this research is to obtain a technique of carbon capture which has economical development, refering to air pollution equipment in existence, we aim to change DSI into a technique of carbon capture. We use commercial material, zeolite 13X, to capture carbon for CO2 capture from flue gas. We intend to reduce carbon release and condense concentration of CO2 efficiently to promote capture and reuse of carbon. Then, we evaluate the possibility of this method according to the result of the resarch. Research results were divided into the following: The first part was found the best operating condition of granular 13X zeolite to capture carbon dioxide. We focus on the factors of the inlet like moisture content, CO2 concertration, temperature. The results showed that the best of adsorption capacity was obtained under 30 °C with 24lpm,15 % CO2 inlet. The working capacity (qw) reached 82.1 mg-CO2/g-13X. The second part desorbed CO2 from sorbents by using temperature programmed desorption process with low pressure condition or not. We operate the experiment under different desorption temperature, desorption time and five-cycles regeneration test to prove it. The results showed that 95% of CO2 was concentrated with Granular 13X under desorption conditions of 180°C in 10 minutes. In this desorption condition, the AI of 13X is 97.8, CO2 removel effferency is 99.1% and without the pressure swing process. Finally, DSI system is better way to capture CO2 in this research , compare with fixed bed and fluidized bed. These three method can capture 3.94、1.3、0.78 kgCO2 per day per kilogram 13X under the same conditions. The results indicate DSI system has feasibility on CO2 capture in a flue gas application.
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Book chapters on the topic "Post-combustion system"

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Fosbøl, Philip, Nicolas von Solms, Arne Gladis, Kaj Thomsen, and Georgios M. Kontogeorgis. "Methods and Modelling for Post-combustion CO2Capture." In Process Systems and Materials for CO2Capture, 43–78. Chichester, UK: John Wiley & Sons, Ltd, 2017. http://dx.doi.org/10.1002/9781119106418.ch2.

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Dinca, Cristian, Adrian Badea, Vladimir Tanasiev, and Horia Necula. "Life Cycle Assessment of Circulating Fluidized Bed Combustion with CO2 Post-Combustion Capture." In Progress in Systems Engineering, 113–20. Cham: Springer International Publishing, 2015. http://dx.doi.org/10.1007/978-3-319-08422-0_17.

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Neveux, Thibaut, Yann Le Moullec, and Éric Favre. "Post-combustion CO2Capture by Chemical Gas-Liquid Absorption." In Process Systems and Materials for CO2Capture, 283–310. Chichester, UK: John Wiley & Sons, Ltd, 2017. http://dx.doi.org/10.1002/9781119106418.ch11.

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Damartzis, Theodoros, Athanasios I. Papadopoulos, and Panos Seferlis. "Operability Analysis in Solvent-based Post-combustion CO2Capture Plants." In Process Systems and Materials for CO2Capture, 545–70. Chichester, UK: John Wiley & Sons, Ltd, 2017. http://dx.doi.org/10.1002/9781119106418.ch21.

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Kakaras, Emmanouil K., Antonios K. Koumanakos, and Aggelos F. Doukelis. "Optimized Lignite-fired Power Plants with Post-combustion CO2Capture." In Process Systems and Materials for CO2Capture, 629–47. Chichester, UK: John Wiley & Sons, Ltd, 2017. http://dx.doi.org/10.1002/9781119106418.ch25.

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Lawal, Adekola, Javier Rodriguez, Alfredo Ramos, Gerardo Sanchis, Mario Calado, Nouri Samsatli, Eni Oko, and Meihong Wang. "Improved Design and Operation of Post-combustion CO2Capture Processes with Process Modelling." In Process Systems and Materials for CO2Capture, 463–99. Chichester, UK: John Wiley & Sons, Ltd, 2017. http://dx.doi.org/10.1002/9781119106418.ch18.

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Liu, Helei, Raphael Idem, and Paitoon Tontiwachwuthikul. "Design, Modeling and Simulation of Post Combustion CO2 Capture Systems Using Reactive Solvents." In SpringerBriefs in Petroleum Geoscience & Engineering, 23–27. Cham: Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-030-00922-9_3.

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Nikolaidis, George N., Eustathios S. Kikkinides, and Michael C. Georgiadis. "Modelling and Optimization of Pressure Swing Adsorption (PSA) Processes for Post-combustion CO2Capture from Flue Gas." In Process Systems and Materials for CO2Capture, 343–69. Chichester, UK: John Wiley & Sons, Ltd, 2017. http://dx.doi.org/10.1002/9781119106418.ch13.

