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Corrosion mitigation is an important aspect of amine-based post-combustion carbon dioxide (CO2) capture operations due to the desire to use less expensive but corrosion-vulnerable materials such as low carbon steels in the construction of a capture system. In this study, the corrosion behavior of A106 (grade B) carbon steel with an in-house proprietary amine-based solvent was investigated in a laboratory environment at 80°C using an organic corrosion inhibitor, 2-mercaptobenzothiazole (MBT). The corrosion inhibition mechanism was interpreted by electrochemical methods and surface analyses. The results revealed that the corrosion rates of carbon steel were significantly retarded using MBT. The critical inhibitor concentration was determined to be lie between 10 ppm and 50 ppm under the tested conditions.

Στην παρούσα διατριβή προτείνεται ένα γενικευμένο πλαίσιο για το βέλτιστο σχεδιασμό διεργασιών δέσμευσης CO2 καύσης που βασίζεται σε ένα ευέλικτο μοντέλο ισορροπίας σε συνδυασμό με την τεχνική της ορθογώνιας ταξιθεσίας σε πεπερασμένα στοιχεία. Δομικές μονάδες όπως το τμήμα της στήλης διαχωρισμού, μονάδες μεταφοράς θερμότητας καθώς και διαχωριστές και αναμίκτες ρευμάτων επιτρέπουν τη δημιουργία και αξιολόγηση εναλλακτικών διαγραμμάτων ροής μέσα σε ένα μη-γραμμικό πρόγραμμα βελτιστοποίησης. Το προτεινόμενο πλαίσιο σχεδιασμού χρησιμοποιήθηκε για το βέλτιστο σχεδιασμό ενός αριθμού εναλλακτικών διαγραμμάτων ροής για τον διαχωρισμό του CO2 από ένα ρεύμα απαερίων. Αυτά τα διαγράμματα ροής απεικονίζουν τις διάφορες μορφές σύνδεσης μεταξύ των μονάδων επεξεργασίας και υποδεικνύουν κατάλληλη κατανομή των κινητήριων δυνάμεων με στόχο την ενίσχυση της απόδοσης της διεργασίας. Προσδιορίστηκαν οι αλληλεπιδράσεις μεταξύ των εναλλακτικών διαλυτών και διαγραμμάτων ροής και η απόδοση του κάθε υποψηφίου ζεύγους διαλύτη / διαγράμματος ροής αξιολογήθηκε με χρήση ποιοτικών και ποσοτικών δεικτών. Θεωρήθηκε ακόμα η ενεργειακή ολοκλήρωση μεταξύ των διαφόρων διεργασιών μέσα στη μονάδα δέσμευσης CO2, καθώς και μεταξύ της μονάδας δέσμευσης και της παρακείμενης μονάδας παραγωγής CO2. Επιπλέον, προτείνεται ένα ολοκληρωμένο πλαίσιο βέλτιστου σχεδιασμού και λειτουργικότητας. Μέσα σε αυτό πραγματοποιήθηκε η ταυτόχρονη αξιολόγηση και ιεράρχηση διάφορων συνδυασμών διαλυτών, διαγραμμάτων ροής και δομών ελέγχου. Η εξερεύνηση των χαρακτηριστικών σε μόνιμη κατάσταση και των δυναμικών αποκρίσεων σε εξωγενείς διαταραχές για μια δεδομένη δομή ελέγχου έγινε με τη χρήση μεθόδου αντιστάθμισης διαταραχών. Οι διαφορετικές εγγενείς ιδιότητες των συστημάτων, όπως η δομή του επιλεγμένης διαγράμματος ροής και η φύση του διαλύτη αποτελούν πρόσθετα χαρακτηριστικά σχεδιασμού που διαφοροποιούν την απόκριση της διεργασίας. Η ανάλυση ευαισθησίας παράγει χρήσιμες πληροφορίες σχετικά με την επιλογή της δομής ελέγχου και το εύρος των διακυμάνσεων των παραμέτρων εντός των οποίων οι υποψήφιες διεργασίες επιδεικνύουν τη βέλτιστη απόδοση. Επιπλέον, επιτρέπει την τροποποίηση των σχεδιαστικών χαρακτηριστικών της διεργασίας, προκειμένου να ενισχυθεί η λειτουργικότητα της. Ακόμα, καθίσταται δυνατή η αξιολόγηση της δυναμικής συμπεριφοράς των συστημάτων μέσω της χαρτογράφησης των δυναμικών χαρακτηριστικών ανοικτού βρόχου και του προσδιορισμού των περιοχών που σχετίζονται με αστάθεια, ταλαντωτική συμπεριφορά ή αργή απόκριση.

Converter steelmaking is the main stage in ore-based production using blast furnace hot metal and steel scrap as charge materials. Over 70% of steel is produced via basic oxygen converters today. The converter process was developed in the middle of nineteenth century by blowing air through pig iron melt for decarburisation. The subsequent innovation was basic lining and the Thomas process. The next problem, the switch from air to oxygen was hard and did not succeed on an industrial scale until the 1950s when oxygen blowing via top lance was developed. Oxygen bottom blowing was then solved by applying annular nozzles with hydrocarbon cooling. Current technologies combine benefits of top and bottom blowing in hybrid processes. In this review, the history of converter processes is briefly surveyed. Recent progress and challenges, e.g. better utilisation of post combustion for scrap melting, are discussed. Continuous converting and the future role of converter process are also highlighted.

