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1
Soriano, Allan N., Adonis P. Adornado, Angelica A. Pajinag, Diana Joy F. Acosta, Niel M. Averion, Gilfred M. Leron, and Vergel C. Bungay. "Multicriterial Analysis of Simulated Process of Post-Combustion Capture of Pure H2S and Mixtures of H2S and CO2 Using Single and Blended Aqueous Alkanolamines." ASEAN Journal of Chemical Engineering 15, no. 1 (October 1, 2015): 72. http://dx.doi.org/10.22146/ajche.49695.
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The paper evaluates the performance of the nine selected alkanolamines, namely, monoethanolamine (MEA), diethanolamine (DEA), monomethylethanolamine (MMEA), aminoethylethanolamine (AEEA), diisopropanolamine (DIPA), triethanolamine (TEA), dimethylethanolamine (DMEA), N-methyldiethanolamine (MDEA), and piperazine (PZ) for post-combustion capture of pure hydrogen sulfide (H2S) and mixtures of hydrogen sulfide and carbon dioxide (CO2) at different solvent mass flows: 500, 750, and 1000 kg/h using Aspen Plus® Version 7.2. The objective of the paper is to select the best chemical absorbent for each different criterion: percent H2S removal, percent H2S solvent carrying capacity, percent H2S retained in the lean solvent, percent CO2 and H2S removal, percent CO2 and H2S solvent carrying capacity, percent CO2 and H2S retained in the lean solvent. Based from the obtained results, piperazine is an absorbent that has a good potential for use as a single amine or in mixtures with other amines for capture of pure H2S and mixtures of H2S and CO2.
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Karunarathne, Sumudu S., Dag A. Eimer, and Lars E. Øi. "Physical Properties of MEA + Water + CO2 Mixtures in Postcombustion CO2 Capture: A Review of Correlations and Experimental Studies." Journal of Engineering 2020 (March 5, 2020): 1–17. http://dx.doi.org/10.1155/2020/7051368.
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The knowledge of physicochemical properties of a mixture of amine, water, and CO2 is beneficial in evaluating the postcombustion CO2 capture process and process equipment design. This study reviews the literature of density, viscosity, and surface tension measurements with the evaluated measurement uncertainties and proposed correlations for monoethanol amine (MEA), water, and CO2 mixtures. Adequate research has been performed to measure and develop correlations for pure MEA and aqueous MEA mixtures, but further studies are required for CO2-loaded aqueous MEA mixtures. The correlations fit measured properties with an acceptable accuracy, and they are recommended to use in process equipment design, mathematical modelling, and simulations of absorption and desorption.
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Ma, Yanqing, Yitao Liao, Yi Su, Baojie Wang, Yong Yang, Dong Ji, Hongwei Li, Huairong Zhou, and Dongliang Wang. "Comparative Investigation of Different CO2 Capture Technologies for Coal to Ethylene Glycol Process." Processes 9, no. 2 (January 22, 2021): 207. http://dx.doi.org/10.3390/pr9020207.
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The coal to ethylene glycol (CTEG) process has drawn much attention due to the serious conflict between supply and demand of ethylene glycol in China. However, it is inevitably accompanied by the problem of high CO2 emissions. Carbon capture is one of the most promising potential effective ways to address this issue. However, the CTEG process, integrated with carbon capture technology, will lead to energy and economic penalties. Thus, a comprehensive evaluation of CTEG process with different CO2 capture technologies is urgently needed. This study analyzed the technoeconomic performance of four CO2 capture alternatives for the CTEG process: Rectisol, mono-ethanol amine (MEA), chilled ammonia process (CAP) and dimethyl carbonate (DMC) technologies. Results show the energy consumption of CO2 capture of the Rectisol process is the lowest, 1.88 GJ/tCO2, followed by the DMC process, 2.10 GJ/tCO2, the CAP process, 3.64 GJ/tCO2, and the MEA process, 5.20 GJ/tCO2. The CO2 capture cost of the Rectisol process is lowest, CNY 169.5/tCO2, followed by the DMC process, CNY 193.2/tCO2, the CAP process CNY 232.6/tCO2, and the MEA process CNY 250.5/tCO2. As the Rectisol technology has the best comprehensive performance, it is the best option for CTEG industry in comparison with the MEA, CAP, and DMC technologies.
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Ho Choi, Jeong, Jong Tak Jang, Chan Young Park, Soung Hee Yun, Won Hee Jo, Jung-Hyun Lee, and Yeo Il Yoon. "The Piperidine-H2O-CO2 System for Sequestering Highly Concentrated CO2." Science of Advanced Materials 13, no. 5 (May 1, 2021): 755–70. http://dx.doi.org/10.1166/sam.2021.3895.
