CO2 capture from power plantsPart I. A parametric study of the technical performance based on monoethanolamine (original) (raw)
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Energy Procedia, 2009
Carbon dioxide is a greenhouse gas with a major impact on global climate change. One of the options for reducing CO 2 emissions is post combustion CO 2 capture from power plant flue gases. The main challenge for this process is the reduction of energy requirement for solvent regeneration. In order to reduce the costs of the absorption/desorption process, new tailored solvents for that process are needed. LTD operates a gas-fired pilot plant (column diameters 0.125 m, absorber packing height 4.25 m, flue gas flow 30-100 kg/h, CO 2 partial pressure 35-110 mbar) in which such new solvents were studied in the frame of the EU project CESAR. To obtain a baseline for testing the new solvents, first systematic studies were carried out with MEA in that plant with two different structured packings: Sulzer Mellapak 250.Y and BX 500. The most important process parameters CO 2 removal rate Ψ CO2 , fluid dynamic load and solvent flow rate were systematically varied. Besides MEA, two new solvents were studied in the pilot plant. It is shown that a direct comparison of results for different solvents obtained in such pilot plant experiments is not trivial. The comparison of only a few operating points for the new solvents with seemingly corresponding results for MEA can lead to wrong conclusions, since for each solvent an optimisation of the operating conditions is necessary. Only systematical studies allow a meaningful comparison. The technique that was used in the present work for this purpose was measuring data sets at constant CO 2 removal rate of 90% (by adjustment of the regeneration energy in the desorber) and systematically varying the solvent flow rate. A minimal energy requirement for the given removal rate is found from these studies. Only the optima for different solvents should be compared. By this procedure, solvents were identified that show a clear improvement in regeneration energy requirement when compared to MEA.
International Journal of Greenhouse Gas Control, 2012
The post combustion process based on the CO 2 absorption using amine aqueous solution is one of the more attractive options to drastically reduce greenhouse gas emissions from electric power sector. However, the solvent regeneration is highly energy intensive affecting the total operating cost significantly. The CO 2 removal target depends on the absorption and desorption processes where the main parameters of both processes are strongly coupled. Consequently, the simultaneous optimization of the whole CO 2 capture process is essential to determine the best design and operating conditions in order to minimize the total cost. This paper presents and discusses different cost optimizations including both investments and operating costs. The impact of different CO 2 emission reduction targets on the total annual cost, operating conditions and dimensions of process units is investigated in detail. Optimized results are discussed through different case studies.
Post-combustion Carbon Capture (PCC) is a key technology in a complete CO 2 capture and storage (CCS) chain. Reactive liquid absorption processes are currently the most advanced, both in commercial and technological terms. The area of improved solvents for CO 2 is a focal point in many R&D programmes, in addition to more efficient PCC process engineering and optimised process integration. CSIRO's R&D programme in Australia is investigating all these areas and this paper discusses solvent testing results with real flue gases. The performance of the solvents is determined by the inter-dependent relationships between the following three parameters: 1. CO 2 removal efficiency; 2. heat requirement for solvent regeneration; and 3. solvent loss as a result of evaporation/carry-over or solvent detoriation. The trials were conducted in CSIRO's transportable PCC Pilot Plant -hosted by Loy Yang Power, Australia -that has been capturing CO 2 from flue gas from the brown coal-fired power...
Comparison of solvent performance for CO2 capture from coal-derived flue gas: A pilot scale study
Chemical Engineering Research and Design, 2013
The performance of a proprietary solvent (CAER-B2), an amine-carbonate blend, for the absorption of CO 2 from coalderived flue gas is evaluated and compared with state-of-the-art 30 wt% monoethanolamine (MEA) under similar experimental conditions in a 0.1 MWth pilot plant. The evaluation was done by comparing the carbon capture efficiency, the overall mass transfer rates, and the energy of regeneration of the solvents. For similar carbon loadings of the solvents in the scrubber, comparable mass transfer rates were obtained. The rich loading obtained for the blend was 0.50 mol CO 2 /mol amine compared to 0.44 mol CO 2 /mol amine for MEA. The energy of regeneration for the blend was about 10% lower than that of 30 wt% MEA. At optimum conditions, the blend shows promise in reducing the energy penalty associated with using industry standard, MEA, as a solvent for CO 2 capture.
The aim of the paper consists in analyzing the effects of primary amines used (monoethanolamine -MEA) for CO 2 post-combustion capture on operating parameters for circulating fluidized bed combustion coal technology (CFBC). Primary amines are characterized by a higher chemical reaction with CO 2 but, also by a lower absorption capacity compared to secondary and tertiary amines. Additionally, the primary amines necessitate a higher energy required for solvent regeneration than the secondary and tertiary amines. Therefore, several process parameters have been optimized for reducing the heat required by the MEA regeneration and for increasing the CO 2 capture process efficiency. The process parameters analyzed in the optimized study were: amine (MEA) concentration in solvent; solvent flow; lean and rich loading solvent with CO 2 ; temperature of solvent in the absorption and stripper unit, etc. The heat required for solvent regeneration was 3.1 GJ/tonne CO 2 obtained by process parameters optimization (MEA concentration in solvent 40 wt.% and lean loading solvent 0.42 mol CO 2 /mol MEA). For 30 wt.% MEA concentration in solution, the energy required was 3.3 GJ/tonne CO 2 obtained for the optimal lean loading solvent of 0.44 mol CO 2 /mol MEA.
CO 2 capture from power plants
International Journal of Greenhouse Gas Control, 2007
i n t e r n a t i o n a l j o u r n a l o f g r e e n h o u s e g a s c o n t r o l 1 ( 2 0 0 7 ) 1 3 5 -1 4 2 Absorption process MEA ASPEN plus Economics a b s t r a c t While the demand for reduction in CO 2 emission is increasing, the cost of the CO 2 capture processes remains a limiting factor for large-scale application. Reducing the cost of the capture system by improving the process and the solvent used must have a priority in order to apply this technology in the future. In this paper, a definition of the economic baseline for post-combustion CO 2 capture from 600 MW e bituminous coal-fired power plant is described.
Energy Procedia, 2013
In this work the potential of a novel post-combustion CO 2 capture process is analysed with respect to the integrated overall process. As solvent a blend of two amines (DEEA/MAPA) which forms two liquid phases under CO 2 loading is used. The two phases have distinct physical characteristics. Only the heavy phase, rich in CO 2 loading, is led to the desorber. The novel solvent combination promises very low energy consumption compared to a 30 wt.-% MEA solution. The efficiency penalty, taking into account the integrated overall process, is very low too. Furthermore, different integration configurations in the overall process are investigated to show the effect in greenfield and retrofit power plant cases.
WEENTECH Proceedings in Energy
In the present world, Scientists are very much concern on to reduce the concentration level of carbon dioxide in environment to save the world. In the present work, the CO2 capturing efficiencies of three different amine solvents were analyzed. The selected solvents were mono-ethanol amine (MEA), solvent containing mixture of methyl diethanol amine (MDEA) and piperazine (PZ) called activated -MDEA and aqueous ammonia (NH3) solution. Rigorous simulation method was considered in the current study. The effects of different key parameters for different solvents on the CO2 removal efficiency were analyzed. Packing height, solvent temperature and absorber height were the significant influential parameters for MEA system whereas for activated-MDEA (a-MDEA), those are the ratio of the solvent to feed quantity and the mixed solvent PZ concentration level. For aqueous NH3 solution, absorber and stripper’s temperature, CO2 loading, concentration of NH3, height of the absorber, lean and rich so...