This front-end engineering and design (FEED) study is for a carbon dioxide (CO2) capture system for Unit #2 (816 MW) at the Prairie State Generating Company’s (PSGC) Energy Campus in Marissa, IL. The capture technology used is the Advanced KM CDR Process™ from Mitsubishi Heavy Industries (MHI). The project will be the largest post-combustion capture plant in the world. In addition, it will incorporate advancements in the technology including lessons learned from past projects and a new proprietary solvent. The overall business model being developed by PSGC focuses on the generation of 45Q tax credits as a result of sequestering the captured CO2. Because the Prairie Research Institute (PRI) within the University of Illinois at Urbana-Champaign (UIUC) leads both this capture effort and the storage effort, there is close coordination and integration between the capture and storage efforts. This integration is vital to achieving the desired business targets for the project.

The implementation of carbon capture, use, and storage in the cement industry is a necessity, not an option, if the climate targets are to be met. Although no capture technology has reached commercial scale demonstration in the cement sector yet, much progress has been made in the last decade. This work intends to provide a general overview of the CO2 capture technologies that have been evaluated so far in the cement industry at the pilot scale, and also about the current plans for future commercial demonstration., S.M. acknowledges the award of an Introduction to Research fellowship (grant number: JAEICU-19-INCAR-26) from the JAE Intro ICUs Programme of the Agencia Estatal Consejo Superior de Investigaciones Científicas (CSIC). M.G.P. acknowledges support from the Ramon y Cajal Programme (grant number: RyC-2015-17516) of the Government of Spain, co-financed by the European Social Fund. Financial support from the Government of the Principado de Asturias (PCTI, grant number: IDI/2018/000115), co-financed by the European Regional Development Fund (ERDF), is also acknowledged.

It is typical to assume that the capture system operates at the full working load of the power plant. This study aims to develop systematic design framework which can provide a cost-effective strategy for operating CO 2 capture plant under different operating load. The part-load performance of CO 2 capture process together with power plant is modeled and evaluated with a process simulator UniSim ® . This study considers both natural gas-fired combined cycle (NGCC) and coal-fired plants, in which optimization is carried out for finding an economic operating strategy to minimize regeneration energy without compromising process efficiency of the capture system. The multi-period modeling approach is applied to accommodate discontinuous nature of part-load performance, with which techno-economic impacts of part-load operation is investigated in a holistic manner. The case study is presented to demonstrate the usefulness of proposed design and optimization framework and to provide practical guidelines and conceptual insights for part-load operation in practice. From the case study, the specific reboiler duty is reduced through the superstructure optimization at full-load operation, which is about 3% lower than one without structural modifications. Also, the operational optimization for part-load achieves energy savings by 2–3% in NGCC and 3–5% in coal-fired power plant.

Membrane technology is a promising strategy in flue gas CO2 capture. Recently, many high-performance multilayer composite membranes for CO2/N2 separation were successfully developed in the laboratory. However, the detailed scaling-up processes were rarely discussed due to the lack of mature technology and equipment that specially designed for the proven advanced membrane materials. This study investigated the large-scale production of the defect-free thin multilayer composite membrane for flue gas CO2 capture. A novel coating machine with double blades and surface cross-linking unit was designed, and the industrial scale multilayer composite membranes were prepared by running the coating machine twice. The coating solution stability of intermediate layer solution was prolonged to more than 72 h. The key technologic parameters including web speed and the concentration of cross-linking unit were analyzed. The continuously prepared multilayer composite membrane shows high and stable CO2/N2 performance and great potential in the application of flue gas CO2 capture.

The energy consumption associated with absorbent regeneration remains the most critical challenge for the industrial implementation of chemisorption based CO 2 capture processes. Aimed at reducing the energy consumption, this paper proposes a promising process modification of the ammonia (NH 3 ) based CO 2 capture process that involves an advanced flash stripper with a cold rich split. We investigated the techno-economic performance of the advanced NH 3 process integrated with a 650 MW coal-fired power plant, and evaluated it technical and energy performance using a rigorous, rate-based model in Aspen Plus. A sensitivity study was also performed to optimise the modelling parameters, i.e. the stripper pressure and the absorbent NH 3 concentration, and minimize the regeneration duty. A very competitive regeneration duty of 1.86 MJ/kg CO 2 was achieved for an optimised stripper pressure of 12 bar and an NH 3 concentration of 10.2 wt%, with a total equivalent work of 0.164 MW h/t CO 2 for absorbent pumping, NH 3 regeneration and CO 2 compression. We also used a validated economic model to estimate the capital investment of the advanced NH 3 process and its corresponding economic performance. With its significant reduction in energy consumption, the proposed process was economically competitive with CO 2 avoided cost was as low as US$40.7/t CO 2 . This was 34% and 44% less than the reference NH 3 and monoethanolamine (MEA) processes, respectively. The advanced NH 3 based flash stripper also had technical and economic advantages over other amine absorbents, such as MEA and piperazine (PZ), as well as other advanced stripper modifications, such as inter-heating process, revealing its process viability in commercial application.

This paper provides a short review of the multitude of processes proposed for solvent-based and sorbent-based post-combustion CO 2 capture. (Membrane-based systems, another important technology for CO 2 capture is outside the scope of this review.) The majority of process configurations discussed in the open literature focus on reducing the energy penalty with little consideration of capital cost or operability — key factors for industrial implementation. This paper highlights advances in all three areas and identifies opportunities for future research.