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The post-combustion capture (PCC) process using amines is one of the most representative technologies for separating CO2 from huge CO2 emisions. However, the achievement of reasonable costs for capturing CO2 requires continuous studies on absorbent development, process optimization, and energy saving. Among these, the absorbent development is the most essential factor in reducing the operating cost and equipment cost of the PCC process. In this study, piperidine (PD) solution is used as an alternative absorbent to overcome the disadvantage of commercial monoethanolamine (MEA) solution. The absorption rate, absorption capacity and regeneration energy of PD solution were measured to confirm its performance as an alternative absorbent. It was found that PD solution shows key advantages, compared with MEA solution. First, the overall mass transfer of CO2 in PD solution was 2.69 times faster than in MEA solution at 313 K. Second, PD solution was capable of absorbing 1.5 times more of CO2 than MEA solution. Third, the reboiler heat duty of PD solution showed 1.16 times better energy-efficiency than that of MEA because the sensible heat of PD was 75.8 kJ·mol−1 lower than that of MEA. From these results, PD solution is deemed to be a good alternative absorbent to replace MEA solution.
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Dinca, Cristian, Adrian Badea, and Horia Necula. "High Performance of the CFBC Pilot Plant with CO2 Chemical Absorption by Optimizing the Absorber Parameters." Advanced Materials Research 746 (August 2013): 3–8. http://dx.doi.org/10.4028/www.scientific.net/amr.746.3.
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The objective of this paper consists to identify the influence of absorption process temperature and pressure on the energy requirement of the CO2 chemical capture process. The study aimed to reducing CO2 emissions from coal combustion process in the circulating fluidized bed combustion (CFBC). The post-combustion CO2 capture process was analyzed using primary amine MEA in the following conditions: the ratio L/G was varied between 0.45..1.6 kgliquid/kggas keeping constant the flue gas flow and varying the solvent flow between 500 .. 1 600 kg/h. The CO2 capture process efficiency was maintained constant around 90%. For a concentration of 30% MEA in solution, it was observed that when the absorber solution temperature increasing from 32 to 49 °C, the amount of heat required for the solvent regeneration increased from 2.1 to 3.3 GJ/tCO2 according to the solvent pressure and flue gas pressure respectively. On the other hand, for varying the absorber solvent pressure in the range 1.1 .. 2.1 atm, the heat required by the process was not significantly influenced. Considering the same variation of the absorber solvent temperature, the rich loading solvent was increased from 0.43 to 0.57 mol CO2/mol MEA and consequently the MEA capacity of CO2 absorption from 0.3 to 0.422 molCO2/mol MEA.
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Chen, Pao-Chi, Hsun-Huang Cho, Jyun-Hong Jhuang, and Cheng-Hao Ku. "Selection of Mixed Amines in the CO2 Capture Process." C 7, no. 1 (February 24, 2021): 25. http://dx.doi.org/10.3390/c7010025.
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In order to select the best mixed amines in the CO2 capture process, the absorption of CO2 in mixed amines was explored at the required concentrations by using monoethanolamine (MEA) as a basic solvent, mixed with diisopropanolamine (DIPA), triethanolamine (TEA), 2-amino-2-methyl-1-propanol (AMP), and piperazine (PZ). Here, a bubble column was used as the scrubber, and a continuous operation was adopted. The Taguchi method was used for the experimental design. The conditional factors included the type of mixed amine (A), the ratio of the mixed amines (B), the liquid feed flow (C), the gas-flow rate (D), and the concentration of mixed amines (E). There were four levels, respectively, and a total of 16 experiments. The absorption efficiency (EF), absorption rate (RA), overall mass transfer coefficient (KGa), and scrubbing factor (ϕ) were used as indicators and were determined in a steady-state by the mass balance and two-film models. According to the Taguchi analysis, the importance of the parameters and the optimum conditions were obtained. In terms of the absorption efficiency (EF), the absorption rate (absorption factor) (RA/ϕ), and the overall mass transfer coefficient (KGa), the order of importance is D > E > A > B > C, D > E > C > B > A, and D > E > C > A > B, respectively, and the optimum conditions are A1B4C4D3E3, A1B3C4D4E2, A4B2C3D4E4, and A1B1C1D4E1. The optimum condition validation results showed that the optimal values of EF, RA, and KGa are 100%, 30.69 × 10−4 mol/s·L, 1.540 l/s, and 0.269, respectively. With regard to the selection of mixed amine, it was found that the mixed amine (MEA + AMP) performed the best in the CO2 capture process.
