CO2 Compression Research Articles

Evolution of anthracite nanopores with CO2 adsorption at different pressures by synchrotron radiation small angle X-ray scattering

As a porous medium, coal has a strong adsorption capacity for CO2. Nanopore is the main adsorption space of coal reservoir. To study the evolutionary characteristics of nanopores in coals with CO2 adsorption, in situ small angle X-ray scattering experiments of anthracite at different CO2 adsorption pressures were carried out. The change of scattering intensity ratio RI in nanopores with different sizes were analyzed. The porosity, specific surface area and average aperture were quantitatively characterized. The research shows that the 5 nm pores is more susceptible to higher CO2 pressure, while the scattering phenomenon in the 15 nm pores changes most obviously at lower CO2 pressure. The deformation sensitivity of 35–75 nm pores to CO2 adsorption is consistent. The scattering data in anthracite show a positive Porod deviation. CO2 will become dense with increasing pressure, and its filling of nanopores makes some scattering phenomena become invisible to X-ray. There will be a new boundary between dense CO2 and free CO2, which affects the fluctuation of electron density between two-phase systems. There is a positive correlation between the Porod deviation of the scattering data and the CO2 pressure. In the process of CO2 adsorption, the dynamic deformation of anthracite nanopores is obvious, resulting in synchronous changes of porosity and specific surface area. CO2 adsorption pressure is negatively correlated with porosity and specific surface area, but positively correlated with the average aperture. The decrease of CO2 pressure leads to the gradual recovery of nanopore deformation. However, at different evolution stages of the same CO2 pressure, the porosity, specific surface area and average aperture of anthracite are inconsistent. Irreversible damage to anthracite nanopores is produced with CO2 adsorption. The evolution of nanopores is the result of the superposition of CO2 compression and adsorption.

On the exergy efficiency of CO2 capture: The relation between sub-process and overall efficiencies

A generic exergy targeting tool for gas separation processes is developed, which is applicable to any defined boundary conditions for incoming feed gas as well as delivered separation products. Whereas targeting tools in the literature so far are mostly simplified and limited to post-combustion related cases and isothermal and isobaric conditions, the present approach is based on a rigorous exergy methodology, which enables exergy targeting for a broad spectrum of boundary conditions.Understanding the causes behind thermodynamic losses throughout the process is a prerequisite for improving energy efficiency. In this respect, exergy analysis provides a powerful tool, which enables the identification and quantification of irreversibilities and thereby exergy losses. The methodology is used to show that common separation processes can be attributed with negative minimum separation work, since a corresponding reversible separation process would yield an exergy output in addition to providing the specified product streams.CO2 capture involves considerable energy demand caused by the various processing steps. The exergy balance of a CO2 capture process can in turn be applied to determine the exergy efficiency for each sub-process as well as for the overall process. Exergy efficiency criteria can be formulated in different ways, and in the present work it will be evaluated primarily against the minimum theoretical exergy requirement, that is, the performance theoretically achievable for a reversible process.Through a quantitative example based on published literature on CO2 separation from syngas, it is shown that a process may still require a substantial amount of exergy input despite having a negative minimum separation work, which in turn results in a negative exergy efficiency. A relation between sub-system exergy efficiency and overall system exergy efficiency is derived on a general basis. For the numerical example of CO2 capture from syngas, the derived relation shows consistency and is able to reproduce the total process efficiency also when one of the sub-processes, CO2 separation, has a negative exergy efficiency. Exergy efficiency results are finally compared with corresponding results based on a well-established rational exergy efficiency.Despite different values and even signs for the separation sub-process efficiency, it is still shown that there are no contradictions between the two efficiency criteria when used consistently, since they give identical total exergy efficiency when applied to the control volume of the combined CO2 separation and compression process, and since identical results are obtained also when expressing the total exergy efficiency as a linear combination of the two sub-process efficiencies, one of which has a negative sign.