Gas-fired industrial furnaces are used for heat-treatment of semi-finished steel products. The required energy is provided by gas-fired burners, which are supplied by fuel and air. The combustion is often realized fuel rich to avoid scale formation at the product surface. Thus, the flue gas contains unburnt products, which are oxidized in a post combustion chamber by adding fresh air. The control of the volume flow of air to the post combustion chamber is a crucial task because the flue gas leaving the furnace must not contain unburnt products. For this control task, a two-degrees-of-freedom control strategy based on differential flatness in combination with a MIMO-PI controller is proposed. The basis for the control design is a first-principles mathematical model of the air supply circuit and the combustion of flammable products. The model is validated by means of measurement data from a real plant.

Intensified stripper used in chemical absorption process based on rotating packed bed (RPB) technology was studied through modelling and simulation in this paper. The model was developed by dynamically linking Aspen Plus ® rate-based model with visual Fortran. Suitable correlations for RPB were implemented in Fortran to replace the default correlations in Aspen Plus ® rate-based model. The standalone stripper model was validated with experimental data. The paper compared standalone intensified stripper with conventional stripper using MEA solvent. The result shows 9.69 times size reduction. Therefore PI has great potential for use in carbon capture application.

IHI, with technical support from CSIRO, designed and constructed the “PICA pilot plant”, for the continued development of an advanced PCC process, which will enable a reduction in the CO2 capture absorbent regeneration energy by 40% compared to the conventional MEA based process. The project team installed the pilot plant at the AGL Loy Yang power plant in Australia. The pilot plant has been commissioned and tested in a conventional MEA based process configuration and has commenced a 5,000 hour operating campaign using the IHI absorbent and the IHI optimized process configuration, and had achieved 1,800 hours of operationby mid September, 2016. The designed CO2 capture ratio of 90% has been achieved and stable plant operation has been confirmed. Continuous analysis will be kept for confirming the performance and robustness of the system.

This short overview briefly summarizes the prominent evolutions and scientific breakthroughs in the development of end-of-pipe technologies with respect to the standard regulations of atmospheric pollutant emissions from automotive exhaust. Up to now, several strategies have been implemented to fulfill more and more stringent emission limits and to overcome the extensive use of critical materials. This led to the elaboration of cheaper and more compact systems with close-coupled technologies suitable for light duty vehicles and also to preserve the competitiveness of car manufacturers. But all these improvements could not be sufficient to face short-term, more severe limitations as well as more realistic test driving cycles since the actual ones usually underestimate the emissions of current atmospheric pollutants especially from diesel powered engines. Presently, several scenarios have been envisioned which account for the partial replacement of liquid fossil fuels by alternative fuels for urban travel and the emergence of hybrid engines powered by natural gas or bio-fuels accompanied by more simple and efficient end-of-pipe systems. In this short overview, particular attention was paid to the past and present academic contributions which led and/or inspired important technical and commercial applications.

The performance of a mono-ethanolamine-based post-combustion CO2 capture plant was assessed experimentally using a dedicated pilot plant located at a coal-fired power station in China. The 1000-h pilot campaign enabled the assessment of the flue gas pre-treatment process, the conduct of a parametric study for optimization of the thermal energy requirement, determination of degradation products in the absorption liquid, and measurement of main process emissions. These results are compared with results in reports on other pilot plant operations based on mono-ethanolamine. © 2016 Society of Chemical Industry and John Wiley & Sons, Ltd.

This paper presented a comparative study of monoethanolamine (MEA) and diethanolamine (DEA) for post-combustion CO2 capture (PCC) process with different process configurations to study the interaction effect between solvent and process. The steady state process model of the conventional MEA-based PCC process was developed in Pro/II® and was validated with the experimental data. Then ten different process configurations were simulated for both MEA and DEA. Their performances in energy consumption were compared in terms of reboiler duty and total equivalent work. The results show that DEA generally has better thermal performances than MEA for all these ten process configurations. Seven process configurations provide 0.38%–4.61% total energy saving compared with the conventional PCC process for MEA, and other two configurations are not favourable. For DEA, except one configuration, other process configurations have 0.27%–4.50% total energy saving. This work also analyzed the sensitivities of three key parameters (amine concentration, stripper pressure and lean solvent loading) in conventional process and five process modifications to show optimization strategy.

In this paper, optimization of a post combustion carbon capture process based on two different objective functions of energy and utility requirements and associated costs is presented. CO2 residual mole fraction of the regenerated solution, solution circulation rates and lean solution temperature were selected as three most important variables of the process for optimization. One at a time method is adopted for optimization of the process variables. The results show that for a post combustion carbon capture process using monoethanolamine (MEA), lowest costs of the process are associated with the highest CO2 residual mole fraction of regenerated solution, lowest solution circulation rate and highest lean solution temperature. Based on the results of this research, having a general view of energy and utility requirements of the process leads to finding the lowest possible process costs. However, if a component oriented view is adopted for energy requirements, the worst possible choices of operational parameters are likely to be made.

A detailed optimization-orientated model of monoethanolamine-based CO 2 capture plant and compression train in which all the technical and economic assumptions are defined and/or optimized was developed and used to simultaneously determine the cost optimal control and design variables including feed fraction ratio at different degrees of capture (DOC), which represents the amount of CO 2 removed, for plant designs that partially bypass the CO 2 capture process so as to achieve low to moderate reductions of CO 2 , but at lower overall cost. The effects of varying carbon prices on the levelized cost of CO 2 capture and compression were also studied. The capture bypass option was observed to be the cost optimal choice for lower than 60% overall DOC. Carbon prices were observed to have a clear impact on the cost optimal DOC, with the cost-optimal DOC shifting from 70%⿿80% to 85%⿿90% at carbon prices of $4/t CO 2 to $23/t CO 2 respectively. The study highlighted that if a suitably high carbon price does not materialize through a market mechanism, appropriate policies need to be put in place to achieve decarbonisation targets.