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Choi, Yoon-Seok, Deli Duan, Shengli Jiang, and Srdjan Nešić. "Mechanistic Modeling of Carbon Steel Corrosion in a Methyldiethanolamine (MDEA)-Based Carbon Dioxide Capture Process." Corrosion 69, no. 6 (January 3, 2013): 551–59. http://dx.doi.org/10.5006/0695.
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A predictive model was developed for corrosion of carbon steel in carbon dioxide (CO2)-loaded aqueous methyldiethanolamine (MDEA) systems, based on modeling of thermodynamic equilibria and electrochemical reactions. The concentrations of aqueous carbonic and amine species (CO2, bicarbonate [HCO3−], carbonate [CO32−], MDEA, and protonated MDEA [MDEAH+]) as well as pH values in the MDEA solution were calculated. The water chemistry model showed a good agreement with experimental data for pH and CO2 loading, with an improved correlation upon use of activity coefficients. The electrochemical corrosion model was developed by modeling polarization curves based on the given species's concentrations. The required electrochemical parameters (e.g., exchange current densities, Tafel slopes, and reaction orders) for different reactions were determined from experiments conducted in glass cells. Iron oxidative dissolution, HCO3− reduction, and MDEAH+ reduction reactions were implemented to build a comprehensive model for corrosion of carbon steel in an MDEA-CO2-water (H2O) environment. The model is applicable to uniform corrosion when no protective films are present. A solid foundation is provided for corrosion model development for other amine-based CO2 capture processes.
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Wang, Junyao, Liangxu Liu, Xuelan Zeng, and Kaixiang Li. "Solar-assisted CO2 capture with amine and ammonia-based chemical absorption：A comparative study." Thermal Science, no. 00 (2020): 149. http://dx.doi.org/10.2298/tsci191222149w.
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Intensive energy penalty caused by CO2 separation process is a critical obstacle for retrofitting power plant with carbon capture technology. Therefore, the concept of utilizing solar energy to assist solvent regeneration for post-combustion carbon capture power plant is proposed recently as a promising pathway to compensate the efficiency reduction derived from CO2 capture process. However, the feasibility of solar-assisted post-combustion (SPCC) technologies largely depends on the types of CO2 absorbent, categories of solar thermal collectors, areas of solar field and the integration of thermal energy storage system. Therefore, this paper conducts a comparative analysis on MEA-based and NH3-based SPCC power plants employing two types of solar collectors, i.e the vacuum tube (VT) and the parabolic through collector (PTC), with climate data of Tianjin City. Levelized costs of electricity and cost of CO2 removed are comparatively studied for both SPCC configurations. Results show that the proposed SPCC configurations are economically viable when the price of vacuum the tube (VT) is lower than 86.64$/m2 and 117.29$/m2 for the MEA-based and NH3-based SPCC power plant respectively. Meanwhile, the price of PTC should be less than 111.12$/m2 for the MEA-based and 114.51$/m2 for the NH3-based SPCC power plant. It is indicated that employing the VT for chilled NH3-based SPCC power plant offers a promising approach to reduce the energy penalty with attractive economic performance.
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Lee, Yunje, Junghwan Kim, Huiyong Kim, Taesung Park, Hailian Jin, Hoonsik Kim, Sangdo Park, and Kwang Soon Lee. "Operation of a Pilot-Scale CO2 Capture Process with a New Energy-Efficient Polyamine Solvent." Applied Sciences 10, no. 21 (October 29, 2020): 7669. http://dx.doi.org/10.3390/app10217669.
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A new blending recipe of a polyamine-based solvent for capturing post-combustion CO2 was proposed, and its performance and characteristics were investigated using a pilot-scale carbon capture process (PCCP). The proposed solvent is a blend of three types of amines and was designed to separate the solvent roles into those of a main amine, auxiliary amine, and reaction-rate-enhancing amine. Polyamine 3,3′-iminobis (N, N-dimethylpropylamine) was selected as the main amine given its ability to capture large amounts of CO2. 2-Amino-2-methyl-1-propanol was used as the auxiliary amine, with piperazine added as the reaction-rate-enhancing amine. This solvent was tested in a PCCP that can handle 150 Nm3/h of flue gas. The proposed solvent was found to operate stably while consuming substantially lower reboiler duty than the monoethanolamine (MEA) 30 mass% solvent.
