CO2 Capture Rate Research Articles

Dynamic operation and modelling of amine-based CO2 capture at pilot scale

This study combines pilot plant experiments and dynamic modelling to gain insight into the interaction between key process parameters in producing the dynamic response of an amine-based CO2 capture process. Three dynamic scenarios from the UKCCSRC PACT pilot plant are presented: (i) partial load stripping, (ii) capture plant ramping, and (iii) reboiler decoupling. These scenarios are representative of realistic flexible operation of non-baseload CCS power stations. Experimental plant data was used to validate a dynamic model developed in gCCS. In the capture plant ramping scenario, increased liquid-to-gas (L/G) ratio resulted in higher CO2 capture rate. The partial load stripping scenario demonstrated that the hot water flow directly affects reboiler temperature, which in turn, has an impact on the solvent lean loading and CO2 capture rate. The reboiler decoupling scenario demonstrates a similar relationship. Turning off the heat supply to the reboiler leads to a gradual decline in reboiler temperature, which increases solvent lean loading and reduces CO2 capture rate. The absorber column temperature profile is influenced by the degree of CO2 capture. For scenarios that result in lower solvent lean loading, the absorber temperature profile shifts to higher temperature (due to the higher CO2 capture rate).

Experimental Testing of a Bi-Functional Material Cu-Cao Composite within the Ca/Cu H2 Production Process

A novel CaO/CuO based composite material (53 wt% CuO/ 22 wt% CaO/ 25 wt% Ca12Al14O33), developed for combined CO2 capture and heat transfer for the Ca/Cu hydrogen production process, showed a maximum CO2 capture rate of 1.53*10-2 kmol CO2/h.kg material, at a linear gas velocity of 0.55 m/s when operating in a fixed bed reactor in presence of a commercial reforming catalyst during methane Sorption Enhanced Reforming (SER). The system was able to convert up to 2.4 kg CH4/h.kg catalyst, producing a gas stream with over 93 % vol. hydrogen (dry basis) at 10 bars for a steam to carbon molar ratio of 3.2.

A novel experimental apparatus for the study of low temperature regeneration CO2 capture solvents using hollow fibre membrane contactors

The design, capability and construction of a novel, experimental apparatus for the study of low temperature regeneration CO2 capture agents is presented. The decisions and challenges in developing a new experimental capability are discussed, as well as how it addresses the experimental intermediate between bench scale experiments and large, application specific projects. To demonstrate the utility and capability of the apparatus, a low temperature regenerating CO2 capture protic ionic liquid (PIL) solution – dimethylpropylenediamine acetate + 50% H2O – was used to remove CO2 from an incoming gas stream consisting of 10% (v/v) CO2 in air. SuperPhobic® 2.5 × 8 hollow fibre membrane contactors were used for both the absorption and regeneration processes. The loading-only experiment achieved pseudo steady state in approximately 12 min, achieving a pseudo steady-state mass transfer rate (Koverall) of (3.66 ± 0.2) × 10−5 m s−1, and a CO2 removal rate of 5.15 × 10−3 g m−2 s−1. This value is comparable to other ionic liquid CO2 capture agents such as 1-ethyl-3-methylimidazolium ethylsulfate that have also been measured under pseudo-steady state conditions. In continuous operation, where CO2 is absorbed and stripped in series, steady-state was achieved in approximately 15 h. Due to the higher concentration of CO2 in the liquid under steady-state conditions, the value of Koverall decreased to (1.80 ± 0.1) × 10−5 m s−1, with a CO2 removal rate of 2.89 × 10−3 g m−2 s-1. The effects of several parameters on the steady-state CO2 capture rate, namely vacuum pressure of regeneration and liquid flow through the contactor were studied. Several factors were found to affect the stability of the overall CO2 removal rate, including H2O loss from the aqueous solution. With the utility and flexibility of the designed system, we have demonstrated that PILs are certainly worthy of further investigation as CO2 capture agents for a range of applications.