A techno-economic assessment of the reutilisation of municipal solid waste incineration ash for CO2 capture from incineration flue gases by calcium looping

Waste-to-Energy (WtE) through municipal solid waste (MSW) incineration is a key waste management strategy to reduce the mass and volume of landfilled wastes, especially for land-constrained areas such as urban centres. However, this process releases large amounts of CO2 into the atmosphere and the ash that remains after burning, which contains a variety of metals and minerals, is often sent to the landfill after some metal recovery. In this study, the CaO containing ash is used to derive sorbents for the calcium looping (CaL) process for post-combustion CO2 capture and storage (CCS), and a techno-economic assessment was performed to preliminarily probe the feasibility of retrofitting a CaL plant using ash-derived sorbents to capture CO2 from a 200MWth WtE plant, as a possible means to decarbonise WtE plants. The analysis was performed through process modelling of the CaL plant using 4 different supplementary fuels in the calciner, namely, biomass charcoal (BC), solid recovered fuel (SRF), coal, and natural gas (NG). At the base purge ratio of 5%, all the cases show increases in the levelised cost of electricity (LCOE) over the base WtE, ranging from 184 (NG) to 246 (BC) USD/MWhe. The sale of additional electricity generated from the heat recovery steam cycle could slightly mitigates the capital intensiveness of the process, resulting in a levelised cost of carbon abatement (LCCA) range of USD 89 (SRF) to 184 (coal)/tCO2, which is competitive with other bioenergy with CO2 capture and storage (BECCS) technologies. The biogenic fuels also result in lower specific primary energy consumption per CO2 avoided (SPECCA) of 5.6 (BC) and 6.8 (SRF) MJLHV/tCO2, which are comparable to values from other CCS technologies and CaL implementation studies. Sensitivity analysis of 14 economic and process parameters reveals that further improvements can be achieved through optimisation of the energy intensive sub-processes, such as cryogenic air separation and CO2 compression and purification. Tighter solid heat integration (SHI) concepts were also modelled and are shown to effectively reduce fuel and O2 requirements by up to 22.2%, thereby lowering annualised costs by up to 11.9%. In addition, this paper highlights the importance of regulatory support through favourable policies such as higher carbon pricing and CO2 credit trading to push the development and adoption of negative emission technologies to meet global decarbonisation targets.

Blade design and analysis of centrifugal compressors for the transcritical carbon dioxide refrigeration cycle

The compressor is one important component in the transcritical CO2 (carbon dioxide) refrigeration cycle. The CO2 compressor has a small volume at the same refrigeration capacity because its refrigeration capacity per unit volume is large. The radial compressor often used in the CO2 refrigeration cycle has complex internal flow and difficult blade modeling. The paper presented a new centrifugal compressor with radial flow, whose blades are straight and easy to process. Taking a single stage compressor blade for example, the effects of the velocity coefficient, energy head coefficient, rotational speed of the moving blade, blade height, inlet radius and radial distance of the blade on the efficiency and pressure ratio were studied. According to the conclusions, the paper designed and simulated the blades of two compressors of the transcritical CO2 two-stage refrigeration cycle. Simulation result showed that the efficiencies of the two compressors were respectively 84.97% and 87.23%.

Design strategy for inlet conditions of supercritical CO2 centrifugal compressors

To improve the aerodynamic performance and suppress the condensation in supercritical CO2 centrifugal compressors, a design strategy is proposed in this paper. The inlet compression factor and density are adopted to study the compressor performance and flow characteristics by solving three-dimensional Reynolds-averaged Navier-Stokes equations with condensable gas. The results indicate that in the range of operating conditions studied, increasing inlet compression factor or density, the condensation area will decrease. However, the pressure ratio will also decrease. By the means of decreasing inlet compression factor and increasing density, the inlet conditions alter from baseline conditions (7.69 MPa, 305.15 K) to optimization conditions (8.40 MPa, 305.54 K). The condensation area decreases by a large margin and the peak efficiency increases from 73.2% to 75.4%, while the pressure ratio remains unchanged. The design strategy provides a new idea for supercritical CO2 compressors to improve the performance and suppress the condensation at impeller inlet.