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Li, Yuan, Qi Min Wang, and Pei Bin Wang. "Evaluation of Post-Combustion CO2 Capture Technologies." Advanced Materials Research 734-737 (August 2013): 1881–86. http://dx.doi.org/10.4028/www.scientific.net/amr.734-737.1881.
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This paper evaluates the results of two recent studies of advanced amine-based, post-combustion CO2 capture plant designs. The first study was conducted by the IEA Greenhouse Gas R&D Programme (IEA GHG), while the second study was conducted by Parsons for the US DOEs National Energy Technology Laboratory (NETL). Fluors improved monoethanolamine (MEA) process, known as the Econamine FG PlusSM technology, is utilised for both studies. Cost and performance estimates for both pulverized coal and natural gas-fired combined cycle plants are summarized. Differences between the design bases and assumptions for the two studies are discussed. The Econamine FG PlusSM technology, as an improved process in amine-based post-combustion CO2 capture described in this paper is leading to lower increases in the cost of electricity (COE). Both the DOE/Parsons and IEA GHG studies show that the increase is now down to 42 to 43% from as high as 60 to 70% indicated from previous studies for PC plants with CO2 capture.
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Gheni, Saba A., Mohammed F. Abed, Essam K. Halabia, and Saad R. Ahmed. "Investigation of carbon dioxide (CO2) capture in a falling film contactor by computer simulation." Oil & Gas Science and Technology – Revue d’IFP Energies nouvelles 73 (2018): 43. http://dx.doi.org/10.2516/ogst/2018020.
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In this work, mathematical models of carbon dioxide (CO2) absorption by monoethanolamine amine (MEA) in a falling film contactor are developed. The proposed models aim to predict conversion of the gas–liquid reaction along the contactor, gas–liquid interface temperature profile (axial and radial), liquid film thickness along the contactor length, axial and radial concentration profiles of reactants in liquid film, and axial and radial profiles of velocity in the liquid film. A code written in MatLab was used to obtain these profiles based on multi grid method through programming of kinetic and thermodynamic equations and physical properties of the absorption system. The mathematical model is validated by an experimental measurement based on absorption of CO2 gas by MEA solution. Four parameters are studied as independent variables namely, mole fraction of carbon dioxide in gaseous mixture, molar concentration of absorbent (MEA, volumetric flow rate of MEA, and its temperature. It is found that the entrance effect of the falling film contactor is related to axial distance from the contactor entrance exponentially: E=B0exp(−B1y) An optimization technique based on minimization of the sum of the squared error between the experimental and predicted composition of absorption process is used to obtain B0 and B1. It is found that reaction between carbon dioxide and MEA is instantaneous, and the axial conversion of carbon dioxide in the gas phase varies exponentially with the contactor length.
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Maneeintr, Kreangkrai, and Tawatchai Charinpanitkul. "A Comparative Performance of New Materials for Carbon Dioxide Removal in Absorption Process." Materials Science Forum 890 (March 2017): 176–79. http://dx.doi.org/10.4028/www.scientific.net/msf.890.176.
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Nowadays, the problems of climate change and global warming become more serious on environmental concern due to the higher amount of carbon dioxide in the atmosphere. Basically the main sources of carbon dioxide come from anthropogenic activities such as power generation, industries and so on. Currently, the effective technology to remove CO2 from these sources is absorption especially chemical absorption. Also, the chemicals used are one of the key parameters for effective CO2 removal. The widely used amine solutions are monoethanolamine (MEA) and diethanolamine (DEA). Nevertheless, they also have disadvantages such as low capacity, corrosion and high heat of regeneration thus making carbon capture technology more expensive. Therefore, many novel materials have been developed to improve the efficiency and compensate the disadvantages of some amines. Consequently, the objective of this work is to investigate the vapor-liquid equilibrium of CO2 in novel materials of 2-(methylamino) ethanol or 2-MAE and 3-Amino-1-Propanol or 3-AP at the temperature from 40 °C to 80 °C and CO2 partial pressures ranging from 5 to 100 kPa. The solubility results of CO2 in novel materials are compared with those of aqueous solution of MEA and DEA. For cyclic capacity, the results present that novel materials provide higher performance than that of MEA with less cost. This means that novel materials can save more energy and cost for solution regeneration and making it more economically viable.
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Raksajati, Anggit, Minh Ho, and Dianne Wiley. "Solvent Development for Post-Combustion CO2 Capture: Recent Development and Opportunities." MATEC Web of Conferences 156 (2018): 03015. http://dx.doi.org/10.1051/matecconf/201815603015.