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Badr, Sara, Stavros Papadokonstantakis, Robert Bennett, Graeme Puxty, and Konrad Hungerbuehler. "Uncertainties in Modelling the Environmental Impact of Solvent Loss through Degradation for Amine Screening Purposes in Post-combustion CO2Capture." In Process Systems and Materials for CO2Capture, 153–72. Chichester, UK: John Wiley & Sons, Ltd, 2017. http://dx.doi.org/10.1002/9781119106418.ch6.

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Akula, Paul, John Eslick, Debangsu Bhattacharyya, and David C. Miller. "Modelling and Parameter Estimation of a Plate Heat Exchanger as Part of a Solvent-Based Post-Combustion CO2 Capture System." In Computer Aided Chemical Engineering, 47–52. Elsevier, 2019. http://dx.doi.org/10.1016/b978-0-12-818597-1.50008-4.

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Conference papers on the topic "Post-combustion system"

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Cohen, Stuart M., Michael E. Webber, and Gary T. Rochelle. "Utilizing Solar Thermal Energy for Post-Combustion CO2 Capture." In ASME 2010 4th International Conference on Energy Sustainability. ASMEDC, 2010. http://dx.doi.org/10.1115/es2010-90147.

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There is broad scientific agreement that anthropogenic greenhouse gases are contributing to global climate change and that carbon dioxide (CO2) is the primary contributor. Coal-based electricity generation produces over 30% of U.S. CO2 emissions; however, coal is also an available, secure, and low cost fuel that currently provides roughly half of U.S. electricity. As the world transitions from the existing fossil fuel-based energy infrastructure to a sustainable energy system, carbon dioxide capture and sequestration (CCS) will be a critical technology to allow continued use of coal-based electricity in an environmentally acceptable manner. Post-combustion amine absorption and stripping is one leading CO2 capture technology that is relatively mature, available for retrofit, and amenable to flexible operation. However, standard system designs have high capital costs and can reduce plant output by approximately 30% due to energy requirements for solvent regeneration (stripping) and CO2 compression. A typical design extracts steam from the power cycle to provide CO2 capture energy, reducing net power output by 11–40%. One way to reduce the CO2 capture energy penalty while developing renewable energy technologies is to provide some or all CO2 capture energy with a solar thermal energy system. Doing so would allow greater power plant output when electricity demand and prices are the highest. This study presents an initial review of solar thermal technologies for supplying energy for CO2 capture with a focus on high temperature solar thermal systems. Parabolic trough and central receiver (power tower) technology appear technically able to supply superheated steam for CO2 compression or saturated steam for solvent stripping, but steam requirements depend strongly on power plant and CO2 capture system design. Evacuated tube and compound parabolic collectors could feasibly supply heat for solvent stripping. A parabolic trough system supplying the energy for CO2 compression and solvent stripping at a gross 500 megawatt-electrical coal-fired power plant using 7 molal MEA-based CO2 capture would require a total aperture area on the order of 2 km2 or more if sized for an average direct normal solar insolation of 561 W/m2. The solar system’s capital costs would be roughly half that of the base coal-fired plant with CO2 capture. This analysis finds that irrespective of capital costs, relatively high electricity prices are required for additional electricity sales to offset the operating and maintenance costs of the solar thermal system, and desirable operational periods will be further limited by the availability of sunlight and thermal storage. At CO2 prices near 50 dollars per metric ton of CO2, bypassing CO2 capture yields similar operating economics as using solar energy for CO2 capture with lower capital cost. Even at high CO2 prices, any operating profit improvement from using solar energy for CO2 capture is unlikely to offset system capital costs. For high temperature solar systems such as power towers and parabolic troughs, direct electricity generation is likely a more efficient way to use solar energy to replace output lost to CO2 capture energy. However, low temperature solar systems might integrate more seamlessly with solvent stripping equipment, and more rigorous plant design analysis is required to definitively assess the technical and economic feasibility of using solar energy for CO2 capture.
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Manfredi Gasparovic, Claudia Luiza, Sandro Froehner, George Stanescu, and Marcelo Risso Errera. "CONSTRUCTAL DESIGN OF A MINERAL CARBONATION SYSTEM FOR POST-COMBUSTION CARBON CAPTURE." In 18th Brazilian Congress of Thermal Sciences and Engineering. ABCM, 2020. http://dx.doi.org/10.26678/abcm.encit2020.cit20-0468.

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Chen, Xianhao, Shiyu Shen, Chonghui Zhang, Peizhi Liao, and Xiao Wu. "Feed-forward decoupling control of solvent-based post-combustion CO2 capture system." In 2019 Chinese Automation Congress (CAC). IEEE, 2019. http://dx.doi.org/10.1109/cac48633.2019.8997279.

