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Various industries around the world recognize the importance of achieving Net Zero Greenhouse Gases (GHG) emission by 2050. Industrial processes have been attributed to the increase in CO2 concentrations causing climate change. As the rate of emissions continues to increase, there becomes a pressing need to adopt new technologies that allow for a real shift towards emission reduction. In this paper, Carbon Capture (CC) technologies are explored and reviewed across various industries namely: cement, steel, ethanol and powerplants. A statistical representation of various CC implementations and facilities is presented with a supportive case study, including some evaluative discussions of energy demands, capture rates, and economic impacts of various technology adoptions. Moreover, the paper includes a comparative data analysis of various solvents and configurations used for carbon capture, to show their effectiveness in reducing CO2 and cost of implementation. The paper also discusses some crucial limitations and challenges of CC, including economic and technical aspects. However, with the success seen in CC applications across various industries, there remains scope for future work to address novel solvents, with reduced costs and minimum modifications to existing processes. A brief overview of life cycle assessment of carbon capture and storage is also presented. [ABSTRACT FROM AUTHOR]

The sudden increase in the concentration of carbon dioxide (CO2) in the atmosphere due to the high dependency on fossil products has created the need for an urgent solution to mitigate this challenge. Global warming, which is a direct result of excessive CO2 emissions into the atmosphere, is one major issue that the world is trying to curb, especially in the 21st Century where most energy generation mediums operate using fossil products. This investigation considered a number of materials ideal for the capturing of CO2 in the post-combustion process. The application of aqueous ammonia, amine solutions, ionic liquids, and activated carbons is thoroughly discussed. Notable challenges are impeding their advancement, which are clearly expatiated in the report. Some merits and demerits of these technologies are also presented. Future research directions for each of these technologies are also analyzed and explained in detail. Furthermore, the impact of post-combustion CO2 capture on the circular economy is also presented. [ABSTRACT FROM AUTHOR]

Membrane technology advancements within the past twenty years have provided a new perspective on environmentalism as engineers design membranes to separate greenhouse gases from the environment. Several scientific journals have published articles of experimental evidence quantifying carbon dioxide (CO 2 ), a common greenhouse gas, separation using membrane technology and ranking them against one another. On the other hand, natural systems such as the respiratory system of mammals also accomplish transmembrane transport of CO 2 . However, to our knowledge, a comparison of these natural organic systems with engineered membranes has not yet been accomplished. The tracheal respiratory systems of insects transport CO 2 at the highest rates in the animal kingdom. Therefore, this work compares engineered membranes to the tracheal systems of insects by quantitatively comparing greenhouse gas conductance rates. We demonstrate that on a per unit volume basis, locusts can transport CO 2 approximately ∼100 times more effectively than the best current engineered systems. Given the same temperature conditions, insect tracheal systems transport CO 2 three orders of magnitude faster on average. Miniaturization of CO 2 capture systems based on insect tracheal system design has great potential for reducing cost and improving the capacities of industrial CO 2 capture., (© 2024 IOP Publishing Ltd.)

The sudden increase in the concentration of carbon dioxide (CO2) in the atmosphere due to the high dependency on fossil products has created the need for an urgent solution to mitigate this challenge. Global warming, which is a direct result of excessive CO2 emissions into the atmosphere, is one major issue that the world is trying to curb, especially in the 21st Century where most energy generation mediums operate using fossil products. This investigation considered a number of materials ideal for the capturing of CO2 in the post-combustion process. The application of aqueous ammonia, amine solutions, ionic liquids, and activated carbons is thoroughly discussed. Notable challenges are impeding their advancement, which are clearly expatiated in the report. Some merits and demerits of these technologies are also presented. Future research directions for each of these technologies are also analyzed and explained in detail. Furthermore, the impact of post-combustion CO2 capture on the circular economy is also presented.