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Chemical absorption is widely regarded as the most promising technology for post-combustion CO2 capture from large industrial emission sources with CO2 separation from natural gas using aqueous amine solvent system having been applied since the 1930s. The use of monoethanolamine (MEA) in CO2 absorption system possesses several drawbacks, such as high regeneration energy, high solvent loss, and high corrosion tendency. Various solvents have been developed for post-combustion CO2 capture application including the development of aqueous solvents and phase-change solvents. Some of these alternate solvents have been reported to have better solvent properties, which could improve the CO2 absorption system performance. This paper reviews key parameters involved in the design improvement of several chemical absorption process systems. In addition, some novel solvent systems are also discussed, for example encapsulated solvents systems. Some of the key solvent parameters that affect the capture performance, such as heat of reaction, absorption rate, solvent working capacity, solvent concentration, and solvent stability, are discussed in this paper, particularly in relation to the economic viability of the capture process. In addition, some guidelines for the future solvent development are discussed.
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Zaini, Nabilah, and K. S. N. Kamarudin. "An Investigation of Carbon Dioxide Sequestration on Amine–Modified Kenaf: Adsorption Isotherm Study." Advanced Materials Research 1125 (October 2015): 327–31. http://dx.doi.org/10.4028/www.scientific.net/amr.1125.327.
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The increase concentration of CO2 in the atmosphere is linked with global climate change. Among the technology options used for CO2 capture, there is a growing interest in using adsorption method for separation process. Inspired by the most applicable technology of amine–based chemical absorption for capturing CO2, the development of amine–functionalized kenaf based adsorbent has been proposed in this study. The incorporation of amine functional group (MEA and TEPA) on kenaf was conducted via wet impregnation method. The characterization was carried out by using FESEM and FTIR. The CO2 adsorption equilibrium study have been conducted and further described by Langmuir and Freundlich isotherm equation models at temperature of 0, 25 and 50oC. Result presented shows that Freundlich isotherm model fits the experimental data for raw kenaf and amine–modified kenaf. It was indicated by the values of R2. Additionally, results for each sample show the adsorption favourability since the values of KL is less than 1 and the magnitude of Freundlich (n) is greater than 1. Finally, this study revealed that the amine–modified kenaf could become another potential adsorbent for CO2 separation.
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Ma’mun, S., Hallvard F. Svendsen, and I. M. Bendiyasa. "Amine-based carbon dioxide absorption: evaluation of kinetic and mass transfer parameters." Journal of Mechanical Engineering and Sciences 12, no. 4 (December 27, 2018): 4088–97. http://dx.doi.org/10.15282/jmes.12.4.2018.08.0354.
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Global emission of carbon dioxide (CO2), a major contributor to the climate change, has increased annually and it reached over 37 Gt in 2017. An effort to reduce the emission, therefore, needs to be conducted, e.g. post-combustion capture by use of amine-based absorption. The objective of this study is to evaluate the kinetic and mass transfer parameters in a CO2 absorption process using monoethanolamine (MEA), 2-(methylamino)ethanol (MMEA), and 2-(ethylamino)ethanol (EMEA) as absorbents. The experiments were conducted in a bubble reactor at atmospheric pressure and 40 °C with 10-vol% CO2 flowrate of 5 NL/men. The CO2 concentration leaving the reactor was measured by an IR CO2 analyzer. The results obtained from this experiment were the overall absorption rates consisting of both chemical reaction and mass transfer. Analysis result shows that the reaction between CO2 and amines takes place fast, therefore the mass transfer of CO2 from the gas into the liquid through the gas film would control the overall absorption rate.
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Andreasen, Anders. "Optimisation of carbon capture from flue gas from a Waste-to-Energy plant using surrogate modelling and global optimisation." Oil & Gas Science and Technology – Revue d’IFP Energies nouvelles 76 (2021): 55. http://dx.doi.org/10.2516/ogst/2021036.
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The optimisation of Post Carbon Capture (PCC) from a Waste-to-Energy plant has been studied using Kriging surrogate models trained from a set of rigorous process simulations. The surrogate models allow fast and efficient calculation of model responses required for the optimisation of operating parameters. Optimisation is performed using Differential Evolution (DE) requiring a vast amount of function calculations (>1000) which would be extremely time consuming if done with a rigorous process simulation model. It is found that for meeting a CO2 removal efficiency of 85% for a flue gas containing 12.6 mole % CO2 and a reboiler temperature limited to max. 120 °C, a L/G ratio of approx. 2.2 (kg/kg) is optimal. This is accompanied by a stripper/regenerator pressure of 1.85 bara, a temperature of the flue gas at the lower bound, a temperature approach of the lean amine entering the absorber of 6.5 °C (to the flue gas temperature), and a temperature approach in the L/R heat exchanger of 5 °C. The optimal lean and rich amine loading is approx. 0.21 and 0.52 (mole CO2/mole MEA).