CO2 Compression and Dehydration for Transport and Geological Storage

Observation of the greenhouse effect prompts the consideration of every possibility of reducing anthropogenic carbon dioxide emissions. One of the key methods that has been the subject of much research is Carbon Dioxide Capture and Storage. The purpose of this study was to investigate the main technologies of CO2 capture, separation, and dehydration as well as methods of its transport and methodology of selecting a suitable geological storage site. An installation of dehydration and compression of carbon dioxide captured after the post-combustion was designed at a temperature of 35 °C, a pressure of 1.51 bar, and a mass flow rate of 2.449 million tons/year, assuming that the geological storage site is located at 30 km from the capture place. For the dehydration process, a multistage compression and cooling system were applied, combined with a triethylene glycol (TEG) dehydration unit. The mass flow rate of TEG was selected as 0.5 kg/s. H2O out of the TEG unit was 26.6 ppm. The amount of energy required to compress the gas was minimized by adopting a maximum post-compression gas temperature of 95 °C for each cycle, thereby reducing plant operating costs. The total power demand was 7047 kW, 15,990 kW, and 24,471 kW, and the total received heat input was 13,880.76 kW, 31,620.07 kW, and 47,035.66 kW for 25%, 60%, and 100% plant load, respectively. The use of more compressors reduces the gas temperature downstream through successive compression stages. It also decreases the total amount of energy required to power the entire plant and the amount of heat that must be collected during the gas stream cooling process. The integration of CO2 compression and cooling system to recover heat and increase the efficiency of power units should be considered.

Thermodynamic analysis of a novel isothermal compressed carbon dioxide energy storage system

Currently, compressed carbon dioxide (CO2) energy storage (CCES) mainly uses adiabatic compression. Although there is plenty of research on isothermal compression air energy storage, few of them discuss the potential of isothermal compressed CO2. This paper proposes a novel isothermal CCES (ICCES) system. The near-isothermal process is achieved by a liquid piston with a porous medium insert. An oil column is used to separate CO2 and water. A trans-critical CO2 cycle is proposed in this paper. The cycle includes a near-isothermal compression/expansion process and an isochoric heating/cooling process. A program is written to perform a simulation analysis of the system, and a one-dimension heat exchange model is used. The result shows that the choice of the thermodynamic path of CO2 affects the system most. The round-trip efficiency of the system is 0.7 when the initial pressure is 6.43 MPa and CO2 vapor quality is optimum. The energy density of the system is 0.65 kWh/m3, with the volume of CO2 gas storage occupying most of the system volume. Choosing a lower initial pressure increases the energy density. The liquid piston operation speed affects the power density and efficiency of the system. And the power density when storing energy is also greatly influenced by the CO2 vapor quality.

Thermodynamic evaluation on a new CO2 energy storage system assisted by adsorption bed

The share of renewable energy in energy systems is increasing under the background of the accelerated transformation on the current energy structure. Energy storage technologies enjoy excellent functions in dealing with the problems arising from the extensive applications of renewable energies. A compressed CO2 energy storage system configured with adsorption bed is proposed with the merits of high efficiency and large energy density in this paper. The gaseous working fluid at the turbine outlet is directly absorbed and stored by the adsorbent material in the adsorption bed, which solves the low-pressure CO2 storage problem. The thermodynamic performance and parametric analysis are investigated by establishing mathematical models of the proposed system. Results demonstrate that the maximum efficiency can be identified and the optimized HPC exit pressure is shifted to the right when the HPT inlet pressure is lower than 14 MPa, and then it is located at 15 MPa. The curve of system efficiency declines almost in a layered manner with the increase in HPT inlet pressure. The maximum efficiency is ensured by locating HPC exit pressure at 13 MPa and HPT inlet pressure at 12 MPa. Under this condition, the efficiency and energy density can reach 68.79 % and 17.44 kWh/m3, which reveals that the system efficiency is competitive and its energy density is more superior with about 5–6 times of that of the adiabatic compressed air energy storage technique.