This paper presents the findings of the techno-economic assessment undertaken by Wood for the UK Government Department for Business, Energy and Industrial Strategy on the large-scale deployment of Molten Carbonate Fuel Cells (MCFCs) for post-combustion CO2 capture integrated with a new build combined cycle gas turbine power plant for the generation of low carbon electricity. The findings are compared with a state of the art proprietary amine scrubbing technology. Based on a new build power plant to be installed in the North East of England, with a power train comprising two trains of H-class gas turbines each with a dedicated steam turbine, the configuration presented utilises MCFCs between the gas turbine exhausts and their heat recovery steam generators and cryogenic separation for unconverted fuel recycle and CO2 purification. It was found that the proposed configuration could achieve 92% CO2 capture from the overall power plant with MCFCs while achieving 42% of additional new power production with only 2.6 %-points of thermal efficiency penalty compared to a conventional proprietary amine benchmark. While the total project capital cost increased by 65%, the high overall thermal efficiency and additional power generated resulted in a Levelised Cost of Electricity almost identical to the benchmark at £70/MWh (US$97/MWh). A number of areas are identified for potential further improvement in this scheme. It is concluded that use of MCFC technology, which also has the capability to be tailored for hydrogen production and combined heat and power services, shows significant potential to be competitive with, or exceed, the cost and technical performance of current state of the art technologies for post-combustion CO2 capture.

This paper investigates the relationships among the important process parameters that impact Post-combustion Carbon Capture (PCC) carbon dioxide (C O 2) separation. A better understanding of the complex relationships among those parameters can support optimization and performance enhancement of the separation process. Being able to precisely predict the process parameters will enable the operator to determine the current state of the process, forecast any potential changes or events, and adjust process parameters to enhance the plant's performance. With the objective of studying the process parameters' correlations in the amine-based PCC process, we modeled the multi-year historical production data of the Clean Energy Technologies Research Institute (CETRi) (formerly known as the International Test Center for PCC or ITC) in Regina, Saskatchewan, Canada, using a Decision Forest approach. The model validation process revealed that the Decision Forest model produced higher predictive accuracy than previous efforts. The Decision Forest models we developed also represent knowledge about the importance of parameters involved in the capture process, and such knowledge is useful for further optimization of the capture process in the future. • Modeling the parameters of the Carbon Capture process with machine learning (ML). • The ML models used Decision Forest with Gradient Boosting and Oblique Split. • The ML models achieved superior predictive accuracy compared to past efforts. • The ML models support interpretability by visualizing weights and prediction paths. [ABSTRACT FROM AUTHOR]

Intensive energy penalty caused by CO2 separation process is a critical obstacle for retrofitting power plant with carbon capture technology. Therefore, the concept of utilizing solar energy to assist solvent regeneration for post-combustion carbon capture power plant is proposed recently as a promising pathway to compensate the efficiency reduction derived from CO2 capture process. However, the feasibility of solar-assisted post-combustion technologies largely depends on the types of CO2 absorbent, categories of solar thermal collectors, areas of solar field, and the integration of thermal energy storage system. Therefore, this paper conducts a comparative analysis on monoethanolamine-based and NH3-based solar-assisted post-combustion power plants employing two types of solar collectors, i.e the vacuum tube and the parabolic through collector, with climate data of Tianjin City, China. Levelized costs of electricity and cost of CO2 removed are comparatively studied for both solar-assisted post-combustion configurations. Results show that the proposed solar-assisted post-combustion configurations are economically viable when the price of vacuum tube is lower than 86.64 $/m2 and 117.29 $/m² for the monoethanolamine-based and NH3-based solar-assisted postcombustion power plant, respectively. Meanwhile, the price of parabolic through collector should be less than 111.12 $/m² for the monoethanolamine-based and 114.51 $/m² for the NH3-based solar-assisted post-combustion power plant. It is indicated that employing the vacuum tube for chilled NH3-based solar-assisted post-combustion power plant offers a promising approach to reduce the energy penalty with attractive economic performance. [ABSTRACT FROM AUTHOR]