Application of piece-wise linear system identification to solvent-based post-combustion carbon capture

Solvent-based post-combustion carbon capture (PCC) is currently the most promising method to reduce CO2 emission. To achieve a plant-wide controller for flexible operation, it is necessary to develop a data-driven model to understand the dynamic characteristics of PCC plant. This paper aims to: (i) carry out system identification to develop a data-driven model and (ii) provide insights into the nonlinear dynamics among the key variables from the PCC process in a wide operating range. These key variables include: CO2 capture rate, reboiler temperature, condenser temperature and lean solvent temperature. Pilot-scale PCC process implemented in gCCS was used to generate simulation data for system identification and model comparison. Linear single-input-single-output (SISO) transfer function models were firstly developed at different capture rates. Open loop step tests on identified models were then introduced to report the dynamics of key variables in various operating conditions and to indicate the level of system nonlinearity graphically. The nonlinearity analysis was carried out to investigate the system nonlinearity distribution in a quantitative manner. Based on the nonlinearity analysis, a multi-input-multi-output (MIMO) piece-wise model was proposed to simulate the nonlinear characteristics of PCC plant. The piece-wise model shows a satisfactory agreement with gCCS simulation data. Results of this study successfully demonstrate the nonlinear behavior of the solvent-based PCC process, which can be applied in the design of flexible plant-wide controllers.

Nonlinearity Analysis and Multi-Model Modeling of an MEA-Based Post-Combustion CO2 Capture Process for Advanced Control Design

The monoethanolamine (MEA)-based post-combustion CO2 capture plant must operate flexibly under the variation of the power plant load and the desired CO2 capture rate. However, in the presence of process nonlinearity, conventional linear control strategy cannot achieve the best performance under a wide operation range. Considering this problem, this paper systematically studies the multi-model modeling of the MEA-based CO2 capture process for the purpose of (1) implementing well-developed linear control techniques to the design of an advanced controller and (2) achieving a wide-range flexible operation of the CO2 capture process. The local linear models of the CO2 capture process are firstly established at given operating points using the method of subspace identification. Then the nonlinearity distribution at different loads of an upstream power plant and different CO2 capture rates is investigated via the gap metric. Finally, based on the nonlinearity investigation results, the suitable linear models are selected and combined together to form the multi-model system. The proposed model is validated using the measurement data, which is generated from a post-combustion CO2 capture model developed in the go-carbon capture and storage (gCCS) simulation platform. As the proposed multi-linear model has a simple mathematical expression and high prediction accuracy, it can be directly employed as the control model of a practical advanced control strategy to achieve a wide operating range control of the CO2 capture process.

When to invest in carbon capture and storage: A perspective of supply chain

Abstract The purpose of this study is to investigate the investment threshold of carbon capture and storage (CCS) project from the perspective of supply chain, overcoming the limitations of previous works regarding this topic mainly from a single investor’s perspective. An analytical real options model was firstly presented for the scenario of centralized decision making, then the model was extended by integrating the real options theory with the game theory to examine the CCS investment threshold for the scenario of dual-echelon supply chain. An interesting finding is that CCS investment requires a much higher threshold under the dual-echelon supply chain than that under the centralized scenario, and this finding is consolidated by a numerical example simulation. Furthermore, the results of the numerical simulation indicated that the CCS investment threshold is positively affected by carbon price volatility, CO2 capture rate and the transfer payments coefficients, while negatively affected by capital subsidy. These conclusions can provide theoretical foundation for decision-making of CCS investment and related policy-making.

Duplex Pd/ceramic/Pd composite membrane for sweep gas-enhanced CO2 capture

Supported, thin-layered Pd membranes are promising tools for pre-combustion carbon capture because they can deliver simultaneously high-pressure CO2 and H2 streams as needed for sequestration and power generation, respectively. Moreover, the diluent required for the gas turbine fuel can be advantageously added as sweep gas in the membrane separator to boost H2 permeation. A composite membrane has been prepared with Pd layers on both sides of a porous ceramic tube to eliminate the mass transfer resistance resulting from sweep gas diffusion into the support of conventional Pd/ceramic membranes. The H2 permeability of the Pd/ceramic/Pd membrane (1.01 ×10−8 mol m−1 s−1 Pa−0.5 at 773 K) is similar to that of a supported single Pd layer membrane but its H2/N2 selectivity (18033) is enhanced by an order of magnitude at 773 K and ΔP = 500 kPa. Intriguingly, the selectivity of the double Pd layer membrane improves with increasing pressure difference ΔP while that of Pd/ceramic membranes declines. This unusual pressure dependence originates from the elevated pressure within the ceramic of the double Pd layer membrane. The sweep gas-induced mass transfer resistance grows rapidly with increasing permeate pressure and sweep gas amount attenuating the single gas H2 flux of the Pd/ceramic membrane by 67% at 1 MPa permeate pressure. This resistance remains significant under CO2 capture conditions albeit concentration polarization on the feed side has an even stronger permeation-retarding effect in that situation. The CO2 capture rate and purity benefit greatly from the enhanced high-pressure H2 selectivity of Pd/ceramic/Pd membranes which renders them attractive tools for any kind of H2 separation task.