Thermo-economic performance of a compressed CO2 energy storage system with a flexible gas holder

In recent years, engineers' eyes have been increasingly captured by the compressed CO2 energy storage since it is a competitive electricity storage technology equipped with massive renewable power plants. Nevertheless, how to design an effective system configuration, for instance the scenarios of storing CO2 in high and low pressures, vacillates to the left and right in the researchers. A CO2 energy storage cycle, configured by three section compression/expansion, two-tank heat storage, artificial tank for storing high pressure CO2 liquid and gas holder for storing ambient pressure CO2, is comprehensively examined in this paper. Both the thermodynamic and economic performances are considered. Results demonstrate that the round trip efficiency is capable of arriving at 71 % along with the levelized cost of electricity being 0.1252 $/kWh. Inspiringly, the system is operated with low pressures, charge pressure being 8 MPa and discharge pressure being 6 MPa. The turbomachineries are provided with the 68.18 % share of overall exergy destruction. The high pressure heater carries the largest exergy destruction among heat exchangers. By integrating with low grade waste heat of 39 °C, the efficiency can be further improved to 72.66 % with the levelized cost of electricity being 0.1242 $/kWh. Meanwhile, the discharge pressure should be raised to 6.58 MPa.

Energy and exergy performance evaluation of a novel low-temperature physical energy storage system consisting of compressed CO2 energy storage and Kalina cycle

To improve the overall performance of the Compressed CO2 Energy Storage (CCES) system under low-temperature thermal energy storage conditions, this paper proposed a novel low-temperature physical energy storage system consisting of CCES and Kalina cycle. The thermal energy storage temperature was controlled below 200 °C, and the Kalina cycle was used to optimize the reuse of the stored thermal energy. A thermodynamic model of the integrated system was constructed, and the system performance was analyzed from the energy and exergy perspectives. Several evaluation indicators, such as system exergy efficiency (SEE), round trip efficiency (RTE), system energy density (SED), Kalina exergy efficiency (KEE), and Kalina energy efficiency (KEnE), were defined to evaluate system performance. In addition, the influences of several core parameters (e.g., split ratio (r), storage pressure (ps), turbine efficiency (te), pinch point temperature difference (pt) of heat exchangers, and ambient temperature (T0)) on the system performance were analyzed. The results of the base condition showed that SEE, RTE, SED, KEE, and KEnE were 58.17 %, 59.38 %, 6.32 kWh/m3, 38.62 %, and 8.64 %, respectively. The exergy destruction in heat exchanger 3 was the largest, accounting for 71.7 % of total exergy destruction. The sensitivity analysis results showed that increasing r could increase the SEE of the system, increasing ps could lead to a decrease in the RTE of the system, and increasing T0 could cause the RTE and SED to increase. The increase in te could improve all evaluation indices, while the increase in pt could reduce the system's overall performance. This study provides a new solution for the integrated application and optimal design of CCES systems under low-temperature thermal energy storage conditions.

