Solvent Regeneration Energy Research Articles

Optimization of the Post-Combustion CO2 Capture Process Applied to Cement Plant Flue Gases: Parametric Study with Different Solvents and Configurations Combined with Intercooling

The present study is related to Aspen HysysTM simulations of the post-combustion CO2 capture process by absorption-regeneration. More precisely, the purpose of the works is to quantify the interest in terms of solvent regeneration energy of combining alternative process configurations (“Lean/Rich Vapor Compression” (L/RVC)) with an intercooled absorber (ICA). Water-wash sections were also added in the flow sheet for a more accurate simulation of the global process. The Norcem Brevik cement plant flue gas was taken as case study and three different solvents were considered, namely: monoethanolamine (MEA), piperazine (PZ) and piperazine-methyldiethanolamine (MDEA) blend. For each configuration and solvent, parametric studies were carried out in order to identify the operating conditions ((L/G)vol., intercooling temperature, stages and flow rate) minimizing the solvent regeneration energy. Total equivalent thermodynamic work and utilities costs were also analyzed. It could be highlighted that implementing ICA leads to supplementary energy savings. More precisely, the MDEA+PZ blend with RVC+ICA configuration leads to a regeneration energy of 2.19 GJ/tCO2 (35% energy savings in comparison with MEA 30% conventional configuration), the utilities costs being also lower (24.5% savings) in comparison with the same reference case. As perspectives, an other blend will be investigated (namely DEA + PZ) with the same configurations (LVC or RVC + ICA).

Initial solubility & density evaluation of Non-Aqueous system of amino acid salts for CO2 capture: potassium prolinate blended with ethanol and ethylene glycol

Amine scrubbing is the state of the art technology for CO2 capture, and solvent selection can significantly reduce the capital and energy cost of the process. Higher energy requirement for aqueous amine based CO2 removal process is still a most important downside preventive its industrial deployment. Therefore, in this study, novel non-aqueous based amino acid salt system consisting of potassium prolinate, ethanol and ethylene glycol has been studied. This work presents initial CO2 solubility study and important physical properties i.e. density of the studied solvent system. Previous work showed that non-aqueous system of potassium prolinate and ethanol has good absorption rates and requires lower energy for solvent regeneration. However, during regeneration, solvent loss issues were found due to lower boiling point of the ethanol. Therefore, ethylene glycol was added into current studied system for enhancing the overall boiling point of the system. The good initial CO2 solubility and low density of studied solvent system offers several advantages as compared to conventional amine solutions.

Evaluating CO2 desorption performance in CO2-loaded aqueous tri-solvent blend amines with and without solid acid catalysts

To enhance the energy efficiency of the CO2 desorption process, the regeneration behaviors of the CO2-loaded 6 M MEA-AMP-PZ (monoethanolamine, 2-amino-2-methyl-1-propanol and piperazine) tri-solvent blends with different AMP/PZ molar ratios with four different solid acid catalysts (H-ZSM-5, γ-Al2O3, SAPO-34 and SO42−/TiO2) and a blank at 96 °C were investigated in terms of CO2 desorption rate, cyclic capacity and relative heat duty. For the no-catalytic runs, the results showed that all the tri-solvent blended amines greatly increased CO2 desorption rate, cyclic capacity and decreased the relative heat duty in comparison with 5 M MEA. The 13C NMR analysis indicated that the 3 M MEA-2.5 M AMP-0.5 M PZ blend with the highest AMP/PZ ratio produced the largest amount of bicarbonate and less carbamate, which resulted in the best desorption performance. With regard to catalyst, when the solid acid catalysts were introduced, the regeneration performance of the blend was further improved. The best of the blends along with H-ZSM-5 provided the combination with the best performance in CO2 desorption, and reduced the relative heat duty by 61.6% as compared to 5 M MEA without catalyst (100%). Five relevant physicochemical properties of the catalyst were obtained and used to better understand the catalytic regeneration process. A possible catalytic CO2 desorption mechanism was analyzed. The results revealed that the mesopore surface area coupled with total acid sites of the catalyst had the most positive influence on improving the CO2 desorption performance. Findings from this work imply that the combination of solid acid catalyst with tri-solvent blended amines is a promising alternative method for further reduction of solvent regeneration energy requirement.