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Gatti, Manuele, Emanuele Martelli, Daniele Di Bona, Marco Gabba, Roberto Scaccabarozzi, Maurizio Spinelli, Federico Viganò, and Stefano Consonni. "Preliminary Performance and Cost Evaluation of Four Alternative Technologies for Post-Combustion CO2 Capture in Natural Gas-Fired Power Plants." Energies 13, no. 3 (January 22, 2020): 543. http://dx.doi.org/10.3390/en13030543.
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The objective of this study is to assess the technical and economic potential of four alternative processes suitable for post-combustion CO2 capture from natural gas-fired power plants. These include: CO2 permeable membranes; molten carbonate fuel cells (MCFCs); pressurized CO2 absorption integrated with a multi-shaft gas turbine and heat recovery steam cycle; and supersonic flow-driven CO2 anti-sublimation and inertial separation. A common technical and economic framework is defined, and the performance and costs of the systems are evaluated based on process simulations and preliminary sizing. A state-of-the-art natural gas combined cycle (NGCC) without CO2 capture is taken as the reference case, whereas the same NGCC designed with CO2 capture (using chemical absorption with aqueous monoethanolamine solvent) is used as a base case. In an additional benchmarking case, the same NGCC is equipped with aqueous piperazine (PZ) CO2 absorption, to assess the techno-economic perspective of an advanced amine solvent. The comparison highlights that a combined cycle integrated with MCFCs looks the most attractive technology, both in terms of energy penalty and economics, i.e., CO2 avoided cost of 49 $/tCO2 avoided, and the specific primary energy consumption per unit of CO2 avoided (SPECCA) equal to 0.31 MJLHV/kgCO2 avoided. The second-best capture technology is PZ scrubbing (SPECCA = 2.73 MJLHV/kgCO2 avoided and cost of CO2 avoided = 68 $/tCO2 avoided), followed by the monoethanolamine (MEA) base case (SPECCA = 3.34 MJLHV/kgCO2 avoided and cost of CO2 avoided = 75 $/tCO2 avoided), and the supersonic flow driven CO2 anti-sublimation and inertial separation system and CO2 permeable membranes. The analysis shows that the integrated MCFC–NGCC systems allow the capture of CO2 with considerable reductions in energy penalty and costs.
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Olindo and Vogtländer. "The Role of Hydrogen in the Ecological Benefits of Ultra Low Sulphur Diesel Production and Use: An LCA Benchmark." Sustainability 11, no. 7 (April 11, 2019): 2184. http://dx.doi.org/10.3390/su11072184.
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Desulphurization of oil-based fuels is common practice to mitigate the ecological burden to ecosystems and human health of SOx emissions. In many countries, fuels for vehicles are restricted to 10 ppm sulphur. For marine fuels, low sulphur contents are under discussion. The environmental impact of desulphurization processes is, however, quite high: (1) The main current source for industrial hydrogen is Steam Methane Reforming (SMR), with a rather high level of CO2 emissions, (2) the hydrotreating process, especially below 150 ppm, needs a lot of energy. These two issues lead to three research questions: (a) What is the overall net ecological benefit of the current desulphurization practice? (b) At which sulfphur ppm level in the fuel is the additional ecological burden of desulphurization higher than the additional ecological benefit of less SOx pollution from combustion? (c) To what extent can cleaner hydrogen processes improve the ecological benefit of diesel desulphurization? In this paper we use LCA to analyze the processes of hydrotreatment, the recovery of sulphur via amine treating of H2S, and three processes of hydrogen production: SMR without Carbon Capture and Sequestration (CCS), SMR with 53% and 90% CCS, and water electrolysis with two types of renewable energy. The prevention-based eco-costs system is used for the overall comparison of the ecological burden and the ecological benefit. The ReCiPe system was applied as well but appeared not suitable for such a comparison (other damage-based indicators cannot be applied either). The overall conclusion is that (1) the overall net ecological benefit of hydrogen-based Ultra Low Sulphur Diesel is dependent of local conditions, but is remarkably high, (2) desulphurization below 10 ppm is beneficial for big cities, and (3) cleaner production of hydrogen reduces eco-cost by a factor 1.8–3.4.
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Fu, Chao, Simon Roussanaly, Kristin Jordal, and Rahul Anantharaman. "Techno-Economic Analyses of the CaO/CaCO3 Post-Combustion CO2 Capture From NGCC Power Plants." Frontiers in Chemical Engineering 2 (January 11, 2021). http://dx.doi.org/10.3389/fceng.2020.596417.
