Carbon Capture Plant Research Articles

Influence of CO2 on the Solubility of Potassium Glycinate in Glycine–KOH–H2O, Glycine–KHCO3–H2O, and Glycine–KOH–KHCO3–H2O

In this study, solid–liquid equilibria (SLE) were measured in the systems glycine (Gly)–KOH–H2O, Gly–KHCO3–H2O, and Gly–KOH–KHCO3–H2O using the method of freezing point depression (FPD). A total of 211 new data points are presented in the concentration range 0 < b (potassium glycinate (PG)) < 28 mol of PG/kg of water. The PG solubility was measured for the systems Gly–KOH–H2O and Gly–KHCO3–H2O with mole ratios of 1:1, 1:2, 1:5, 2:1, 5:1 (nKOH:nGly) and 1:1, 3:1 (nKHCO3:nGly). Eutectic points were identified in these systems. The SLE of CO2 loaded systems Gly–KHCO3–H2O and Gly–KOH–KHCO3–H2O were studied in order to identify the limits for safe operation of a carbon capture plant. Results revealed that PG (nKHCO3:nGly, 1:1) was less soluble in a 0.5 mol of CO2/mol of PG loaded solution than in a 0.1 mol of CO2/mol of PG solution. The understanding of the solubility of aqueous PG solutions with and without the influence of CO2 is critical in order to avoid precipitation issues related to solvent mixing, solvent handling, and during operation of a carbon capture plant. The data are important for the development of thermodynamic models.

Biofuel Production through Algae Route using Solar Assisted Carbon Capture Plant

In present scenario when there is great hike in energy demand which results in increased prices of petroleum products and the big matter of concern is that the resources are diminishing so rapidly, these diminishing fuels should be replaced by biofuels. Other sources of biofuels are limited and difficult to cultivate therefore microalgae has comes out as an important source of renewable biofuel. Microalgae grow in the presence of sunlight and CO2, and those rich in lipids are excellent source of biofuels (biodiesel) after processing. The present study was aimed at production of biofuel through microalgae route using carbon capture pilot plant and exploring feasibility of scaling-up of bio-fuel production on a mega scale coal fired thermal power plant through analysis and selection of species that can grow in ash-pond area on mass scale.

Low carbon economic dispatch of power system at multiple time scales considering GRU wind power forecasting and integrated carbon capture

To achieve carbon neutrality in electricity, measures such as increasing the share of renewable energy sources such as wind power and achieving more accurate and faster wind power forecasting, and low carbon retrofitting of thermal power units are all important to achieve the goal. Firstly, the GRU prediction algorithm was used to forecast wind power, which performed well in terms of prediction accuracy and model training speed. Then, we continue to fully utilize the source-side low-carbon characteristics by installing flue gas bypass systems and liquid storage in carbon capture plants to form an integrated carbon capture plant operation, thereby reducing carbon emissions and the proportion of abandoned wind. Secondly, a three-stage low carbon economic dispatch model is established to reduce wind abandonment by combining wind power forecasts on different time scales. Finally, a case study was carried out using a modified IEEE-39 node system. The results show that the proposed three-stage integrated dispatching method can make full use of wind energy and achieve the goal of economic dispatching of the power system.

Techno-economic evaluation of post-combustion carbon capture based on chemical absorption for the thermal cracking furnace in ethylene manufacturing

As the core unit of an ethylene production plant, thermal cracking furnace generates a large amount of CO2 emissions. To reduce the CO2 emissions, post-combustion carbon capture based on chemical absorption using monoethanolamine (MEA) solvent is used to capture CO2 from the thermal cracking furnace. The computational fluid dynamics (CFD) method was used to simulate the operation of a 60kt/a thermal cracking furnace to obtain the flow rate and composition of the flue gas. A carbon capture plant model was developed using Aspen Plus® and validated using the pilot plant test data from Technology Centre Mongstad (TCM) in Norway. Scale-up of the capture plant model was carried out to match the flue gas flow rate of the thermal cracking furnace. Two integration cases of the carbon capture plant and the industrial thermal cracking unit were carried out. The results show that the excess heat of the gasoline fractionator can be used to provide heat for the carbon capture plant without affecting ethylene production. The economic evaluation was conducted based on the two case studies. Results show that the cost of CO2 capture can be reduced from $80.03/tonne (without heat integration) to $70.41/tonne with heat integration. When considering the impact of carbon credits on capture costs, the cost will be further reduced to $50.41/tonne.