Heavy industries including cement, iron and steel, oil refining, and petrochemicals are collectively responsible for about 22% of global CO2 emissions. Among these industries, oil refineries account for 4–6%, of which typically 25–35% arise from the regenerators in Fluid Catalytic Cracking (FCC) units. This article reviews the progress in applying CO2 capture technologies to FCC units. Post combustion and oxyfuel combustion have been investigated to mitigate CO2 emissions in FCC and, more recently, Chemical Looping Combustion (CLC) has received attention. Post combustion capture can readily be deployed to the flue gas in FCC units and oxyfuel combustion, which requires air separation has been investigated in a pilot-scale unit by Petrobras (Brazil). However, in comparison, CLC offers considerably lower energy penalties. The applicability of CLC for FCC has also been experimentally investigated at a lab-scale. As a result, the studies demonstrated highly promising CO2 capture capacities for FCC with the application of post combustion (85–90%), oxyfuel combustion (90–100%) and CLC (90–96%). Therefore, the method having lowest energy penalty and CO2 avoided cost is highly important for the next generation of FCC units to optimize CO2 capture. The energy penalty was calculated as 3.1–4.2 GJ/t CO2 with an avoiding cost of 75–110 €/t CO2 for the application of post combustion capture to FCC. However, the application of oxyfuel combustion provided lower energy penalty of 1.8–2.5 GJ/t CO2, and lower CO2 avoided cost of 55–85 €/t CO2. More recently, lab-scale experiments demonstrated that the application of CLC to FCC demonstrate significant progress with an indicative much lower energy penalty of ca. 0.2 GJ/t CO2.

There is a wide range of resources for CO2 emissions. The net amount of CO2 emissions in the cement industry due to the consumption of fossil fuels and the chemical processes of cement production under heating raw materials is reported to be in the range of 15–25%; this industry, among all the industries and after the power plants and refineries, is the largest CO2 gas producer throughout the world. Using CO2 capture and storage (CCS), it can reduce greenhouse gas emissions in a short time. In this study, the technical feasibility study of recycling CO2 in Abyek Cement Company, with a cement production capacity of about 12,500 tons per day in two production lines, has been studied as one of the largest cement industries throughout the world. Fuel oil (Mazut) is used as the primary fuel for furnaces in this industry. Affected by combustion, the emissions emitted from the five-stage preheater contain 5/24% vol% of CO2, 7.6% H2O, 4.8% vol% of O2, and 63.1% N2. [ABSTRACT FROM AUTHOR]

Flexible operation of combined cycle thermal power plants with chemical absorption post combustion CO 2 capture is a key aspect for the development of the technology. Several studies have assessed the performance of decentralized control structures applied to the post combustion CO 2 capture process via dynamic process simulation, however there is a lack of published data from demonstration or pilot plants. In this work, experiments on transient testing were conducted at the amine plant at Technology Centre Mongstad, for flue gas from a combined cycle combined heat and power plant (3.7–4.1 CO 2 vol%). The experiments include six tests on open-loop responses and eight tests on transient performance of decentralized control structures for fast power plant load change scenarios. The transient response of key process variables to changes in flue gas volumetric flow rate, solvent flow rate and reboiler duty were analyzed. In general the process stabilizes within 1 h for 20% step changes in process inputs, being the absorber column absorption rates the slowest process variable to stabilize to changes in reboiler duty and solvent flow rate. Tests on fast load changes (10%/min) in flue gas flow rate representing realistic load changes in an upstream power plant showed that decentralized control structures could be employed in order to bring the process to desired off-design steady-state operating conditions within (<60 min). However, oscillations and instabilities in absorption and desorption rates driven by interactions of the capture rate and stripper temperature feedback control loops can occur when the rich solvent flow rate is changed significantly and fast as a control action to reject the flue gas volumetric flow rate disturbance and keeping liquid to gas ratio or capture rate constant. [ABSTRACT FROM AUTHOR]