Ca-Looping technology has experienced a substantial development in the technical readiness level in the last years, especially in its application as post-combustion CO 2 capture technology in power plants. Experimental results from MW-scale power plants worldwide have confirmed post-combustion Ca-Looping process using interconnected circulating fluidised bed reactors as a promising technology for CO 2 capture. Among the different fields of research having contributed to this breakthrough, modelling activity aiming at assessing sorbent properties, interpreting results from experimental reactors or assessing technology scale-up through large-scale reactors and process integration have played a crucial role. This paper aims at reviewing and discussing findings obtained by different research groups worldwide about post-combustion Ca-Looping process modelling. Assumptions made with respect to sorbent performance, reactor operating conditions and process integration between different components are crucial when evaluating the performance of the Ca-Looping process as a post-combustion technology for CO 2 capture. With the aim of understanding the importance of these assumptions, this paper covers particle reaction and reactor models for carbonation and calcination steps, assessing the impact of the conditions used for their determination into their reactivity predictions, as well as process modelling works that assess performance obtained when integrating a Ca-Looping process into a power plant. Indications on the research needs detected among the reviewed works have also been highlighted in this work to contribute to the advancement of the knowledge on the Ca-Looping technology.

The more and more restrictive environment requirements in the field of pollutant emissions of co-generative plants are imposing researches related to the more efficient work of those related to the post combustion facility. The paper presents the results of a post combustion burner achieved on a test bench, when it idling operates on natural gas mixed with air or with burned gases of a gas turbine. The modeling of the measured emissions, led to NOx concentrations in ambient air that are below the limits imposed by the in force regulations related to air quality and are correlated to the real time measured data.

The market of solar-assisted post-combustion CO2 capture (SPCC) is emerging globally in recent years. It is considered as a promising technology to apply the ammonia as the absorbent to implement the SPCC technology in view of its low regeneration temperature and low regeneration heat duty. However, few literatures indicate which type of solar thermal collectors (STCs) involved in the ammonia-based SPCC power plant is more applicable. Therefore, in this paper, the maximum theoretical potential price of STCs which make the value of the levelized costs of electricity (LCOE) and the cost of CO2 removed (COR) lower than that of the reference post-combustion CO2 capture (PCC) power plant is estimated. The potential of ammonia-based SPCC technology in the selected locations is also estimated, based on the detailed solar radiation resource assessment (i.e. DNI, sunshine time) and the STCs performance. It would be more attractive to adopt the vacuum tube (VT) as the STC involved into the ammonia-based PCC power plant to capture CO2 than parabolic trough collector (PTC). In order to achieve lower LCOE and COR than that of the reference PCC system, the price of the vacuum tube (VT) has to be reduced to 131.02 $/m2, 91.76 $/m2 and 57.10 $/m2 for the location of M1(Lhasa), M2(Tianjin) and M3(Xi’an), respectively. And the price of the parabolic trough collector (PTC) has to be reduced to 139.09 $/m2, 89.83 $/m2 and 50.84 $/m2, respectively.

Among the current technologies for post-combustion CO2 capture, amine-based chemical absorption appears to be the most technologically mature and commercially viable method. This review highlights the opportunities and challenges in post-combustion CO2 capture using amine-based chemical absorption technologies. In addition, this review provides current types and emerging trends for chemical solvents. The issues and performance of amine solvents are reviewed and addressed in terms of thermodynamics, kinetics, mass transfer, regeneration and solvent management. This review also looks at emerging and future trends in post-combustion CO2 capture using chemical solvents in the near to mid-term.

The ultimate benefit of flexible operation of the post-combustion CO 2 capture (PCC) plant depends on the ability to optimally balance between many competing factors, including the additional capital investment and operating cost savings. In this work, a large number of scenarios are constructed by considering combinations of possible realizations of the uncertain economic factors such as energy cost profile, emission penalty and value of captured CO 2 . Then, the design choices like the size of the storage tanks and the regeneration capacity are optimized by minimizing an overall cost averaged over all the scenarios. The optimal design problem is naturally formulated as a two-stage stochastic program. This multi-scenario optimal design is compared with the design that minimizes the overall cost for just a single nominal scenario as well as the design that minimizes the cost averaged over the worst-case scenarios.

Post-combustion capture of CO 2 from the flue gas of power plants by calcium looping, in which lime is used to capture CO 2 , is currently a promising technology. The decay in CO 2 uptake capacity of natural limestone is an intrinsic disadvantage of this technology, and the design of more stable sorbents has become an important goal. Techno-economic calculations that examine calcium looping must take into account this decay in capacity, and this has to date been accomplished using a formula for the population distribution of particles in the cycling system. However, the formula has some limitations that make it less suited to very stable sorbents, making it difficult to incorporate newer materials in such calculations. We developed a more general formula for the population distribution of solid particles in processes involving recirculations, and compared it with the widely used equation in the calculation of several process metrics. Particular consideration was given to conditions relevant to enhanced or tailored sorbents, for which our modified formula was well suited. In addition, the impacts of calcium looping process configuration on this generalized population distribution of solid particles were studied from mathematical and operational perspectives.