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Manfredi Gasparovic, Claudia Luiza, George Stanescu, and Marcelo Risso Errera. "FIRST-ORDER CONSTRUCT OF A MINERAL CARBONATION SYSTEM FOR POST-COMBUSTION CARBON CAPTURE." In 26th International Congress of Mechanical Engineering. ABCM, 2021. http://dx.doi.org/10.26678/abcm.cobem2021.cob2021-2004.

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Lu, Xijia, Scott Martin, Mike McGroddy, Mike Swanson, Josh Stanislowski, and Jason D. Laumb. "Testing of a Novel Post Combustion Acid Removal Process for the Direct-Fired, Oxy-Combustion Allam Cycle Power Generation System." In ASME Turbo Expo 2017: Turbomachinery Technical Conference and Exposition. American Society of Mechanical Engineers, 2017. http://dx.doi.org/10.1115/gt2017-65217.

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The Allam Cycle is a high performance oxy-fuel, supercritical CO2 power cycle that offers significant benefits over traditional fossil and hydrocarbon fuel-based power generation systems. A major benefit arises in the elimination of costly pre-combustion acid gas removal (AGR) for sulfur-(SOx) and nitrogen-based (NOx) impurities by utilizing a novel downstream cleanup process that utilizes NOx first as a gas phase catalyst to effect SOx oxidation, followed by NOx removal. The basic reactions required for this process, which have been well-demonstrated in several facilities for the cleanup of exhaust gasses, ultimately convert SOx and NOx species to sulfuric, nitric and nitrous acids for removal from the supercritical CO2 stream. The process results in simplified and significantly lower cost removal of these species and utilizes conditions inherent to the Allam Cycle that are ideally suited to facilitate this process. 8 Rivers Capital and the Energy & Environmental Research Center (EERC), supported by the state of North Dakota, the US Department of Energy (DOE) and an Industrial consortium from the State of North Dakota, are currently working together to test and optimize this novel impurity removal process for pressurized, semi-closed supercritical CO2 cycles, such as the Allam Cycle. Both reaction kinetic modeling and on-site testing have been completed. Initial results show that both SOx and NOx can be substantially removed from CO2-rich exhaust gas containing excess oxygen under 20 bar operating pressure utilizing a simple packed spray column. Sensitivity of the removal rate to the concentration of oxygen and NOx was investigated. Follow-on work will focus on system optimization to improve removal efficiency and removal control, to minimize metallurgy and corrosion risks from handling concentrated acids, and to reduce overall CAPX/OPEX of the system.
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Dai, Baoxin, Xiao Wu, Xiufan Liang, and Jiong Shen. "Model predictive control of post-combustion CO2 capture system for coal-fired power plants." In 2017 36th Chinese Control Conference (CCC). IEEE, 2017. http://dx.doi.org/10.23919/chicc.2017.8028841.

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Gülen, S. Can, and Chris Hall. "Gas Turbine Combined Cycle Optimized for Post-Combustion Carbon Capture." In ASME Turbo Expo 2017: Turbomachinery Technical Conference and Exposition. American Society of Mechanical Engineers, 2017. http://dx.doi.org/10.1115/gt2017-65261.

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This paper describes a gas turbine combined cycle (GTCC) power plant system, which addresses the three key design challenges of post-combustion CO2 capture from the stack gas of a GTCC power plant using aqueous amine-based scrubbing method by offering the following: (i) low heat recovery steam generator (HRSG) stack gas temperature, (ii) increased HRSG stack gas CO2 content and (iii) decreased HRSG stack gas O2 content. This is achieved by combining two bottoming cycle modifications in an inventive manner, i.e., (i) high supplementary (duct) firing in the HRSG and (ii) recirculation of the HRSG stack gas. It is shown that, compared to an existing natural gas-fired GTCC power plant with post-combustion capture, it is possible to reduce the CO2 capture penalty — power diverted away from generation — by almost 65 percent and the overall capital cost ($/kW) by about 35 percent.
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Ahn, Ji Ho, Ji Hun Jeong, and Tong Seop Kim. "Performance Enhancement of a Molten Carbonate Fuel Cell/Micro Gas Turbine Hybrid System With Carbon Capture by Off-Gas Recirculation." In ASME Turbo Expo 2018: Turbomachinery Technical Conference and Exposition. American Society of Mechanical Engineers, 2018. http://dx.doi.org/10.1115/gt2018-76014.