• The steady operation of the methane/ammonia free-piston engine was achieved. • Effects of ammonia addition on the engine operating characteristics were studied. • Combustion and emission characteristics of the engine were studied numerically. • Obvious post combustion phenomenon occurred under the ammonia addition condition. In this paper, experimental and numerical studies of the methane-ammonia dual-fuel glow-ignition free-piston engine generator (FPEG) are carried out, with emphasis on its operation stability, performance and combustion characteristics. The ammonia in FPEG operates at different energy substitution rates (ESRs), including 100 %CH 4 , 90 %CH 4 +10 %NH 3 , 80 %CH 4 +20 %NH 3 , and 70 %CH 4 +30 %NH 3. The experimental results show that the FPEG can achieve stable operation in the methane/ammonia dual-fuel combustion mode. However, the operation stability of the FPEG becomes worse with the increase of the ESR. Especially when ESR = 30 %, engine shutdown accident will occur due to the high cycle-to-cycle variation caused by ignition delay. The peak pressure and heat release rate (HRR) decrease significantly because the additive ammonia weakens the combustion activity and reduces the combustion rate of mixture. In the case of pure methane, the indicated power and indicated thermal efficiency reach 319 W and 11.33 %, respectively. However, when ESR = 10 %, 20 % and 30 %, the corresponding values decrease significantly to 210 W, 7.48 %, 189 W, 6.72 % and 139 W, 4.95 %, respectively. The high-speed flame images show that with the increase of ESR, the flame structure becomes less wrinkled, because the addition of ammonia reduces the flame speed and weakens the combustion reaction, leading to the weakening of turbulent combustion intensity. In addition, the ammonia addition will also lead to post combustion phenomenon. The simulation results show that the start of combustion (SOC) is delayed and the crank angle (CA) 0–10 and CA10-50 are prolonged with the increase of ESR, because the ammonia addition reduces the amount of key radical, such as OH and H, which reduces the mixture reaction rate. The NOx emission decreases with the increase of ESR due to the low combustion temperature. Soot emissions from the pure methane remain extremely low, and the CO emissions gradually increase with the increase of ESR due to the incomplete combustion of mixture. In addition, the amount of unburned ammonia increases with the increase of ESR. [ABSTRACT FROM AUTHOR]

The GE Chilled Ammonia Process (CAP) is a post combustion CO 2 capture technology that produces a high purity CO 2 product stream that can be utilized in the existing and new markets. The development of the CAP technology began with laboratory bench-scale experiments to confirm that aqueous ammonia solution effectively absorbs CO 2 with sufficiently low vapor phase ammonia emissions at reduced temperatures. From these results, a technology development program was initiated to scale-up and validate the process for commercialization. The approach taken here is illustrative of industrial scale process development and improvement. For the CAP CO 2 capture technology, the development effort involved an iterative approach as information from the different development stages was obtained to set environmental & economic targets, develop predictive tools and models for process optimization, and to support validation efforts at operating facilities. Over the course of the program, the technology was successfully tested on flue gasses produced from coal, oil, and natural gas combustion, in addition to flue gas produced from refinery applications. Process know-how and operational experience was gained and together with validated data from bench-scale and pilot plant facilities was returned to push process design improvement and the development of predictive models. Currently, the CAP design is also modified and extended into applications involving Urea, Methanol, and Soda Ash Production. While many lessons learned and process improvement opportunities have been extracted from pilot plant and other test facilities, pilot plant results and process modeling studies are still unveiling potential for further improvement. Optimization and integration with the power generation facility occurred in the development phases of several FEED studies for large CCS plants. The CAP design is ready for a demonstration-scale project and now is much improved from the design that was tested originally at laboratory bench-scale. For example, the CAP scrubbing solution is now operated in a non-solids mode where precipitation is not a part of the overall operational strategy and the process flow scheme is now modified and improved from original flow schemes implemented at early pilot facilities to improve performance at reduced cost. This work summarizes the bench-scale, pilot-scale, and validation facility results and offers insights into the lessons learned and effort required bringing the technology into commercialization at an industrial scale. The lessons learned from each of the pilot plants at different sizes are illustrated and the associated impact of the results from each pilot plant in the current CAP product offering is also discussed. A summary of the important results from CAP test facilities including Stanford Research International (SRI), WE energies, EONCAP-Karlshamm, AEP Mountaineer, TCM and GE's pilot facility in Vaxjo, Sweden are presented. Distinguishing features of the GE CAP are provided drawing comparison to open literature versions of ammonia based CO 2 capture processes. Evolution of key performance parameters such as energy demand, product quality, solvent strength, process flow scheme, etc., at the different plant sizes are also discussed. In addition, the current state of development for extending the technology into areas where CO 2 may be utilized productively are also be addressed in addition to the latest improvement concepts currently being studied on CAP. Finally, the paper will also summarize the advantages of CAP as compared to conventional amine based processes. [ABSTRACT FROM AUTHOR]