Comparison of various configurations of the absorption-regeneration process using different solvents for the post-combustion CO2 capture applied to cement plant flue gases

Carbon Capture Utilization or Storage (CCUS) has gained widespread attention as an option for reducing CO2 emissions from power plants but specific developments are still needed for the application to cement plants. More precisely, the post-combustion CO2 capture process by absorption-regeneration is the more mature technology but its cost reduction is still necessary. The present study is focusing on Aspen Hysys™ simulations of different CO2 capture process configurations (namely “Rich Solvent Recycle” (RSR), “Solvent Split Flow” (SSF), “Lean/Rich Vapor Compression” (L/RVC)) applied to the flue gas coming from the Norcem Brevik cement plant (taken as case study) and using three different solvents, namely: monoethanolamine (MEA), piperazine (PZ) and piperazine-methyldiethanolamine (MDEA) blend. For each configuration and solvent, different parametric studies were carried out in order to identify the operating conditions ((L/G)vol., split fraction, flash pressure variation, etc.) minimizing the solvent regeneration energy. Total equivalent thermodynamic works and utilities costs were also analyzed. It was shown that the configurations studied allow regeneration energy savings in the range 4–18%, LVC and RVC leading to the higher ones. As perspectives, other configurations and combination of configurations will be considered in order to further reduce the energy consumption of the process.

Conventional and advanced exergy analysis of post-combustion CO2 capture based on chemical absorption integrated with supercritical coal-fired power plant

Post-combustion CO2 capture (PCC) based on chemical absorption is one of the strategic technologies identified to reduce emission of greenhouse gases from various power plants. However, PCC based on chemical absorption incurs serious energy penalty due to the use of energy for solvent regeneration. Reducing the energy/exergy use in this process can reduce energy penalties. It is also important to increase the efficiency of the CO2 capture system. This study focuses on: steady state simulation of a closed-loop PCC plant integrated with supercritical coal-fired power plant (SCPP); conventional and advanced exergy analyses of the PCC; and case studies on strategies to reduce exergy destruction in the system components. The conventional exergy analysis evaluates the amount and location of exergy destruction within the whole system. The advanced exergetic analysis estimates the sources of the exergy destruction in individual component or the whole system and the potential for reducing it. The results show that the energy consumption and the efficiency of the PCC process can be improved by recovering the avoidable exergy destroyed in the system components. This is important because for every 1% reduction in the energy required for capture, costs can be lowered to between 0.7–1%.

Experimental investigation on efficient carbon dioxide capture using piperazine (PZ) activated aqueous methyldiethanolamine (MDEA) solution in a packed column

The rising proportion of anthropogenic CO2 and its several adverse effects in the atmosphere through global warming has become an issue of widespread attention to find out an effective and highly efficient CO2 capture technique towards mitigation of greenhouse gas emission. The current investigation characterizes on CO2 capture technique through post combustion method by means of aqueous (MDEA+PZ) blend as an absorbent to arrest the power plant exhaust. The absorption study has been executed in a packed column over extensive variation of temperature and CO2 partial pressure besides physicochemical properties viz. viscosity and density determination. The CO2 absorption and stripping performances are evaluated under the influence of various process parameters. In this study PZ plays a significant role of reaction rate accelerator through gradual increase in mass percentage from 2 to 10wt% maintaining a constancy of the entire solvent strength of 30wt% in aqueous blend. The highest specific rate of absorption and maximum CO2 loading attained in aqueous (MDEA+PZ) blend having the PZ ratio of 10wt% are (30.16×10−6) kmolm−2s−1 and 0.78mol CO2 respectively. The maximum regeneration efficiency of 92.24% has been observed in aqueous (MDEA+PZ) blend containing least PZ fraction (2wt%). The necessary amount of heat energy for solvent regeneration of aqueous (MDEA+PZ) blend has also been calculated and the estimated reboiler heat duty is within a range of 3.0–4.1MJ/kg CO2. Hence, aqueous (MDEA+PZ) blend could be an effective absorbent for CO2 capture from flue gas through absorption-desorption process.