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The demand for clean energy continues to increase as the human society becomes more aware of environmental challenges such as global warming. Various power systems based on high-temperature fuel cells have been proposed, especially hybrid systems combining a fuel cell with a gas turbine, and research on carbon capture and storage technology to prevent the emission of greenhouse gases is already underway. This study suggests a new method to innovatively enhance the efficiency of a molten carbonate fuel cell/micro gas turbine hybrid system including carbon capture. The key technology adopted to improve the net cycle efficiency is off-gas recirculation. The hybrid system incorporating oxy-combustion capture was devised, and its performance was compared with that of a post-combustion system based on a hybrid system. A molten carbonate fuel cell system based on a commercial unit was modeled. Externally supplied water for reforming was not needed as a result of the presence of the water vapor in the recirculated anode off-gas. The analyses confirmed that the thermal efficiencies of all the systems (MCFC stand-alone, hybrid, hybrid with oxy-combustion capture, hybrid with post-combustion capture) were significantly improved by introducing the off-gas recirculation. In particular, the largest efficiency improvement was observed for the oxy-combustion hybrid system. Its efficiency is over 57% and is even higher than that of the post-combustion hybrid system.
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Montañé, Rubén, and Lars Olof Nord. "Dynamic Simulations of the Post-combustion CO2 Capture System of a Combined Cycle Power Plant." In The 12th International Modelica Conference, Prague, Czech Republic, May 15-17, 2017. Linköping University Electronic Press, 2017. http://dx.doi.org/10.3384/ecp17132111.

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Chen, Qin, Ashok Rao, and Scott Samuelsen. "Solid Sorbent Post-Combustion CO2 Capture in Subcritical PC Power Plant." In ASME 2015 9th International Conference on Energy Sustainability collocated with the ASME 2015 Power Conference, 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/es2015-49483.

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Existing coal fired power plants are expected to continue providing a significant portion of power generation and a majority of these are subcritical pulverized coal (PC) units which have higher CO2 emissions on a MWe basis due to their higher heat rates, while CO2 emissions are an increasing concern due to global pressure on limiting greenhouse gas accumulation in the atmosphere. Current state-of-the-art CO2 capture technology uses an aqueous amine solution to chemically absorb the CO2 from the flue gas and thus requires a large amount of energy for solvent regeneration. Novel solid sorbent based CO2 capture technologies are under development to capture the CO2 via physical adsorption and desorption, thereby consuming far less energy for the sorbent regeneration process. This present work is focused on retrofitting a subcritical PC power plant with solid sorbent post combustion CO2 capture technology. Thermal performance and costs are compared with an amine based CO2 capture plant as well as the plant with no CO2 capture. The design of the solid sorbent based CO2 capture system is optimized for integration to minimize plant modifications and the associated downtime. In an existing PC plant with a net power efficiency of 36.57%, use of the amine based capture reduces the net efficiency to 26.01% while with the solid sorbent based capture, the reduction in net efficiency is far less at 28.67% when 90% of the CO2 is captured. As a consequence, the increase in plant cooling duty is significantly lower for the solid sorbent CO2 capture case, with the water usage on a per MW basis being almost 17% lower than the amine based PC plant. The calculated levelized cost of electricity is increased from $60.5/MWh without CO2 capture to $124.3/MWh for amine based capture while that with the solid sorbent based capture is much lower at $115.8/MWh.
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Reports on the topic "Post-combustion system"

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Brown, Alfred, and Nathan Brown. Novel Solvent System for Post Combustion CO{sub 2} Capture. Office of Scientific and Technical Information (OSTI), September 2013. http://dx.doi.org/10.2172/1155036.

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Balepin, Vladimir. Supersonic Post-Combustion Inertial CO2 Extraction System Final Report. Office of Scientific and Technical Information (OSTI), April 2017. http://dx.doi.org/10.2172/1394653.

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Liu, Kunlei, Heather Nikolic, Jesse Thompson, Reynolds Frimpong, Lisa Richburg, Keemia Abad, Saloni Bhatnagar, et al. Application of a Heat Integrated Post-combustion CO2 Capture System with Hitachi Advanced Solvent into Existing Coal-Fired Power Plant. Office of Scientific and Technical Information (OSTI), June 2020. http://dx.doi.org/10.2172/1635102.

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Dillon, Des, Robert Chu, Haoren Lu, Brice Freeman, William Elliot, and Raymond McKaskle. Initial Engineering Design of a Post-Combustion CO2 Capture (PCC) System for Duke Energy’s East Bend Station Using Membrane-Based Technology. Office of Scientific and Technical Information (OSTI), October 2020. http://dx.doi.org/10.2172/1686164.

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