IHI has been developing Post Combustion Capture (PCC) technology using a chemical absorption process which is applied to coal-fired power plants. To reduce the costs of CO 2 capture, we have been investigating advanced amine solvents, packings, and process. The 2 nd IHI packing and new process were evaluated at a 20 ton-CO 2 /d pilot plant. The absorption performance of the 2 nd IHI packing was 1.8 times higher than a conventional packing with almost the same pressure loss per unit height. As a result of process performance tests, the regeneration energy of new IHI process achieved less than 2.4 GJ/t-CO 2 exluding the radiation heat. [ABSTRACT FROM AUTHOR]

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 CO 2 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. [ABSTRACT FROM AUTHOR]

CEMCAP ( http://www.sintef.no/cemcap/ ) is an EU Horizon 2020 project that aims at maturing CO 2 capture technologies suitable for retrofitting to existing cement plants by undertaking pilot-scale demonstration under industrially relevant conditions. Four capture technologies are being tested, analyzed and compared on a consistent basis: Oxyfuel capture, Chilled Ammonia Process (CAP), membrane-assisted CO 2 liquefaction and Calcium looping. Beyond CEMCAP, having more options than the already mature amine technology available for retrofittable CO 2 capture from cement plants, the technology options for CCS deployment will be expanded. However, it must be recognized that technology development alone will not contribute to the realization of CCS in the European cement industry or any industrial sector. Investment decisions in the EU will require a long term predictability of the policy for prevention of carbon leakage (re-location of production and emissions). [ABSTRACT FROM AUTHOR]

To significantly reduce the amount of emission of carbon dioxide (CO 2 ) to the atmosphere, which is a principal cause of climate change (global warming), and to realize a low-carbon society, the introduction of Carbon dioxide Capture and Storage (CCS) into coal-fired power plants is expected to be effective. Emissions from post-combustion CO 2 capture plants using amine solution may affect the human health and environment. It is, therefore, important to evaluate the environmental impacts by conducting environmental risk assessment, and to, if necessary, employ emission reduction technologies, for effectively introducing CCS. Case studies on amine emissions from the CO 2 capture process and the results of environmental risk assessment are reported. However, there are no guidelines on environmental risk assessment method for the CO 2 capture process which enable plant owners to reduce the environmental impact of the process, to increase understanding of local residents (near CO 2 capture plants) and public, and to promote the introduction of CCS. In this study, as part of the project by Ministry of the Environment (Japan), Mizuho Information & Research Institute, Inc. (MHIR) and Toshiba Corporation drafted the guidelines presenting the basic principles (methods, basic points) of environmental risk assessment with regard to exhaust gas and other parameters involved in the CO 2 capture process. Based on Toshiba's emission data from 10 ton-CO 2 /day scale pilot plant using MEA solution at Mikawa coal fired thermal power plant, MHIR conducted a trial of environmental risk assessment for the CO 2 capture process, examined the risk assessment procedure, and drafted technical guidelines. The guidelines are expected to enable plant owners to make reasonable judgement on “how far emission should be reduced”, and thus to decide “to what extent they should employ emission reduction technologies”. And, the guidelines include “whole-mixture approach”, which not only helps to conquer the issues typical of the CO 2 capture process but also is easy to understand and thus familiar to local residents and public. [ABSTRACT FROM AUTHOR]

In this study, Toshiba conducted evaluation of amine emissions from 10ton-CO 2 /day scale pilot plant within 30wt% MEA solution as well as Toshiba solvent (TS-1), as part of the project by the Ministry of the Environment (Japan). The results show that TS-1 developed by Toshiba has significant advantages over a 30wt% MEA solution in terms of mitigating amine emissions from the top of the absorber. On the other hand, it was found that mist-driven amine emissions are less likely to be reduced by water wash and acid wash, compared to vapour pressure-driven amine emissions. We also verified the role of aerosol contained in the raw flue gas on amine mist formation/growth in the CO 2 absorber. As a result, it is interesting to note that remarkable increase in number concentration of the amine mist from the top of the 1 st tower (water wash) was observed, depending on the increase in number concentration of the aerosol in the flue gas upstream of the absorber. Additionally, the aerosol is nano-order, which is much smaller than that of amine mist (micro-order), and the fluctuation tendencies of the peak diameter of both the aerosol and amine mist were very similar. Therefore, this might indicate that the aerosol acts as a source of amine mist nuclei and enhances amine mist growth in the CO 2 absorber. [ABSTRACT FROM AUTHOR]