Liquid-solid phase-change absorption of acidic gas by polyamine in nonaqueous organic solvent

Acidic gas capture by traditional aqueous amine solution requires a plenty of energy for solvent regeneration. A phase-change capture system was considered to be a promising alternative because only the CO2-rich phase needs to be recovered and the CO2-lean phase can be reused directly without disposal, improving the energy utilization efficiency. Based on this principle, the phase-change absorption behavior of linear polyamines including ethylenediamine (EDA), diethylenetriamine (DETA), triethylenetetramine, tetraethylenepentamine, and cyclic diamines including piperazine (PZ) and triethylene diamine (DABCO) in organic solvents was investigated in the present work. The result indicated that polyamines could react with CO2 to form carbamate precipitates except DABCO, which had no absorption effect. For the absorption of SO2, polyamines could react with SO2 and water from air to form rare organic sulfites except DABCO, which merely absorbed two SO2 molecules to form the electron transfer complex DABCO·(SO2)2. The peculiar absorption behavior of DABCO for CO2 and SO2 implied that it is a highly selective phase-change desulfurizer for flue gas. The sequence of decomposition temperature for the CO2 capture product was DETA-carbamate>EDA-carbamate>PZ-carbamate, while for the SO2 capture product was [EDAH2][SO3]>[PZH2][SO3]·H2O>DABCO·(SO2)2.

Simulations of various Configurations of the Post-combustion CO2 Capture Process Applied to a Cement Plant Flue Gas: Parametric Study with Different Solvents

In order to reduce the operating costs of post-combustion CO2 capture process by absorption-regeneration using amine based solvents for its application in the cement industry, the present study was focused on the Aspen HysysTM simulation of different CO2 capture process configurations (namely conventional configuration, “Rich Solvent Recycle” (RSR), “Solvent Split Flow” (SSF) and “Lean/Rich Vapor Compression” (L/RVC)) applied to the flue gas coming from the Norcem Brevik cement plant in Norway and using three different solvents, namely: monoethanolamine (MEA), piperazine (PZ) and piperazine-methyldiethanolamine (MDEA) blend. For each configuration and solvent, a parametric study was carried out in order to identify the specific operating conditions (flow rates ratio (L/G), split fraction, injection stage in the columns, flash pressure, etc.) minimizing the solvent regeneration energy and highlighting the energetical interest of such configurations. Energy savings of almost 30% were estimated with the RVC configuration and MDEA+PZ blend. A decrease of the condenser cooling energy was also noted. As perspectives, other configurations (such as InterCooled Absorber (ICA)) and combination of configurations will be considered in order to further reduce the energy consumption of the process. In addition to OPEX calculations, the consequence in terms of CAPEX of implementing each process configuration will have to be estimated for evaluating more precisely the global economic interest of using alternative process configurations for the application to cement plant flue gases.

Study of the Post-combustion CO2 Capture Applied to Conventional and Partial Oxy-fuel Cement Plants

The present work was focused on the application in the cement industry of the post-combustion CO2 capture technology using amine-based chemical absorption. Besides conventional conditions, investigations were performed on a concept called “partial oxy-fuel combustion” applied to cement kilns leading to more CO2-concentrated flue gas (yCO2 up to 60%) and allowing to reduce the solvent regeneration energy consumption. The purpose of the study was to highlight and evaluate this reduction. Firstly, the performances of several solvents were evaluated thanks to screening tests at lab (results with a cables-bundle contactor) and micro-pilot (absorption-regeneration unit) scales considering different CO2 contents (yCO2,in = 20-60 vol.%). Simple and blended solvents were tested in such conditions, such as primary and secondary alkanolamines (benchmark Monoethanolamine (MEA), Diethanolamine (DEA) and cyclical di-amine (Piperazine (PZ)). It was shown that the use of activated solutions (such as DEA 30 wt.% + PZ 5 wt.%) presented particularly high absorption performances both in conventional and high CO2 contents conditions. Secondly, Aspen HysysTM simulations were carried out considering cement plant flue gas. For MEA 30 wt.% an increase of yCO2 from 20% to 44% leads to a 26% decrease of the regeneration energy (from 3.36 to 2.48 GJ/tCO2), which is clearly encouraging. As perspectives, new absorption-regeneration tests at micro-pilot scale and simulations will be performed with other solvents in order to have a more global evaluation of the interest of partial oxy-fuel conditions for the cement industry.