Summary Masdar has initiated the Abu Dhabi Carbon-Capture and -Storage Project, with the objective to develop a carbon-capture network in Abu Dhabi capable of creating large reductions of carbon dioxide (CO2) emissions and with the capacity to increase oil recovery by use of CO2 for enhanced oil recovery (EOR). Because Siemens (henceforth referred to as the Technology Owner) has developed, tested, and piloted a proprietary post-combustion CO2-capture technology (PostCapTM) for the removal of CO2 from the flue gas of coal- and gas-fired power plants suitable for the project, both parties decided to cooperate in executing a front-end engineering and design (FEED) study. The technology is based on an aqueous amino-acid-salt solution. The Technology Owner and Masdar have completed a FEED study for capturing 1,800,000 tons of CO2 annually from a natural-gas-fired power plant in Abu Dhabi by application of the PostCapTM technology. Various opportunities and challenges were encountered during the design of the retrofit capture plant. Challenges were often specific to the region, including local climate, water availability, and flue-gas quality. Design and optimization of the plant were influenced by local energy and labor prices. Further opportunities included integration with the power plant and with a local industrial facility. The power plant had to supply the capture plant with steam and power without reducing the original electricity-production capacity. To accomplish this, several heat- and power-integration concepts were evaluated with respect to their feasibility, including the application of a backpressure steam turbine and the retrofit of a simple-cycle gas turbine to combined-cycle gas turbine. Various cooling options were considered in view of climate and resource challenges. Cooling water had to be extracted from a reflux stream produced by an adjacent industrial facility. Drawing on the results of the FEED study, this paper presents the manner in which PostCapTM technology can be applied for capturing CO2 at a power plant in Abu Dhabi for the purpose of EOR, while satisfying specific local needs, and the way utility supply and power plant integration can be facilitated.

Currently, post-combustion carbon capture (PCC) is the only industrial CO2 capture technology that is already demonstrated at full commercial scale in the TMC Mongstad in Norway (300,000 tonnes per year CO2 captured) and BD3 SaskPower in Canada (1 million tonnes per year CO2 captured). This paper presents a comprehensive review of the most recent information available on all aspects of the PCC processes. It provides designers and operators of amine solvent-based CO2 capture plants with an in-depth understanding of the most up-to-date fundamental chemistry and physics of the CO2 absorption technologies using amine-based reactive solvents. Topics covered include chemical analysis, reaction kinetics, CO2 solubility, and innovative configurations of absorption and stripping columns as well as information on technology applications. The paper also covers in detail the post build operational issues of corrosion prevention and control, solvent management, solvent stability, solvent recycling and reclaiming, intelligent monitoring and plant control including process automation. In addition, the review discusses the most up-to-date insights related to the theoretical basis of plant operation in terms of thermodynamics, transport phenomena, chemical reaction kinetics/engineering, interfacial phenomena, and materials. The insights will assist engineers, scientists, and decision makers working in academia, industry and government, to gain a better appreciation of the post combustion carbon capture technology.

As a part of the strategic research program “Advanced technologies for energy generation: Development of a technology for highly efficient zero-emission coal-fired power units integrated with CO2 capture”, a mobile CO2 absorption pilot plant was erected. The main purpose of the pilot plant was to demonstrate the post-combustion technology in conjunction with a coal-fired power plant. The pilot plant captured CO2 by chemical absorption in amine-based solvents, which was considered to be the best adapted technology to the requirements of coal-fired power plants and suitable for retrofitting to existing units. The pilot plant captured up to 1000 kg/day of CO2 from the power plant’s flue gases with CO2 recovery exceeding 90 %. The flexible process flowsheet of the pilot plant offered high potential for the validation of various improvements, which were designed to reduce the process energy demand and to increase the CO2 recovery. This paper summarizes the initial operation experience at the TAURON Łaziska Power Plant in Poland. Selected first results obtained are presented and discussed. The initial campaigns utilized 20 and 30 wt% monoethanolamine (MEA) solutions recognized as baseline solvents that were suitable for comparative purposes. The initial campaigns at the pilot plant successfully demonstrated reliable operation and promising results.

One option to mitigate the adverse effect of power plant output loss from adding a CO 2 capture plant is to operate it in flexible modes in which the capture level and/or regeneration rate are dynamically varied in response to varying electricity market demand and price. This can help the plant meet peak electricity demand and improve its overall profit. However, the benefit is offset by higher capital costs and/or CO 2 emission penalty. Various modes of flexible operation including capture level reduction and solvent storage have been optimized for a given post-combustion capture system with typical daily electrical energy price patterns and the results are compared with those from a fixed point operation. Effects of varying storage capacities and energy price patterns have also been evaluated. Simultaneous use of the two flexible modes is also optimized and the result showed significantly higher cost savings compared to the individual uses.

The overall performance of the post-combustion chamber of steelmaking plants is controlled by the size of the gap that allows for the ambient air to merge with the hot gas stream exiting the fourth hole of an electric arc furnace. The impact of the opening coefficient (ratio between the gap area and the total area) on the post-combustion chamber performance has been investigated by a comprehensive 3D, steady, CFD simulation comprising radiative heat exchanges and detailed chemical reactions. It is found that no unique value of the opening coefficient is capable of optimizing all the relevant quantities of the evacuation process of exhaust fumes. A value of the opening coefficient comprised in the range 0.40–0.52 appears advisable in the investigated model geometry. It is shown that the accurate knowledge of some boundary conditions at the gap does not grossly modify the above serviceable range. Inefficiencies of the sample post-combustion chamber are highlighted and fan power savings are advised.