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Calcium looping is a post-combustion technology that enables CO2 capture from the flue gases of industrial processes. While considerable studies have been performed at various levels from fundamental reaction kinetics to the overall plant efficiency, research work on techno-economic analyses of the calcium looping processes is quite limited, particularly for the Natural Gas Combined Cycle (NGCC). Earlier work has shown that theoretically, a high thermal efficiency can be obtained when integrating calcium looping in the NGCC using advanced process configurations and a synthetic CaO sorbent. This paper presents an investigation of calcium looping capture for the NGCC through a techno-economic study. One simple and one advanced calcium looping processes for CO2 capture from NGCC are evaluated. Detailed sizing of non-conventional equipment such as the carbonator/calciner and the solid-solid heat exchanger are performed for cost analyses. The study shows that the CO2 avoided cost is 86–95 €/tCO2, avoided, which is considerably more expensive than the reference amine (MEA) capture system (49 €/tCO2, avoided). The calcium looping processes considered have thus been found not to be competitive with the reference MEA process for CO2 capture from NGCC with the inputs assumed in this work. Significant improvements would be required, for example, in terms of equipment capital cost, plant efficiency and sorbent annual cost in order to be make the calcium looping technology more attractive for capturing CO2 from NGCC plants.
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Fu, Chao, Simon Roussanaly, Kristin Jordal, and Rahul Anantharaman. "Techno-Economic Analyses of the CaO/CaCO3 Post-Combustion CO2 Capture From NGCC Power Plants." Frontiers in Chemical Engineering 2 (January 11, 2021). http://dx.doi.org/10.3389/fceng.2020.596417.
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Calcium looping is a post-combustion technology that enables CO2 capture from the flue gases of industrial processes. While considerable studies have been performed at various levels from fundamental reaction kinetics to the overall plant efficiency, research work on techno-economic analyses of the calcium looping processes is quite limited, particularly for the Natural Gas Combined Cycle (NGCC). Earlier work has shown that theoretically, a high thermal efficiency can be obtained when integrating calcium looping in the NGCC using advanced process configurations and a synthetic CaO sorbent. This paper presents an investigation of calcium looping capture for the NGCC through a techno-economic study. One simple and one advanced calcium looping processes for CO2 capture from NGCC are evaluated. Detailed sizing of non-conventional equipment such as the carbonator/calciner and the solid-solid heat exchanger are performed for cost analyses. The study shows that the CO2 avoided cost is 86–95 €/tCO2, avoided, which is considerably more expensive than the reference amine (MEA) capture system (49 €/tCO2, avoided). The calcium looping processes considered have thus been found not to be competitive with the reference MEA process for CO2 capture from NGCC with the inputs assumed in this work. Significant improvements would be required, for example, in terms of equipment capital cost, plant efficiency and sorbent annual cost in order to be make the calcium looping technology more attractive for capturing CO2 from NGCC plants.
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Elena Diego, Maria, Jean-Michel Bellas, and Mohamed Pourkashanian. "Process Analysis of Selective Exhaust Gas Recirculation for CO2 Capture in Natural Gas Combined Cycle Power Plants Using Amines." Journal of Engineering for Gas Turbines and Power 139, no. 12 (August 16, 2017). http://dx.doi.org/10.1115/1.4037323.
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Postcombustion CO2 capture from natural gas combined cycle (NGCC) power plants is challenging due to the large flow of flue gas with low CO2 content (∼3–4 vol %) that needs to be processed in the capture stage. A number of alternatives have been proposed to solve this issue and reduce the costs of the associated CO2 capture plant. This work focuses on the selective exhaust gas recirculation (S-EGR) configuration, which uses a membrane to selectively recirculate CO2 back to the inlet of the compressor of the turbine, thereby greatly increasing the CO2 content of the flue gas sent to the capture system. For this purpose, a parallel S-EGR NGCC system (53% S-EGR ratio) coupled to an amine capture plant (ACP) using monoethanolamine (MEA) 30 wt % was simulated using gCCS (gPROMS). It was benchmarked against an unabated NGCC system, a conventional NGCC coupled with an ACP (NGCC + carbon capture and storage (CCS)), and an EGR NGCC power plant (39% EGR ratio) using amine scrubbing as the downstream capture technology. The results obtained indicate that the net power efficiency of the parallel S-EGR system can be up to 49.3% depending on the specific consumption of the auxiliary S-EGR systems, compared to the 49.0% and 49.8% values obtained for the NGCC + CCS and EGR systems, respectively. A preliminary economic study was also carried out to quantify the potential of the parallel S-EGR configuration. This high-level analysis shows that the cost of electricity (COE) for the parallel S-EGR system varies from 82.1 to 90.0 $/MWhe for the scenarios considered, with the cost of CO2 avoided (COA) being in the range of 79.7–105.1 $/ton CO2. The results obtained indicate that there are potential advantages of the parallel S-EGR system in comparison to the NGCC + CCS configuration in some scenarios. However, further benefits with respect to the EGR configuration will depend on future advancements and cost reductions achieved on membrane-based systems.