Comparative analysis of transport and storage options from a CO2 source perspective

This study evaluated integrated CCS costs from the perspective of a CO2 source. A source will have captured CO2 requiring suitable storage and affordable transportation between source and storage. Capture, transport, and storage are the links of the CCS value chain. For this study, capture costs were modeled for six hypothetical sources (various industrial and power-generation facilities) with annual CO2 capture rates ranging from 0.65 to 3.90 million tonnes (Mt). Seven storage reservoirs located in the Appalachian, Illinois and Gulf Coast Basins—and of various quality with respect to CO2 storage—were modeled: two within the Rose Run Formation, three within the Mount (Mt.) Simon Formation, one in the Lower Tuscaloosa Formation, and one in the Frio Formation. Storage costs were calculated with the FE/NETL CO2 Saline Storage Cost Model for the seven selected storage reservoirs under dome and regional dip structural settings. For transportation, a dedicated pipeline system and a trunkline pipeline system were modeled. Transportation costs from source to storage reservoirs were evaluated using the FE/NETL CO2 Transport Cost Model. A source may not always be able to find suitable proximal storage. Low CCS costs reflect a source’s mass of captured CO2 finding suitable storage within an affordable transportation distance. Economies of scale are present in each link of the CCS value chain. These economies of scale are limited with respect to storage or the distance captured CO2 can be transported to storage.

Assessment of the improvement of chemical looping combustion of coal by using a manganese ore as oxygen carrier

Finding suitable low-cost materials to be used as oxygen carrier in Chemical Looping Combustion (CLC) of coal is a key issue to achieve the CO2 capture at low economic cost. Recently, a Mn-ore from Gabon has been identified as an alternative to the state of the art of oxygen carriers based on minerals or wastes with high iron content. This Mn-ore showed a high reactivity and a long particle lifetime during batch characterization to be considered as a suitable oxygen carrier. To evaluate the potential of this material in CLC, this work analyses the behaviour of the Mn-ore during continuous combustion of a bituminous coal in a 0.5 kWth CLC unit. The CLC process was evaluated and the effect of the main operating variables - such as fluidizing medium, oxygen carrier circulation rate, temperature, and solids inventory in the fuel reactor - on the combustion efficiency and CO2 capture was investigated. A direct relation between the char conversion rate and the CO2 capture is given, being mainly affected by the mean residence time of solids and temperature in the fuel reactor. The use of a carbon separation system with separation efficiency above 90% would be required to achieve CO2 capture rates higher than 95%. Total oxygen demand values as low as 4.5% were found when optimal operating conditions were selected, mainly being related to oxygen carrier to fuel ration higher than ϕ > 3. At these conditions, the Mn-ore material showed similar combustion efficiencies than other Fe-based low-cost materials previously tested, but with higher CO2 capture rates.

Multiobjective optimization of microalgae (Chlorella sp.) growth in a photobioreactor using Box‐Behnken design approach

AbstractThis study investigates a parameter optimization approach to maximize the specific growth rate of the Chlorella vulgaris microalgae species, its biomass productivity, and CO2 capture rate. For this purpose, the Box‐Behnken experimental design technique is applied with temperature, nitrogen to phosphorus ratio, and light‐dark cycle per day, as the growth controlling parameters. For each response, a quadratic model is developed separately describing the algal specific growth rate, biomass productivity, and CO2 capture rate, respectively. The maximum specific growth rate of 0.84 d−1 is obtained at 25 °C, with a nitrogen to phosphorus ratio of 3.4:1, and light‐dark cycles of 24/0 h. Maximum biomass productivity of 147.3 mg L−1 d−1 is found at 30 °C, with a nitrogen to phosphorus ratio of 3:1, and light‐dark cycles of 12/12 h. In addition, the maximum CO2 capture rate of 159.5 mg L−1 d−1 is also obtained at 30 °C, with a nitrogen to phosphorus ratio of 4:1, and light‐dark cycles of 23/1 h. Finally, a multi‐response optimization method is applied to maximize the specific growth rate, biomass productivity, and CO2 capture rate, simultaneously. The optimal set of 30 °C, a nitrogen to phosphorus ratio 3:1, and light‐dark cycles 16/8 h, provide the maximum specific growth rate of 0.66 per day, biomass productivity of 147.6 mg L−1 d−1, and CO2 capture rate of 141.7 mg L−1 d−1.