Furthering the understanding of product formation in monoethanolamine degradation: A mechanistic DFT study

A thorough understanding of the product formation originating during degradation of monoethanolamine is crucial to future commercialization of carbon capture plants. Here we report on a series of density functional theory (DFT) calculations outlining chemical pathways for the formation of oxidative degradation products. Fragmentation of monoethanolamine (MEA) radicals is surmountable given standard experimental conditions and can lead to the formation of ethanal, ethanoic acid, ammonia, methylamine, water, formaldehyde, formic acid and imines. Alternatively, the MEA radicals can form hydroperoxides after reaction with oxygen which can subsequently go on to form glycine, glycolic acid and N-(2-hydroxyethyl)glycine (HEGly). Experimentally surmountable routes to the formation of oxazoline, N-(2-hydroxethyl)ethylenediamine (HEEDA), N,N’-bis(2-hydroxyethyl)ethylenediamine (BHEEDA), epoxides, (2-Methylamino)ethanol (MAE), N-(2-hydroxyethyl)imidazole (HEI) and diethanolamine (DEA) are also presented.

Recent Advances in Small-Scale Carbon Capture Systems for Micro-Combined Heat and Power Applications

To restrict global warming and relieve climate change, the world economy requires to decarbonize and reduce carbon dioxide (CO2) emissions to net-zero by mid-century. Carbon capture and storage (CCS), and carbon capture and utilization (CCU), by which CO2 emissions are captured from sources such as fossil power generation and combustion processes, and further either reused or stored, are recognized worldwide as key technologies for global warming mitigation. This paper provides a review of the latest published literature on small-scale carbon capture (CC) systems as applied in micro combined heat and power cogeneration systems for use in buildings. Previous studies have investigated a variety of small- or micro-scale combined heat and power configurations defined by their prime mover for CC integration. These include the micro gas turbine, the hybrid micro gas turbine and solid-state fuel cell system, and the biomass-fired organic Rankine cycle, all of which have been coupled with a post-combustion, amine-based absorption plant. After these configurations are defined, their performance is discussed. Considerations for optimizing the overall system parameters are identified using the same sources. The paper considers optimization of modifications to the micro gas turbine cycles with exhaust gas recirculation, humidification, and more advanced energy integration for optimal use of waste heat. Related investigations are based largely on numerical studies, with some preliminary experimental work undertaken on the Turbec T100 micro gas turbine. A brief survey is presented of some additional topics, including storage and utilization options, commercially available CC technologies, and direct atmospheric capture. Based on the available literature, it was found that carbon capture for small-scale systems introduces a large energy penalty due to the low concentration of CO2 in exhaust gases. Further development is required to decrease the energy loss from CC for economic feasibility on a small scale. For the micro gas turbine, exhaust gas recirculation, selective gas recirculation, and humidification were shown to improve overall system economic performance and efficiency. However, the highest global efficiencies were achieved by leveraging turbine exhaust waste heat to reduce the thermal energy requirement for solvent regeneration in the CC plant during low- or zero-heating loads. It was shown that although humidification cycles improved micro gas turbine cycle efficiencies, this may not be the best option to improve global efficiency if turbine waste heat is properly leveraged based on heating demands. The biomass-organic Rankine cycle and hybrid micro gas turbine, and solid-state fuel cell systems with CC, are in early developmental stages and require more research to assess their feasibility. However, the hybrid micro gas turbine and solid-state fuel cell energy system with CC was shown numerically to reach high global efficiency (51.4% LHV). It was also shown that the biomass-fired organic Rankine cycle system could result in negative emissions when coupled with a CC plant. In terms of costs, it was found that utilization through enhanced oil recovery was a promising strategy to offset the cost of carbon capture. Direct atmospheric capture was determined to be less economically feasible than capture from concentrated point sources; however, it has the benefit of negative carbon emissions.

Low‐carbon coordinated scheduling of integrated electricity‐gas distribution system with hybrid AC/DC network

Under the promotion of low-carbon policies, the coordinated operation of integrated electricity-gas distribution system (IEGDS) considering CO2 emission is of great significance to accelerate the process of energy conservation and could improve the economy of IEGDS. The paper proposes a low-carbon coordinated operation of the IEGDS considering hybrid AC/DC distribution network, carbon capture and carbon storage. Firstly, the coordinated scheduling model of the IEGDS is discussed, with coupling constraints of gas turbines and power-to-gas. Secondly, the paper presents the model of hybrid AC/DC power distribution system, where non-linear network constraints are relaxed into second-order-cone programming forms. Regarding carbon emission, the CO2 produced by fossil fuel burning can be partly captured by carbon capture plant, stored in carbon storage tank, and transported by trucks to carbon storage warehouse that trades with the carbon market. With the cooperation of various components, a comprehensive model considering carbon flow and trading in the distribution system is innovatively presented here. Numerical experiments validate the effectiveness of proposed low-carbon coordinated scheduling model for the integrated electricity and natural gas distribution system.