Rate-based Modelling and Validation of a Pilot Absorber Using MDEA Enhanced with Carbonic Anhydrase (CA)

The great paradox of the 21st century is that we must meet the increasing global demand for energy and products while simultaneously mitigating the climate change. If both these criteria are to be met, carbon capture and storage is an imperative technology for sustainable energy infrastructure development. Post-combustion capture is a mature capture technology, however, to make it economically attractive, design of innovative solvents and process optimization is of crucial importance. An example for promising solvent is MDEA enhanced with carbonic anhydrase (CA), due to its fast kinetics and low solvent-regeneration energy demand.The focus of this work is to develop a rate-based model for CO2 absorption using MDEA enhanced with CA and to validate it against pilot-scale absorption experiments. In this work, we compare model predictions to measured temperature and CO2 concentration profiles for different L/G ratios, lean CO2 loadings, gas CO2 content and packing height. We show that the developed model is suitable for CO2 capture simulation and optimization using MDEA and MDEA enhanced with CA. Furthermore, we investigate the accuracy of the General Method (GM) enhancement factor model for CO2 absorption/desorption using wetted-wall column data: 0 to 0.5 CO2 loading and temperatures between 298 and 328K. The present study represents a first step towards developing and optimizing a CA promoted MDEA CO2 capture process.

Advancement and new perspectives of using formulated reactive amine blends for post-combustion carbon dioxide (CO2) capture technologies

Abstract Chemical absorption using amine–based solvents have proven to be the most studied, as well as the most reliable and efficient technology for capturing carbon dioxide (CO2) from exhaust gas streams and synthesis gas in all combustion and industrial processes. The application of single amine–based solvents especially the very reactive monoethanolamine (MEA) is associated with a parasitic energy demand for solvent regeneration. Since regeneration energy accounts for up to three–quarters of the plant operating cost, efforts in its reduction have prompted the idea of using blended amine solvents. This review paper highlights the success achieved in blending amine solvents and the recent and future technologies aimed at increasing the overall volumetric mass transfer coefficient, absorption rate, cyclic capacity and greatly minimizing both degradation and the energy for solvent regeneration. The importance of amine biodegradability (BOD) and low ecotoxicity as well as low amine volatility is also highlighted. Costs and energy penalty indices that influences the capital and operating costs of CO2 capture process was also highlighted. A new experimental method for simultaneously estimating amine cost, degradation rate, regeneration energy and reclaiming energy is also proposed in this review paper.

A novel process for direct solvent regeneration via solar thermal energy for carbon capture

The energy for the solvent regeneration of post-combustion carbon capture (PCC) process is typically provided by steam bleeding from the power plant (PP) steam cycle. The energy penalty for steam bleeding results in serious reduction in the PP capacity estimated to be in the range of 10–40%. Power plant repowering or hybridization using solar-assisted PCC (SPCC) is a promising approach to satisfy carbon capture targets as well as PP load, concurrently. The drawback of this methodology is that notable amounts of solar energy are wasted during heat transfer from solar radiation to rich solvent.This paper presents a novel approach by eliminating the costly desorber system and using solar collector pipe (i.e. parabolic trough pipe) to directly heat the rich solvent and disassociate the bonds of CO2-solvent. This novel technology lowers the process capital expenditure, and also reduces the solvent regeneration energy bringing it close to its theoretical values. The elimination of the complex desorber column also increases the flexibility of the PP operation in response for market dynamics. A case-study for Sydney-Australia shows that in comparison with SPCC methodology, this state-of-the-art approach could notably improve the economics of the process and reduce the size of solar collector field (SCF).

Techno-economic analysis of mechanical vapor recompression for process integration of post-combustion CO2 capture with downstream compression

Post-combustion capture of CO2 using amine solvent is by far the most practical and mature technology, however, energy requirement for solvent regeneration still remains as the biggest obstacle to overcome. In this article, post-combustion CO2 capture process model was validated using experimental data of an existing test bed. Based on the validated model, mechanical vapor recompression (MVR) process is proposed which reduces thermal energy for solvent regeneration by recovering heat from compression process required for CO2 transportation. MVR process not only reduces the amount of steam extracted from the power plant, but can also serve as an interface between CO2 capture and compression for process integration. According to the simulation results, energy saving of 8.4% was observed in comparison with the base case, which is a conventional CO2 capture process followed by 2-stage compression. In addition to energy analysis, exergy analysis based on the 2nd law of thermodynamics and economic evaluation were performed to determine optimal operating condition of the MVR process.

Technical and Energy Performance of an Advanced, Aqueous Ammonia-Based CO2 Capture Technology for a 500 MW Coal-Fired Power Station.