Flexible operation of post-combustion solvent-based carbon capture for coal-fired power plants using multi-model predictive control: A simulation study

Solvent-based post-combustion CO2 capture plant has to be operated in a flexible manner because of its high energy consumption and the frequent load variation of upstream power plants. Such a flexible operation brings out two objectives for the control system: i) the system should be able to change the CO2 capture rate quickly and smoothly in a wide operating range; ii) the system should effectively remove the disturbances from power plant flue gas. To achieve these goals, this paper proposed a multi-model predictive control (MMPC) strategy for solvent-based post-combustion CO2 capture plant. Firstly, local models of the CO2 capture plant at different operating points are identified through subspace identification method. Nonlinearity analysis of the plant is then performed and according to the results, suitable local models are selected, on which the multi-model predictive controller is designed. To enhance the flue gas disturbance rejection property of the CO2 capture plant and attain a better adaption to the power plant load variation, the flue gas flow rate is considered in the local model identification as an additional measured disturbance, thus the predictive controller can calculate the optimal control input even in the case of flue gas flow rate variation. Simulation results on an MEA-based CO2 capture plant developed on gCCS show the effectiveness and advantages of the proposed MMPC controller over wide range capture rate variation and power plant flue gas variation.

Study on the use of an imidazolium-based acetate ionic liquid for CO2 capture from flue gas in absorber/stripper packed columns: Experimental and modeling

In the present work, 1-Ethyl-3-methylimidazolium acetate ([Emim][Ac]) ionic liquid (IL) has been considered for experimental and theoretical investigation of post-combustion carbon dioxide (CO2) capture from flue gas. The absorption and stripping of CO2 into [Emim][Ac] IL has been studied in a typical absorber/stripper system that randomly packed with Raschig ring at absorption pressures of 5–8 bar, absorption temperatures of 298.15–338.15 K and stripping conditions of 1.5 bar in temperature range 363.15–398.15 K. A mathematical model was developed for absorption and stripping processes based on mass transfer concepts and Peng–Robinson equation of state (PR EOS). The validity of the model was verified via comparison of the results achieved by the model with data taken from the experiments performed in this work and VLE data given in the literature. The impacts of parameters such as absorption/stripping pressure and temperature on the performance of CO2 capture, the sorbent flow rate and energy demand at selected operating conditions and specified CO2 capture rates were examined. The experimental tests showed that the recovered CO2 from the stripper column was pure. The results demonstrated that the energy requirement for the CO2 capture IL-based process is about 4890 kW or 2.75 GJ/t CO2. It was also found that the degradation rate of ion liquid is 3.78 wt.% of circulated IL. Using the enhancement factor obtained based on experimental results, the pseudo-first order reaction constant of the CO2 + [Emim][Ac] IL system was estimated. By fitting the kinetics data into Arrhenius equation, the activation energy and frequency factor of the reaction rate constant were found to be 10.317 kJ/mol and 1545 s−1, respectively.

Experimental study of the adsorber performance in a multi-stage fluidized bed system for continuous CO2 capture by means of temperature swing adsorption

Most recently, a new reactor design of a continuous temperature swing adsorption (TSA) CO2 capture process has been proposed by the authors of this work. The reactor design incorporates interconnected multi-stage fluidized bed columns that act as adsorber and desorber in the TSA process. In the course of this work, a comprehensive parameter variation was performed in the TSA bench scale unit, to study the adsorber performance. Results show that by decreasing the operating temperatures in the adsorber to 42 °C, the dynamic CO2 loading of the adsorbent could be increased to 7.4 wt%. The flexibility of the process was investigated in respect to different CO2 concentrations of the treated flue-gas as well as different adsorber feed-gas velocities. Increasing the CO2 concentrations of the adsorber feed-gas leads to an increase of the CO2 capture rate and dynamic CO2 loading of the adsorbent. At the maximum CO2 concentration of 12 vol%CO2, the capture rate reached its maximum of 64 kgCO2·day−1. Furthermore, the flue-gas feeding rate could be increased to 0.87 m·s−1 which successfully demonstrated a turndown ratio of 2.7. However, large gas bubbles observed at adsorber feed-gas velocities exceeding 0.69 m·s−1 make insufficient gas-solids contact likely, which in turn explains a reduction of the dynamic CO2 loading of the adsorbent at these conditions. For high CO2 feeding rates, the capture efficiency dropped because of an insufficient heat transfer surface area and a limitation in the achievable sorbent circulation rates. In conclusion, the parameter study revealed a high operating flexibility of the TSA CO2 capture process and delivered a valuable basis for further improvements of the TSA reactor design.