Thermodynamic loss analysis of a liquid-sorbent direct air carbon capture plant

Direct air capture of CO 2 is often presented as a promising technology to help mitigate climate change, although proposed processes are highly energy intensive. We analyze Carbon Engineering’s 1 Mt-CO 2 /year natural-gas-powered direct air capture (DAC) process, which requires 273.2 MW per plant, where we find that 252 MW are irreversibly lost, corresponding to a second-law efficiency of 7.8%. Our component-level analysis details the mechanisms by which these losses of thermodynamic work potential occur in the most energy-intensive plant segments. Here, we emphasize the effects of chemical exergy dissipation in the air contactor, where stored chemical exergy is released as low-grade heat into the environment. Other major losses occur in the calciner and its preheat cyclones due to the high temperature demanded by its internal chemical reaction, as well as in the water knockout system, CO 2 compression system, and power island. Finally, we illustrate the issues arising from the use of natural gas as a feedstock for heat and power, and suggest directions to pursue for further analysis and process improvements, which we consider imperative to make this DAC process a viable option for large-scale CO 2 removal toward IPCC targets. • Full thermodynamic evaluation of a natural-gas-fueled liquid-sorbent DAC plant • Total destroyed exergy of 252 MW for 273.2 MW provided, second-law efficiency of 7.8% • Largest irreversible losses due to dissipation of chemical exergy as low-grade heat • Evaluation and discussion of thermodynamic losses for all individual components Direct air carbon capture plants’ high energy consumption may be argued as prohibitive to their large-scale deployment. Here, Long-Innes and Struchtrup analyze the thermodynamic losses/exergy destruction at a system and component level for a natural-gas-fueled plant and discuss the loss mechanisms’ implications for process improvements and energy usage reductions.

Integrated Carbon-Capture-Based Low-Carbon Economic Dispatch of Power Systems Based on EEMD-LSTM-SVR Wind Power Forecasting

The optimal utilization of wind power and the application of carbon capture power plants are important measures to achieve a low-carbon power system, but the high-energy consumption of carbon capture power plants and the uncertainty of wind power lead to low-carbon coordination problems during load peaks. To address these problems, firstly, the EEMD-LSTM-SVR algorithm is proposed to forecast wind power in the Belgian grid in order to tackle the uncertainty and strong volatility of wind power. Furthermore, the conventional thermal power plant is transformed into an integrated carbon capture power plant containing split-flow and liquid storage type, and the low-carbon mechanism of the two approaches is adequately discussed to give the low-carbon realization mechanism of the power system. Secondly, the mathematical model of EEMD-LSTM-SVR algorithm and the integrated low-carbon economic dispatch model are constructed. Finally, the simulation is verified in a modified IEEE-39 node system with carbon capture power plant. Compared with conventional thermal power plants, the carbon emissions of integrated carbon capture plants will be reduced by 78.248%; the abandoned wind of split carbon capture plants is reduced by 53.525%; the total cost of wind power for dispatch predicted using the EEMD-LSTM-SVR algorithm will be closer to the actual situation, with a difference of only USD 60. The results demonstrate that the dispatching strategy proposed in this paper can effectively improve the accuracy of wind power prediction and combine with the integrated carbon capture power plant to improve the system wind power absorption capacity and operational efficiency while achieving the goal of low carbon emission.