Post-combustion CO 2 emissions caused by fossil fuel utilization have become a worldwide issue. To understand the macro-level status of research findings and impacts on post-combustion CO 2 capture, a publication-based survey since 2000 was performed using Web of Science™ Core Collection and Journal Citation Reports ® 2014. The number of articles published, citations and important publications were examined to assess the quantity and quality of scientific findings on post-combustion CO 2 capture. Results show that a total of 1025 articles were published during 2000–2013. A remarkable increase in publication numbers was found in 2011 and has remained high in the last three years. The United States and China are the top-two contributors of articles, far surpassing those of all other countries, with an approximate combined of 40% from these two countries. Post-combustion CO 2 capture approaches using absorption, adsorption and membrane techniques were dominant. Times Cited of articles regarding post-combustion CO 2 capture reached to peak in 2010 while the number of citing articles is continuously increasing. The most popular, most-cited and highest impact factor journals were found as International Journal of Greenhouse Gas Control , Industrial and Engineering Chemistry Research and Science , respectively.

The objective of the ACACIA project was to develop processes for post-combustion CO2 capture at a lower cost and with a higher energetic efficiency than first generation processes using amines such as MonoEthanolAmine (MEA) which are now considered for the first Carbon Capture and Storage (CCS) demonstrators. The partners involved in this project were: Rhodia (Solvay since then), Arkema, Lafarge, GDF SUEZ, Veolia Environnement, IFP Energies nouvelles, IRCE Lyon, LMOPS, LTIM, LSA Armines . To validate the relevance of the breakthrough processes studied in this project, techno-economic evaluations were carried out with comparison to the reference process using a 30 wt% MEA solvent. These evaluation studies involved all the industrial partners of the project, each partner bringing specific cases of CO2 capture on their industrial facilities. From these studies, only the process using demixing solvent, DMXTM , developed by IFPEN appears as an alternative solution to the MEA process.

CO 2 Capture and Storage (CCS) is a way to limit the impact of the power plants on the environment. Using the numerical modeling, the paper analyzes the impact of the post-combustion CCS on the coal-fired Thermal Power Plants (TPP) internal consumptions. The steam turbine power is decreased by the steam flow rate requested by the CO 2 capture process. The power consumed by the cooling pumps decreases. The CO 2 compressor unit requests about 9.4 % from the power at the generator clamps (P gc ). The P gc decreases with 15.3 % and the net power decreases with 24.4 % if the CCS is used. The net efficiency of the TPP is reduced by 9.8 percentage points if the CCS is used. The paper compares the internal consumptions of the TPP with and without CCS.

The calcium looping (CaL) process is a post combustion CO 2 capture technology which is currently under development, offering power plants a low cost and energy efficient solution for carbon capture. At IFK, University of Stuttgart, a 200 kW th CaL dual fluidized bed (DFB) pilot plant has been built consisting of two circulating fluidized bed (CFB) reactors. This study presents detailed results of tests conducted on a hydrodynamically scaled cold model of the 200 kW th CaL DFB facility. The preliminary aim of the cold model studies was to check the workability of the major novelty of this facility which is the implementation of two cone valves to control the solid looping rate between the two CFBs. Furthermore, initial cold model tests, based on the relative CaL process boundary conditions, determined the suitability of the 200 kW th CaL DFB system and further tests suggested design improvements for the pilot plant. The novel geometric configurations in a CFB such as a wide bottom CFB reactor and a loop seal with increased weir depth were tested and found to be a useful application for the pilot plant operation. All important process parameters of the cold model DFB system, namely total solid inventory (TSI), riser superficial velocity, air staging ratio, and cone valve opening, were varied in order to fully characterize the DFB operation. The study shows that the proposed solid looping mechanism works satisfactorily and the required operational boundary conditions can be met in the pilot plant with suggested design improvements.

The drive for efficiency improvements in post-combustion CO2 capture (PCC) technologies continues to grow, with recent attention being directed towards flexible operation of PCC plants. However, there is a lack of research into the effect of process disturbances when operating flexibly, justifying a need for validated dynamic models of the PCC process. This review critically examines the dynamic PCC process models developed to date and analyses the different approaches used, as well as the model complexity and their limitations. Dynamic process models coupled with economic analysis will play a crucial role in process control and optimisation. Also discussed are key areas that need to be addressed in future dynamic models, including the lack of reliable dynamic experimental data for their validation, development of feasible flexible operation and process control strategies, as well as process optimisation by integrating accurate process models with established economic analysis tools.

Partnering in Innovation, Inc. (Pi-Innovation) introduces an aqueous post-combustion carbon dioxide (CO2) capture system (Pi- CO2) that offers high market value by directly addressing the primary constraints limiting beneficial re-use markets (lowering parasitic energy costs, reducing delivered cost of capture, eliminating the need for special solvents, etc.). A highly experienced team has completed initial design, modeling, manufacturing verification, and financial analysis for commercial market entry. Coupled thermodynamic and thermal-hydraulic mass transfer modeling results fully support proof of concept. Pi-CO2 has the potential to lower total cost and risk to levels sufficient to stimulate global demand for CO2 from local industrial sources.