CO2 capture by methanol, ionic liquid, and their binary mixtures: Experiments, modeling, and process simulation

The CO2 solubility data in the ionic liquid (IL) 1‐allyl‐3‐methylimidazolium bis(trifluoromethyl sulfonyl)imide, methanol (MeOH), and their mixture with different combinations at temperatures of 313.2, 333.2, and 353.2 K and pressures up to 6.50 MPa were measured experimentally. New group binary interaction parameters of the predictive universal quasichemical functional‐group activity coefficient (UNIFAC)‐Lei model, which has been continually advanced by our group, were introduced by correlating the experimental data of this work and the literature. The consistency between experimental data and predicted results proves the reliability of UNIFAC‐Lei model for CO2‐IL‐organic solvent systems. The newly obtained parameters were incorporated into the UNIFAC property model of Aspen Plus software to optimize a conceptual process developed for the purification of a CO2‐containing gas stream. The simulation results indicate that the use of IL either mixed with MeOH or purely considerably lowers the process power consumption and improves the process performance in terms of CO2 capture rate and solvent loss. © 2018 American Institute of Chemical Engineers AIChE J, 64: 2168–2180, 2018

Techno-economic and Environmental Analysis of Calcium Carbonate Looping for CO2 Capture from a Pulverised Coal-Fired Power Plant

Pulverised coal-fired (PC) power plants are among the major technologies used to generate electricity for power generation around the world. Coal-fired systems are generally considered to have high greenhouse gas emission intensities, apart from power plants that employ CO2 capture and storage (CCS) technology. As a technology option, calcium carbonate looping can be employed to remove carbon dioxide from the PC flue gas streams. Calcium carbonate looping is an attractive technology due to relatively low efficiency penalties. To better understand the performance characteristics and benefits of such a system integration, the ECLIPSE modelling software is used to perform a techno-economic analysis of the calcium carbonate looping system integrated in to an existing hard coal power plant. The overall system efficiency and the CO2 capture rate is evaluated based on a mass and energy balance calculation as part of the modelling. The capital costs, and maintenance and operating costs are estimated according to a bottom-up approach using the information gained through a mass and energy balance. The SimaPro software is used to perform a life cycle analysis of the capture technology to determine its environmental impact. The calcium carbonate looping system is also compared to other CCS solutions.

A power generation system with integrated supercritical water gasification of coal and CO2 capture

Abstract Supercritical water gasification (SCWG) is a promising clean coal technology. A new power generation system with integrated supercritical water gasification of coal andCO2 capture is proposed in this article. The gasification product consisted of H2, CO, CO2, CH4, and unreacted supercritical water is directly combusted with pure O2to provide heat for other units of the system, and the combustion product is used for power generation in turbines. The combustion product consists only of CO2 and H2O. Thus, the CO2 can be easily captured under atmospheric condition. The thermal efficiency of the system can reach 38.31%, while the CO2 capture rate is 100%. The energy and exergic balances are conducted. The exergy efficiency of the system is 38.56%. The system has advantages over most coal-fired power plants with oxy-combustion or post-combustion technologies and IGCC systems with pre-combustion technologies.

Process integration of coal fueled chemical looping hydrogen generation with SOFC for power production and CO2 capture

Chemical looping hydrogen generation (CLHG) is integrated with solid oxide fuel cell (SOFC) and combined cycle for high-efficiency power production with CO2 sequestration. To avoid energy penalty imposed by cryogenic air separation unit for oxygen production, the CLHG is directly fed by coal. The coal gasification and iron oxide reaction occur in the same reactor and no gaseous oxygen is used in gasification. The CLHG operates at an auto-thermal condition by solid circulation. The proposed system could achieve a net power efficiency of 41.59% at a baseline case. Sensitivity analysis is conducted as well on the basis of heat balance. Varying the temperatures of CLHG reactors and iron oxide circulation rate influences the system's efficiency. The increase of the fuel cell's temperature and fuel utilization factor favors the system's net power efficiency. In addition to high net power efficiency, the CO2 capture rate of the proposed system is up to ∼100%, resulting in a virtual carbon-free power plant.