Modeling and Simulation of an Industrial-Scale 525 MWth Petcoke Chemical Looping Combustion Power Plant

This paper presents the modeling and simulation of an industrial-scale chemical looping combustion (CLC) power plant, including all process units (reactors, flue gas treatment units, heat integration, steam cycle, and CO2 compression train). A model of a 525 MWth CLC power plant was built using a rigorous representation of the solid fuel and oxygen carrier. Petcoke was considered the main fuel of interest in this study, and it is compared with other solid fuels. The flue gas compositions obtained with the model show that cleanup units are mandatory to comply with CO2 quality requirements. High levels of flue gas treatment, including 97.1% deNOx and 99.4% deSOx, are needed to achieve typical specifications for captured CO2. This is mainly due to the high level of contaminants in the fuel, but also to the absence of nitrogen in the CLC flue gas, thus resulting in higher concentrations for all substances. The high level of flue gas treatment is thus one of the important challenges for solid fuel combustion in CLC. The overall CO2 capture efficiency of the plant is estimated to be as high as 94%. Regarding the energy balance, a process net efficiency of 38% is obtained. Comparing the results with other available technologies shows that CLC exhibits one of the highest net plant efficiencies and carbon capture rates. CLC is thus a promising technology to produce clean energy from solid fuels. Finally, based on a sensitivity analysis, it is shown that process efficiency is mainly affected by the design and performance of the CLC furnace, the steam injection rate in the fuel reactor, the char separation efficiency, and the excess oxygen in the air reactor.

Environmental/Economic assessment and multi-aspect optimization of a poly-generation system based on waste heat recovery of PEM fuel cells

In the present study, a novel poly-generation system is introduced and studied from energy, exergy, economic and exergy-economic standpoints. In the proposed configuration, the waste heat of proton exchange membrane (PEM) fuel cells is recuperated by an organic Rankine cycle (ORC). Also, an LNG subsystem is chosen as a heat sink medium for the ORC. In this study, the impact of system irreversibilities on the environment is considered as part of the exergoenvironmental analysis, which is a relatively new type of study. In the considered system, PEM fuel cells are responsible for output power while the output power of the ORC and LNG subsystem is transmitted to a trans-critical CO2 compression refrigeration subsystem and a reverse osmosis desalination unit for cooling and freshwater production. A sensitivity analysis is done to assess the effect of changes in PEM fuel cells temperature, PEM fuel cells pressure, current density, and condensation temperature of ORC on the output parameters. Considering the just-mentioned parameters as design variables, the results of two-objective optimization reveals that the exergy efficiency and net present value are calculated to be 22.67 % and 56.61 M$, correspondingly. At the optimum point, the proposed system can produce 1214 kW power, 1116 kW cooling, 161.1 kW heating, and 6 kg/s freshwater. Also, exergoenvironmental index and sustainability index were obtained as 0.5472 and 2.256 at the optimum point.

Syngas production from biogas in a polygeneration process: Simultaneous partial oxidation and dry reforming in a piston engine

This work experimentally investigates the fuel-rich combustion of CH4/CO2/O2 mixtures in a piston engine. The focus of the experiments is to determine suitable operating parameters in terms of stable engine operation, syngas production, CO2 conversion, and avoiding soot emissions. In particular, the spark timing, CO2 intake mole fraction, equivalence ratio, and compression ratio were varied. Results show stable spark-ignition operation over a wide range of the investigated parameters at a compression ratio of 10. Acceptable operation could be achieved within the spark timing limits of -38° to 10 °CA after top dead center, 7 to 27% CO2 in the inlet and equivalence ratios from 2 to 2.5. A maximum H2 yield of 62% could be achieved at an equivalence ratio of 1.9 and a CO2 intake mole fraction of 4% at a compression ratio of 4.5. Spark time advancing from -10 to -38 °CA enhanced the dry reforming reaction and increased the hydrogen yield per methane from 38 to 45%. A significant influence of compression ratio on the amount of soot in the product gas was observed, showing that higher compression ratios increase soot formation.