Post-combustion CO 2 capture technologies tested above ∼20 MWe on flue gas slip streams from coal-fired power plants are thus far exclusively aqueous solutions of amines or ammonia. These near-term technologies, when combined with compression to pipeline pressures, impose a ∼25-30% load on a coal-fired power plant and nearly double the cost of electricity. Much of this increase is due to the relatively low CO 2 concentration and ambient conditions of flue gas, which poses an inherently difficult separation. Nonetheless, this relatively high energy and monetary cost provides an incentive for the development of next generation lower-energy and lower-cost capture processes. Since 2006, the Electric Power Research Institute (EPRI) has had an active program to review and conduct due diligence on emerging post-combustion CO 2 capture technologies. Using this knowledgebase, we critically review and analyze the status of the broad spectrum of next generation technologies, including solvents, adsorbents, membranes, and other capture processes. This effort spans some 125 post-combustion capture technologies and is part of EPRI's on-going effort to understand the landscape of CO 2 capture technologies, to identify research gaps, and to accelerate relevant research fields. We use the taxonomy of technology readiness level (TRL) to rank and classify the landscape of CO 2 capture technologies. We provide overview results of this ranking exercise and show how the findings will be used by EPRI and the utility industry to better identify opportunities to accelerate the development cycle and to anticipate the timing of major pilots and eventual commercial offerings. This analysis also leads us to several important insights, especially for capture technologies applied at power plant scales.

Heat-stable salts (HSS) in amine-based solvents may lead to a long-term performance impairment of post-combustion CO2- capture process system. They can cause a loss of solvent capacity, corrosion, heat exchanger fouling, increased foaming or flooding, etc. The application of electrodialysis (ED) can be a possible cost effective technique for removal of HSS from degraded amine solutions. The paper presents the results of lab-scale ED experiments on HSS removal from synthetic degraded MEA solutions with different HSS content and CO2-loadings. The efficiency of ED-process for reclaiming of MEA solvent is shown. The influence of solvent CO2-loading on the specific energy consumption of ED-process is presented. The lab-scale data have been used for design and manufacturing of a pilot ED plant. Within the OCTAVIUS project it has been planned to test the ED-pilot plant at the EnBW post-combustion CO2 capture pilot plant.

The first commercial post combustion CO 2 capture plant, based on regenerable amine technology, designed by Shell Cansolv was started successfully in Q3, 2013. Subsequently, the plant conceded 72 hrs warranty test run and since then, the CO 2 capture plant has been running smoothly. The plant performance met requirements for a successful warranty test run and in most cases results were considerably better than expected. The CO 2 capture facility is designed to capture 170 tonnes of CO 2 /day from a gas-fired boiler's emissions, however, due to boiler limitations, the plant is running at a capacity of 120 tonnes of CO 2 /day. The capture facility is equipped with a prescrubber followed by an absorber and water wash on the capture side. CO 2 was captured using counter current exchange with the Cansolv DC-103 solvent, which was regenerated in the stripper. At normal operation, the average CO 2 capture was maintained at around 90%, however, CO 2 capture as high as 98% is achieved. The average specific steam consumption over the Performance Test period was noticed as 2 captured. The average CO 2 product purity was greater than 99.0%, more specifically as high as 99.8%. The capture unit is equipped with a semi-batch thermal reclaimer (TR) unit to remove ionic and non-ionic degradation products from DC-103 solvent. The average amine recovery from thermal reclaimer unit was 99.75% with a maximum of 99.8%. The CO 2 capture performance, energy consumption, Amine recovery from Thermal Reclaimer, and operational philosophy exercised at the CO 2 capture plant will help Shell Cansolv to optimize the design of the CO 2 Capture unit further. Learning's from first commercial CO 2 capture plant will help Shell Cansolv to successful start-up of upcoming commercial projects.

A key issue in post-combustion carbon capture is the choice of absorbent. In this paper two different absorbents, monoethanolamine (MEA) and ammonia (NH3), have been modeled in Aspen Plus at different temperatures for possible implementation at an oil refinery. The focus of investigation is the possibilities of heat integration between the oil refinery and the carbon capture process and how these possibilities could change in a future situation where energy efficiency measures have been implemented. The results show that if only using excess heat from the refinery for heating of the carbon capture process, the MEA process can capture more CO 2 than the NH3 process. It is shown that the configuration requiring least supplementary heat when applying carbon capture to all flue gases is MEA at 120 °C. The temperature profile of the excess heat from the refinery suits the MEA and NH3 processes differently. The NH3 process would benefit from a flat section above 100 °C to better integrate the heat needed to reduce slip, while the MEA process only needs heat at stripper temperature.

Flexible operation of post-combustion CO 2 capture (PCC) plants can improve efficiency through coordinating the balance between consumer demands for electricity and CO 2 emission reductions. This strategy however, will impose process disturbances and the immediate and long term impact is unclear. There is a justified need for the development of accurate dynamic PCC models, as well as practical experience in dynamic operation of PCC pilot plants. This paper presents CSIRO PCC pilot plant data from the 2012 and 2013 dynamic campaigns using MEA solvent. The step-change approach to dynamic plant operation was implemented and the use of density meters to instantaneously measure CO 2 loading instantaneously was investigated.

This paper evaluates different technological options for the reduction of CO 2 emissions in heavy industries through their capture and use of best available technologies. This work presents the approach and the preliminary results obtained in the evaluation of iron and steel industry using oxygen blast furnace gas recycling after CO 2 capture in a pressure swing adsorber. It also evaluates the use of post-combustion capture using amines for retrofitting in the cement industry. Both are considered the most feasible technologies to be deployed in Europe in the medium term. Calibration, validation and future work regarding iron and steel industry model are described. The study finally assess the potential of cement and iron and steel industries to supply CO 2 to urea and methanol industries, which are two prospective users of CO 2 captured in Europe.