Atmospheric Dispersion of Gaseous Amine Emitted from Absorption-Based Carbon Capture Plants in Saskatchewan, Canada

Carbon capture and storage (CCS) is a key strategy to reduce carbon dioxide (CO2) emissions from industrial point sources. Gas absorption into aqueous amine solutions is an immediate technology for carbon capture that has been tested in many demonstration plants. One concern of using the amine-based carbon capture process is the environmental impacts and health risk caused by emissions of gaseous amines from the process to the atmosphere. This work applied the knowledge of air dispersion modelling to map out the atmospheric dispersion and resulting ground surface level concentration of gaseous amine, namely Monoethanolamine (MEA), from a coal-fired power plant (with a carbon capture unit) and in surrounding areas, in case of an accidental leaking of amine from the CCS system to the atmosphere. The chosen study area was centered on a coal-fired power plant in the province of Saskatchewan, Canada. The Environmental Protection (EPA) approved air pollution model (CALPUFF), together with meteorological and geophysical data were used for gaseous amine dispersion simulation. The results were presented, and the ground amine concentrations were found to vary with wind patterns (wind direction and wind speed). The maximum ground surface amine concentrations standard is 15.2 µg/m3. However, the results showed that when using the water wash unit, the MEA concentrations were well below the standard level, compared to those without the water wash unit. It is essential for CO2 capture plants located in highly populated areas to be equipped with water wash units.

Sinopec completes China’s first large carbon capture plant

Sinopec completes China’s first large carbon capture plant

Effect of physical properties of synthesized protic ionic liquid on carbon dioxide absorption rate.

The concentration of carbon dioxide gas has accelerated over the last two decades which cause drastic changes in the climatic conditions. In industries, carbon capture plants use a volatile organic solvent which causes many environmental threats. So, a low-cost green absorbent has been formulated with nontoxicity and high selectivity properties for absorbing carbon dioxide gas. This paper contains the synthesis process along with the structure confirmation using 1H NMR, 13C NMR, FT-IR, and mass spectroscopy. Density, viscosity, and diffusivity are measured at different ranges with standard instruments. The kinetic studies were also conducted in a standard predefined-interface stirred cell reactor. The kinetic parameters were calculated at different parameters like agitation speeds, absorption temperature, initial concentrations of ionic liquid, and partial pressure of carbon dioxide. The reaction regime of carbon dioxide absorption is found to be in fast reaction kinetics with pseudo-first-order. The reaction rate and the activation energy of CO2 absorption are experimentally determined in the range of 299 to 333K with different initial concentrations of ionic liquid (0.1-1.1 kmol/m3). The second-order rate constant and activation energy of carbon dioxide absorption in the synthesized ionic liquid is found to be 9.48 × 103m3mol-1s-1 and 16.61kJmol-1 respectively. On increasing the viscosity of the reacting solvent, the diffusivity of CO2 gas molecules decreases, and thus the rate of absorption decreases. This solvent has shown great potential to absorb CO2 at a large scale.

Technical, Economic and Environmental Analysis of the Carbon Capture and Use Plant Using Gases from a Steelmaking Process: A Case Study with a Gas Turbine

Technical, Economic and Environmental Analysis of the Carbon Capture and Use Plant Using Gases from a Steelmaking Process: A Case Study with a Gas Turbine

Results of the 2020 and 2021 campaigns of the commercial carbon capture plant at AVR Duiven

Results of the 2020 and 2021 campaigns of the commercial carbon capture plant at AVR Duiven

Recent ameliorations in membrane based carbon capture technologies

Switching to renewable energy is a time-consuming procedure while considering the current context of increasing industrialization, which has already overburdened the fossil-fueled power plants to meet the grid’s demand and supply ratio. The power industry and the energy sector are responsible for around 65 percent of total greenhouse gas (GHG) emissions, resulting in only a situation to cope with the current establishment of coal-fired power plants with integrated technology for carbon capture. This provides a lucrative opportunity to develop subsidiary technologies to incorporate with existing or upcoming power plants. Hollow fiber membrane (HFM) based technology has emerged as a cheap and efficient alternative to amine-based carbon capture plants. Moreover, due to its great absorption efficiency and ability to circumvent the problems associated with traditional packed columns, HFM technology has gained popularity in recent years. This article examines the most recent technological achievements in the field of HFM based carbon capture technologies, as well as the most significant disclosures in the field of HFM based technologies at a glance and important technological benchmarks for HFMC-based carbon capture has been embarked.

Will blue hydrogen lock us into fossil fuels forever?

Will blue hydrogen lock us into fossil fuels forever?