Using a rate-based model, we assessed the technical feasibility and energy performance of an advanced aqueous-ammonia-based postcombustion capture process integrated with a coal-fired power station. The capture process consists of three identical process trains in parallel, each containing a CO2 capture unit, an NH3 recycling unit, a water separation unit, and a CO2 compressor. A sensitivity study of important parameters, such as NH3 concentration, lean CO2 loading, and stripper pressure, was performed to minimize the energy consumption involved in the CO2 capture process. Process modifications of the rich-split process and the interheating process were investigated to further reduce the solvent regeneration energy. The integrated capture system was then evaluated in terms of the mass balance and the energy consumption of each unit. The results show that our advanced ammonia process is technically feasible and energy-competitive, with a low net power-plant efficiency penalty of 7.7%.

Pilot‐scale evaluation of concentrated piperazine for CO2 capture at an Australian coal‐fired power station: duration experiments

AbstractDuration operation was completed as the final stage of evaluating concentrated piperazine as a CO2 capture solvent at the Tarong pilot plant. For the duration tests, a single operating set‐point was maintained for an extended period of time. The purpose of the duration tests was to monitor the formation of degradation products and the robustness of the solvent. Two duration tests were conducted that differed only in the regeneration temperature used (125 or 155 °C). Four hundred twenty‐five hours of operation were achieved on the solvent with a regeneration temperature of 125 °C. This was followed by a further 421 h of operation with a regeneration temperature of 155 °C, giving a total operating time on the solvent of 1700 h by the end of the project. For the duration experiments, roughly 500 tonnes of flue gas was treated, and approximately 70 tonnes of CO2 captured. The heat stable salt (HSS) measured in highest concentration was formate, with the rate of formation increasing with regeneration temperature. The effect of pre‐treatment could be seen with sulfate concentration in the solvent increasing sharply when caustic supply to the pre‐treatment column was interrupted. Despite the formation of degradation products in the solvent regeneration energy requirements were not notably effected. For operation up to 1700 h on a real coal flue gas, no loss of plant performance was observed. © 2015 Society of Chemical Industry and John Wiley & Sons, Ltd

Investigation of carbon dioxide capture with aqueous piperazine on a post combustion pilot plant – Part II: Parameter study and emission measurement

This paper continues the investigation of a 37.6wt% piperazine solution (7 molal) in a PCC-test facility on the power plant in Dürnrohr, Austria. The use of real power plant flue gas and the well-conceived dimensions of the test facility enable industry-related conditions for full scale applications. A minimum specific energy for solvent regeneration of 3.17GJ/tCO2 was determined in Part I of this paper. The optimal solvent flow rate is 20% lower in comparison to that of 30wt% MEA. Part II tries to reduce the energy consumption further by carrying out a detailed parameter study. Especially at high flue gas flow rates, piperazine shows a good performance because of its fast kinetics. If the maximum achievable flue gas flow rate of 120m3/h (F-factor ∼2Pa0.5) is set, the specific energy for solvent regeneration drops to 3GJ/tCO2. The fast kinetics has also a positive effect by reduction of the absorber height. Halving the absorber height still allows a performance similar to that of 30wt% MEA. Due to the high thermal stability, piperazine enables an operation with high desorber pressures. Higher desorber pressures, resulting in a lower CO2 compression work. In addition, the regeneration energy can be further reduced. An energy saving can also be achieved by the temperature reduction of the incoming flue gas. By operation with flue gases of a natural gas-fired boiler, the minimal energy consumption rises to 3.6GJ/tCO2. The optimal solvent flow rate decreases as with 30wt% MEA. An emission measurement shows a direct correlation between NH3 concentration of the treated flue gas and the solvent flow rate. Because of low water circulation in the water washing section, the NH3 emissions in the treated flue gas increase at high solvent flow rates.

CO2 Capture Modeling, Energy Savings, and Heat Pump Integration

While chemical engineers have designed amine-based CO2 capture systems since 1927, concern over anthropomorphic climate change sparked renewed interest in the 1980s. Subsequent research has led to significant advances such as well-fit property and thermodynamic models, rigorous models for unit operations, and improved process designs. The aim of this work is to summarize proposed process improvements and energy-saving schemes, including absorber intercooling, stripper interheating, stripper condensate rerouting, distributed cross heat exchanger, flash stripper, multipressure stripper, and heat pump integration. We present simulation examples demonstrating that energy-saving schemes must be considered together because of strong and complex interactions. We report an optimal process design integrating all of these improvements in Aspen Plus V8.5, and then evolutionally simplify the design through simulation results. In particular, we propose an optimum energy-saving design that uses an absorption-driven heat pump together with a distributed cross heat exchanger and a stripper vapor condensate rerouting to reduce both the cooling and the heating utility consumptions. The resulting predicted solvent regeneration energy is an absorption-driven heat pump for waste heat recovery with a predicted solvent regeneration energy of 1.67 (GJt/tonne CO2 captured). To our knowledge, this is the lowest solvent regeneration energy yet reported in the literature or patents.