The purpose of this study was to simulate, using Aspen Hysys TM with Amine Package and Kent-Eisenberg model for thermodynamic calculation, the post-combustion CO 2 capture and to compare different configurations of the absorption- regeneration process. In this paper, considering MEA 30% as solvent, we focused on three alternative configurations: the “Stripper Split Feed” (SSF), the “Lean Vapor Compressor” (LVC) and their combination. One of the specific aspects of this work is the fact that we considered cement flue gases, where the CO 2 content (from 20 to 30 wt.%) is higher than the one from conventional power plants (from 5 to 15 wt.%, generally considered in other studies) and which leads to different results in terms of energy savings. In a first step, the result of our simulation model was successfully validated with the use of literature results considering the St Marys cement plant in Canada as case study (CO 2 content of 24 mol.% in the gas to treat) and the classical configuration of the process. The boiler duty of the MEA 30% solvent calculated by our simulation model was equal to 3.71 GJ/tCO 2 (CO 2 capture rate of 85% with a purity of 98%) which is coherent with the literature value (3.68 GJ/tCO 2 ) considering identical operating parameters. The second step of the study was the simulation of this CO 2 capture process considering the same conditions (cement flue gases and MEA 30%) but investigating the three alternative configurations. Globally, this step highlighted that also for the CO 2 capture applied to cement flue gases significant regeneration energy savings (around 24%) are achievable thanks to the use of alternative configurations of the absorption-regeneration process. As perspectives, these simulation results will be compared to the ones obtained using the new Acid Gas Package developed by Aspen Hysys. Other innovative configurations (such as Stripper Overhead Compression “SOC”) will be simulated and the focus will be also put on other solvents (simples or activated solutions).

Standard carbonate looping promises low energy penalties for post-combustion CO2-capture and is particularly suited for retrofitting existing power plants. The heat for calcination can be provided by supplementary coal firing with oxygen leading to energy penalties and additional investment costs for air separation. To further increase the process efficiency, a new concept is considered where the heat for calcination is transferred from an external combustor to the calciner by means of heat pipes. This process modification offers even higher plant efficiencies and lower CO2 avoidance costs than the oxy-fired standard carbonate looping process. The concept of the indirectly heated carbonate looping process is tested at sufficient scale in a 300 kWth test facility at Technische Universität Darmstadt. The main focus of this paper is on the design and erection of the very innovative pilot plant that is currently being commissioned.

The Rotterdam Opslag en Afvang Demonstratieproject (Rotterdam Storage and Capture Demonstration project), or ROAD, aims to build and operate a 250 MWe equivalent CCS chain using post-combustion capture technology and off-shore storage in a depleted gas field under the North Sea. The capture plant would be retrofitted to a new 1 070 MWe coal-fired unit (Maasvakte Power Plant 3) in Rotterdam, Netherlands. It was originally intended to reach a final investment decision at the end of 2010, but the project has faced a series delay associated with permitting, complex commercial negotiations and, most seriously, funding. At the moment (September 2014), the European Commission and the Government of the Netherlands are engaged in a renewed push to solve the funding problems and allow construction to finally start. The project has financial support from the European Energy Programme for Recovery (EEPR) and the Government of the Netherlands and is now the only one of the six projects originally supported that still has any realistic prospect of being realized in the short term. This paper presents an update of the overall project development as at the time of GHGT-12 and the accomplished milestones and issues met in the permitting process. In addition, it will focus on the technical and economic aspects of integrating the capture plant with the power plant. Furthermore, it will provide an outlook on future CCS/CCU developments in Rotterdam, describing the steps under development to create a full CO2 hub in the port including options for ship transport and bio-CCS. The paper concludes with the management of the project delays and the implications for the project economics.

Engineering scale-up challenges, and potential effects of SO 2 on the calcium looping cycle for post combustion CO 2 capture have been investigated in Cranfield University's pilot scale reactor (25 kW th ). Following reactor and process modifications, close to 80% capture was achieved. SO 2 was found to have a detrimental effect on the calcium looping cycle in both batch and continuous cyclic tests, although the presence of steam from natural gas-fired burners was found to have a positive effect on maintaining capture capacity of the sorbent.

This paper describes the development of a post combustion carbon capture process from lab-scale to large-scale, with special focus on the validation of the scale-up with pilot plant tests. Important features like separation efficiency, solvent stability towards stress (caused e.g. by heat and oxygen) and reaction mechanisms with by- products in the flue gas (e.g. SOx and NOx) could be investigated. A fully automated laboratory plant operated on synthetic flue gas on 24/7 basis was used for investigation. For a first scale-up step and for testing the process with real flue gas in industrial vicinity, a pilot plant out of stainless steel was erected on a power plant site and successfully operated for more than 9,000 h. This allowed e.g. the well-founded selection of materials, the validation of various process parameters, the testing of control concepts and isokinetic emission measurement. Equipment was validated and optimized with respect to design features. The size of a full-scale carbon capture plant poses special challenges to e.g. constructability, operability and maintenance and thus requires a subtle completion concept. This paper summarizes how those requirements can be supported by sophisticated scale-up based on thorough pilot plant experiments.

This paper lays out a generic CO2 capture testing methodology that has been applied at multiple sites providing details on the procedure, its key performance indices and their associated specifications, as well as the required pre-test work. Specific application of the methodology for the CO2 Technology Centre Mongstad site, a CO2 capture testing facility located in Norway that performed CO2 capture tests using MEA, is shown as an illustrative example.

The feasibility of the post combustion process Carbonate Looping has been confirmed through operation of various test rigs at different scales worldwide. This work describes the development of a 1 MWth test rig to a 20 MWth pilot plant, shows some important and essential test results of the 1 MWth plant and presents a basic design study with a final setup of the 20 MWth pilot. The erection and operation of a pilot plant in a scale of 20 MWth is considered as a further milestone with regard to a large scale application of this technology.