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Ghasem, Nayef. "Modeling and simulation of the hollow fiber bore size on the CO2 absorption in membrane contactor." Chemical Product and Process Modeling, June 1, 2020. http://dx.doi.org/10.1515/cppm-2019-0121.
Full textAbstract:
AbstractNatural gas is one of the main sources of energy. It contains mainly methane and less percentage of impurity compound (CO2, H2S, and N2). The existence of these undesired impurity compounds in natural gas are not needed, because the presence of the acid gases in natural gas can cause corrosion and lowering the heating value in addition to their hazardous nature. The compound severely influenced human health and cause global warming. Accordingly, the capture of the acid gases species (i. e., CO2, H2S) from natural gas is essential. There are many techniques used for this purpose, hollow fiber polymeric membrane is a promising technique for this purpose. In this article, a numerical model is developed to study the effect of membrane contacting process with diverse fiber bore diameters on the percent removal of CO2 from a gas mixture by means of aqueous MEA/water solution as a scrubbing solvent. The developed model is validated utilizing data available in literature. The verified model is used to investigate the effect of flow rate of liquid and gas, and membrane total contact area on the CO2 removal efficiency. Results revealed that, membrane bore diameter and liquid flow rate have strong impact on the percent removal of CO2. The membrane with smaller bore diameter performs better than the other modules with greater diameter.
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Hossain, Md Shahriar, Suprio Kamal, Mahbub Chowdhury, Md Tariful Islam, and Kawnish Kirtania. "Parametric Study on Co-Feeding of Municipal Solid Waste and Coal in an IGCC Power Plant with Pre-Combustion Carbon Capture." Chemical Engineering Research Bulletin, June 23, 2021, 37–42. http://dx.doi.org/10.3329/cerb.v22i1.54297.
Full textAbstract:
Municipal solid waste (MSW) is one of the top contributors in greenhouse gas (i.e. methane) emissions - particularly from landfill disposals. However, it could be a remarkable source of renewable energy. In Bangladesh, generation of municipal solid waste is at least 2.7 million tonne per year in the major cities, implying a heavy environmental burden. On the other hand, there are several coal-based power plants are in the pipeline to meet the increasing energy demand in Bangladesh with the potential of significant CO2 emission. To find a remedy to the above situation, a power plant using Integrated Gasification and Combustion Cycle (IGCC) technology with pre-combustion carbon capture is considered in this study. IGCC has the advantage of producing high quality syngas from a wide variety of feed and assists in the capture of CO2 at a lower cost while providing high electric efficiency. The power plant was simulated by commercial simulation packages (Aspen PLUS™ and Aspen HYSYS™) using MSW and bituminous coal (Indonesian) as a combined feed. With a feed rate of 1800 tonne per day, Syngas produced from an entrained flow type gasifier was then treated for CO2 removal using mono-ethanol amine (MEA) solvent after necessary shift in a high temperature shift reactor. About 91% efficiency was achieved in the shift reactor while the CO2 capture efficiency was varied for this study from 30% to 85%. Further parametric variation was studied by varying the moisture content of MSW and MSW to coal feed ratio. Through combustion of the H2 rich syngas in a gas turbine and subsequent steam cycle with reheat resulted in 125 MW of electricity at an efficiency of 28.95% while capturing 50% of the CO2 generated in the process for an MSW to Coal feed ratio of 1:1. With variation in moisture content especially during monsoon season, the plant efficiency could be affected remarkably. On the other hand, it was observed that the energy requirement varied from 6 to 8 MW for every 10% increase in CO2 capture quantity. Overall, by capturing 50% of the generated CO2, it is possible to reduce the emission of a same size ultra-supercritical coal-based power plant from about 700 kg CO2/MWh to about 360 kg of net CO2/MWh incorporating co-feeding and pre-combustion capture in an IGCC power plant.
Chemical Engineering Research Bulletin 21(2020) 37-42