Steady state simulation and exergy analysis of supercritical coal-fired power plant with CO2 capture

Integrating a power plant with CO2 capture incurs serious efficiency and energy penalty due to use of energy for solvent regeneration in the capture process. Reducing the exergy destruction and losses associated with the power plant systems can improve the rational efficiency of the system and thereby reducing energy penalties. This paper presents steady state simulation and exergy analysis of supercritical coal-fired power plant (SCPP) integrated with post-combustion CO2 capture (PCC). The simulation was validated by comparing the results with a greenfield design case study based on a 550MWe SCPP unit. The analyses show that the once-through boiler exhibits the highest exergy destruction but also has a limited influence on fuel-saving potentials of the system. The turbine subsystems show lower exergy destruction compared to the boiler subsystem but more significance in fuel-saving potentials of the system. Four cases of the integrated SCPP-CO2 capture configuration was considered for reducing thermodynamic irreversibilities in the system by reducing the driving forces responsible for the CO2 capture process: conventional process, absorber intercooling (AIC), split-flow (SF), and a combination of absorber intercooling and split-flow (AIC+SF). The AIC+SF configuration shows the most significant reduction in exergy destruction when compared to the SCPP system with conventional CO2 capture. This study shows that improvement in turbine performance design and the driving forces responsible for CO2 capture (without compromising cost) can help improve the rational efficiency of the integrated system.

A study of new absorbent for post-combustion CO2 capture test bed

Capture and storage of post combustion CO2 from fossil fuel power plants is the best technique that can be rapidly and safely employed for the control of greenhouse gas emissions. Test bed studies with highly efficient amine CO2 solvent (KoSol−4) developed by KEPCO Research Institute was performed. For the first time in Korea, evaluation of post-combustion CO2 capture technology to capture 2t-CO2/day from a slipstream of flue gas from a commercial scale coal-fired power station was performed. Based on a chemical absorption/regeneration process with KoSol−4, we have studied the effects of lean solvent flow rate, input location and inter-cooling of absorbent, pressure and temperature of stripper for process optimization. This optimization aimed to reduce the energy for solvent regeneration. The optimum point in flow rate of lean absorbents was 700kg/h in 350Sm3/h flue gas. And the regeneration energy using new solvent was 3.02GJ/t-CO2 in 90% CO2 removal, flue gas temperature of 40°C and stripper pressure of 0.35kgf/cm2. In addition, corrosion rate of the pilot plant were measured in six points. It is the largest as 40.52mpy in the bottom of the stripper tower.

Conceptual Design of a Novel CO2 Capture Process Based on Precipitating Amino Acid Solvents

Amino acid salt based solvents can be used for CO2 removal from flue gas in a conventional absorption–thermal desorption process. Recently, new process concepts have been developed based on the precipitation of the amino acid zwitterion species during the absorption of CO2. In this work, a new concept is introduced which requires the precipitation of the pure amino acid species and the partial recycle of the remaining supernatant to the absorption column. This induces a shift in the pH of the rich solution treated in the stripper column that has substantial energy benefits during CO2 desorption. To describe and evaluate this concept, this work provides the conceptual design of a new process (DECAB Plus) based on a 4 M aqueous solution of potassium taurate. The design is supported by experimental data such as amino acid speciation, vapor–liquid equilibria of CO2 on potassium taurate solutions, and solid–liquid partition. The same conceptual design method has been used to evaluate a baseline case based on 5 M MEA. After thorough evaluation of the significant variables, the new DECAB Plus process can lower the specific reboiler energy for solvent regeneration by 35% compared to the MEA baseline. The specific reboiler energy is reduced from 3.7 GJ/tCO2, which corresponds to the MEA baseline, to 2.4 GJ/tCO2, which corresponds to the DECAB Plus process described in this work, excluding the low-grade energy required to redissolve the precipitates formed during absorption. Although this low-grade energy will eventually reduce the overall energy savings, the evaluation of DECAB Plus has indicated the potential of this concept for postcombustion CO2 capture.