Experimental Study on a Supercritical CO2 Centrifugal Compressor Used in a MWe Scale Power Cycle

The centrifugal compressor is the core component of supercritical CO2 power cycle, and its performance and operation stability are research hotspots. However, there are few experimental studies, especially for compressors used in Mwe-scale power cycles. In this paper, based on a 1 MWe supercritical CO2 power cycle, a single-stage centrifugal supercritical CO2 compressor is designed with speed of 40,000 RPM, a pressure ratio of 2.5 and a mass flow of 16.3 kg/s. In order to carry out the compressor test, a general experimental platform for MWe sCO2 compressors is built. In the test, the mass flow range is 13.5~18 kg/s and the maximum experimental pressure ratio is close to 2.0. The performance curve of the compressor of 31,000 ± 1000 RPM is obtained, and the historical curve of the experiment is given. Then, the experimental curve is compared with the design curve using a dimensionless method. The isentropic head coefficient of the experimental curve is lower than the design value, and the experimental curves shift towards the boundary of small flow coefficient. Finally, the influence of compressor inlet condensation on compressor performance and the change of operating boundary is preliminarily explained.

Energy efficiency, sustainability, and operating cost optimization of an FPSO with CCUS: An innovation in CO2 compression and injection systems

Production in FPSO (Floating Production Storage and Offloading) is challenging due to its energy demand, operating cost, and environmental impact. In particular, the composition of the reservoir fluid, which varies along with the life of a well, greatly affects the operation and production of the FPSO. Any optimization study aiming at reducing energy consumption, sustainability, and operating costs during the life span of a well should take this fluid variability into account. Additionally, a typical FPSO operating in the Brazilian deep-water oil regions requires process fluid with high CO2 content. Therefore, a new FPSO process plant configuration comprises a membrane-based CCU (Carbon Capture and Utilization) system integrated with an MEA-based CCS (Carbon Capture and Storage) system and a CO2 compression unit with fewer compressors and one injection unit is proposed. Subsequently, automated optimization procedures consisting of a hybrid algorithm (NSGA-II + AfilterSQP) are implemented to optimize the energy efficiency, sustainability, and operation costs of the FPSO under consideration. More than 25 thermodynamic and structural design variables are considered as input variables in the optimization procedures. The results presented a significant reduction of up to 10.1% (2.9 MW) in overall power consumption, mitigation of CO2 emissions of up to 47 kg/h, a decrease of up to 3.9% (2.4 million USD/year) in operating cost, and an improvement of up to 53.5% in total heating and cooling demand of the FPSO, which means a reduction of 3.8 × 109 (kJ/h). In a proposed system with one CO2 injection unit, optimization results in the mitigation of total power consumption of up to 1.4 MW, a decrease in capital cost of 10 million USD, a reduction in operating cost of 50 million USD/year, and an increase of 4.4% in CO2 removal efficiency.

Ultra-microporous biochar-based carbon adsorbents by a facile chemical activation strategy for high-performance CO2 adsorption

The new adsorption-enhanced compressed CO2 energy storage technology uses high-performance adsorbents to adsorb and store CO2 in low-pressure tanks, reducing vessel costs while significantly increasing energy storage density. In this paper, porous biochar with excellent CO2 adsorption capacity is prepared by carbonization combined with KOH chemical activation using pine nut shells, which can be used for the energy storage system. The influence of pore structure is revealed by changing the activation temperature. The results show that the activity of KOH is moderate at 700 °C, which can promote the formation of ultramicropores. The specific surface area of the obtained porous biochar is 1027 m2·g−1, the distribution center of ultramicropores is about 0.65 nm, and the microporosity can up to 91.7%, which is very suitable for CO2 adsorption under atmospheric pressure and room temperature. The CO2 adsorption capacities are 6.05 mmol·g−1 and 3.96 mmol·g−1 at 1 bar, 273 K and 298 K with the pore volume is only 0.56 cm3·g−1. The material also has a low value of isosteric heat of adsorption about 25 kJ·mol−1. These findings suggest that pine nut shells can be used to design highly porous biochar for the system of new adsorption-enhanced compressed CO2 energy storage.