Dynamic Modeling and Control of a Simulated Carbon Capture Process for Sustainable Power-to-X

The goal of this study is to develop a dynamic model for a Carbon Capture (CC) process that can be integrated with a water electrolysis facility. The possibility of operating the post-combustion CC plant dynamically is investigated. The final model successfully tracks the parallel hydrogen production, providing the stoichiometric required CO2 stream for the subsequent methanol reactor. A dynamic model is used to configure controllers and to test the unit performance and stream conditions for various set points. Through the transient operation, the required feed gas is provided while optimizing the solvent and energy requirements. It is found that the slowest acting stage is the reboiler with a time constant of 3.8 h. Other process variables stabilize much quicker, requiring only a few minutes to reach steady-state conditions. The hydrogen-tracking scenario shows that the carbon capture plant can successfully operate under varying conditions with a maximum CO2 output increase of 7% of the minimum flowrate in the representative 24 h simulation time. The output CO2 stream is maintained at the desired &gt;98% purity, 25 °C temperature, and 1.85 bar pressure, which allows to successfully perform hydrogen tracking operations.

A Decarbonization Roadmap for Singapore and Its Energy Policy Implications

As a signatory to the Paris Agreement, Singapore is committed to achieving net-zero carbon emissions in the second half of the century. In this paper, we propose a decarbonization roadmap for Singapore based on an analysis of Singapore’s energy landscape and a technology mapping exercise. This roadmap consists of four major components. The first component, which also underpins the other three components, is using centralized post-combustion carbon capture technology to capture and compress CO2 emitted from multiple industrial sources in Jurong Island. The captured CO2 is then transported by ship or an existing natural gas pipeline to a neighboring country, where it will be stored permanently in a subsurface reservoir. Important to the success of this first-of-a-kind cross-border carbon capture and storage (CCS) project is the establishment of a regional CCS corridor, which makes use of economies of scale to reduce the cost of CO2 capture, transport, and injection. The second component of the roadmap is the production of hydrogen in a methane steam reforming plant which is integrated with the carbon capture plant. The third component is the modernizing of the refining sector by introducing biorefineries, increasing output to petrochemical plants, and employing post-combustion carbon capture. The fourth component is refueling the transport sector by introducing electric and hydrogen fuel cell vehicles, using biofuels for aviation and hydrogen for marine vessels. The implications of this roadmap on Singapore’s energy policies are also discussed.

Environmental and energetic analysis of coupling a biogas combined cycle power plant with carbon capture, organic Rankine cycles and CO2 utilization processes

Greenhouse gas emissions from power plants that use fossil fuels cause a serious impact to the environment, for this reason the use of renewable energy technologies is an important alternative as a way of combatting climate change. The production of power via biomass is considered as a carbon neutral energy resource, but it is well known that the non-fossil CO2 emitted from this type of processes can also be captured. In order to do so, in this work it is proposed a match between a Biogas combined cycle power plant and postcombustion carbon capture process, to capture the CO2 produced by the biogas combustion, and also it considered a match with an organic Rankine cycle that uses the wasted energy of the combustion gases. Additionally, it is considered that the captured carbon is used to produce some value-added chemicals and fuels. Environmental and energetic evaluations were carried out for the coupling of those technologies. The implementation of the carbon capture plant, results on a diminution of the 87% of the emission of the combined cycle power plant. The life cycle analysis results show that the study case of Syngas production via dry reforming of methane, presents the lower global warming potential (0.088 CO2-eq kg/kg) and it was also found that the global warming potential has a reduction with the help of the mass integration between the different alternatives of CO2 utilization. Finally, it was found an annual reduction of 0.055 CO2-eq t for the system with mass integration compared with the cases without mass integration.

Capital cost estimation of CO2 capture plant using Enhanced Detailed Factor (EDF) method: Installation factors and plant construction characteristic factors

Capital cost is frequently estimated for new and retrofit carbon capture plants as new concepts for cost reduction emerge. Capital cost during initial cost estimation of chemical plants strongly depends on the installation factor(s) of the methodology employed. How these installation factors respond to the cost of each equipment determines the total plant cost and the type of capital cost (new plant or modification project) each method is suited for. The effect of equipment installation factors on capital cost of an amine-based CO2 capture plant using the Enhanced Detailed Factor (EDF) method has been studied. Plant construction characteristic factors have also been introduced to account for different plant construction characteristic situations. The impacts of the installation factors of seven methodologies on capital cost were compared. A uniform installation factor will likely lead to overestimation of very expensive equipment and underestimation of less expensive equipment. EDF method's installation factors respond based on each equipment cost. Even though all the methods estimated the optimum ΔTmin in the cross-exchanger to be 15°C, the cost estimated was €66/tCO2 by the EDF method, Smith's percentage of delivered-equipment factorial method and Hand's factorial method; and €69–79/tCO2 by the other methods. The results demonstrate that the EDF method is suitable for estimating capital cost for new plants and modification projects, small and large plants, and accounts for different plants’ situations.