Coal combustion with a spray granulated Cu-Mn mixed oxide for the Chemical Looping with Oxygen Uncoupling (CLOU) process

The Chemical Looping with Oxygen Uncoupling (CLOU) process is a form of Chemical Looping Combustion (CLC) technology that enables the combustion of solid fuels by means of oxygen carriers that release gaseous oxygen in the fuel reactor, i.e. with oxygen uncoupling capability. In recent years, tests have found several Cu-based, Mn-based and mixed oxide oxygen carriers with suitable properties for the CLOU process. Among them, Cu-Mn mixed oxides show high reactivity and high O2 equilibrium concentration at temperatures of interest for coal combustion. In this work, proof of concept was demonstrated by burning coal with Cu-Mn mixed oxides in a 1.5kWth CLOU unit for the first time. The effect of fuel reactor temperature, solids circulation flow, fluidization agent in the fuel reactor (inert N2 or steam as gasifying agent), and excess air in the air reactor on combustion efficiency and CO2 capture rate was analysed. The results showed that high combustion efficiency and CO2 capture are feasible using this material at relatively low fuel reactor operating temperatures. Therefore, the developed Cu-Mn mixed oxide was a suitable material for use as an oxygen carrier for the CLOU combustion of solid fuels. Optimum operating conditions were determined for this oxygen carrier with regard to the oxygen circulation rate and air reactor conditions for the regeneration of the oxygen carrier.

Post combustion CO2 capture in power plant using low temperature steam upgraded by double absorption heat transformer

In CO2 capture retrofit unit of existing coal-fired power plants, energy level mismatch between extraction steam from turbines and CO2 regeneration process always results in large exergy destruction and low thermal efficiency. Thus, a new CO2 capture system driven by double absorption heat transformer is proposed. Through the absorption heat transformer, low-temperature steam is upgraded into a higher energy level to match the temperature of CO2 regeneration. Also, flue gas heat is partly recovered to preheat the circulating water from CO2 capture process to further decrease system energy penalty. Aspen Plus 11.0 is used to simulate the system and parameters of key processes are validated by experimental values. It is shown that with 90% CO2 capture, the thermal efficiency of the power plant with proposed CO2 capture system is enhanced by 1.25 percentage points compared with traditional method. And the efficiency enhancement of the proposed system has a trend of increase first and then decrease with CO2 capture rate growth. For a 350MW coal-fired power plant, the optimum CO2 capture rate is 53.65% and the corresponding efficiency enhancement is 2.06 percentage points. Exergy analysis shows that the exergy destruction in CO2 separation and steam condensation process can decrease by 49.5% in the proposed system, and thereby the exergy efficiency is 1.85 percentage points higher than the conventional method. Furthermore, the cost of CO2 avoided and cost of electricity of the proposed system will be reduced by 10.7 $/t-CO2 and 1.9 $/MWh, respectively.

Optimization of Stage Numbers in a Multistage Fluidized Bed Temperature Swing Adsorption System for CO2 Capture

A dual loop multi stage fluidized bed process for continuous temperature swing adsorption (TSA) of CO2 is investigated using a thermodynamic process model. The operating case is chosen in accordance with a typical post-combustion CO2 capture process, i.e. 90% CO2 capture rate from a gas stream with 10 vol% CO2 content. Steam is used as the stripping agent on the desorber side. Adsorption thermodynamic data for an amine functionalized sorbent material are employed based on adsorption isotherm data from the literature using the Langmuir model. The optimum stage number on both adsorber and desorber side are investigated with respect to achieve high energy efficiency of the separation process. This means that a low stripping steam demand and a low solids circulation rate are desired. The results show that both solids circulation rate and stripping steam demand are low for configurations with multiple stages for both the adsorber and the desorber. The effect of additional stages is high at the beginning (especially up to three stages) and fades with the number of stages. It can be concluded for the chosen separation task and sorbent that a system with five stages on each side could represent a good compromise between effort and efficiency. Further work will focus on more detailed modeling and on experimental evaluation of the discussed process.