Prediction of speed of sound in compressed hydrocarbon and CO2 mixtures: theory comparison

Prediction of speed of sound in compressed hydrocarbon and CO2 mixtures: theory comparison

Experimental study of adsorption CO2 storage device for compressed CO2 energy storage system

Compressed CO2 energy storage is a reliable physical energy storage solution. The main challenge of compressed CO2 energy storage system is how to solve the high-density storage of low-pressure CO2. In this study, we proposed a new type of adsorption transcritical compressed CO2 energy storage system. We used adsorbents to adsorb CO2 for achieving low-pressure, high-density storage of low-pressure CO2. We investigated the gas storage capacity of the adsorption storage system and the heat and mass transfer process. Results demonstrate that the storage density (57.6 °C–25 °C) of adsorption gas storage is 43.46 kg/m3, which is 24.8 times of the CO2 density (1.75 kg/m3, 30 °C, 1 bar). If the adsorbents are heated above 160 °C, then the storage density will increase 3–4 times. The whole process is controlled by heat exchange efficiency. The heat exchange efficiency greatly affects the response time of the system during the application.

A calcium looping system powered by renewable electricity for long-term thermochemical energy storage, residential heat supply and carbon capture

Affordable long-term energy storage and CO2 capture technique are imperative to developing the future carbon–neutral energy system. This paper proposed a calcium looping system powered by excess renewable electricity to achieve long-term thermochemical energy storage, residential heat supply and carbon capture. The system can be constructed with industrial equipment and exploit natural, abundant and cheap limestone as the circulating material. The electrical calciner is designed to charge the energy and produce the high-pressured CO2 during the valley of the electricity grid, while the carbonator side is primarily driven by the discharged thermochemical energy and on-demand coordinates the heat network along with the carbon capture. The HEATSEP framework is adopted to optimize heat transfer processes and operating conditions for deriving the most favorable system configuration in the energy and economic aspects. Compared to the reference plant with electric boilers and short-term heat storage tanks, an energy penalty of around 32.3% total energy percentage points should be paid to drive long-term energy storage and carbon capture. The energy penalty is attributed to thermal losses in the calciner and heat exchanger networks, chemical energy lost by the make-up flow of fresh limestone, CO2 compression for storage and auxiliary power for solid/fluid circulations. Due to a comparable total plant investment cost to the reference plant, the proposed system achieves the CO2 avoidance cost of 111.1 RMB/tonCO2, showing some competitiveness over current post-combustion carbon capture techniques. The techno-economic competitiveness of the proposed system can be further strengthened by replacing natural or synthetic Ca-based materials with high cycling performance instead of limestone, as well as extending applicable occasions to achieve almost year-round operation.

An innovative biomass-fueled gas turbine-ORC system equipped with electrochemically mediated amine regeneration (EMAR) for CO2 capture

CO2 capture technologies can contribute to reducing pollutant emissions and achieving a ‎cleaner environment. ‎Despite the trend toward reducing fossil fuel use, many of the suggested alternatives emit substantial amounts of CO2, including biomass gasifiers. This study presents a novel hybrid power generation system consisting of a biomass gasifier, a gas turbine, an ORC cycle, an electrochemically mediated amine regeneration (EMAR) technology to capture CO2 emissions, and, for the final storage, a CO2 compressor. Clean production is the primary goal of this study, in which a large amount of energy is produced with a near zero CO2 emission, using EMAR CO2 capture technology. An energy-based model is presented and validated carefully. Two scenarios are proposed to assess the system feasibility encompassing parametric and optimization studies. During the parametric study, the influence of the three subsystems' (gas turbine, biomass gasifier, EMAR) parameters is investigated on three energy efficiencies, defined to evaluate the proposed system performance. Lastly, the hybrid system is optimized via Genetic algorithm considering each efficiency as the objective. Results illustrate that the maximum obtainable efficiency of the system without utilizing EMAR can reach up to 33.65%. Whereas utilizing EMAR and CO2 compressing lowers the efficiency by 6–8% (by point).