A REVIEW OF PRE-COMBUSTION CO 2 CAPTURE IN IGCC

Energy Procedia, 2014

This work aims at assessing the performance of IGCC power plants with CO 2 capture based on air-blown gasification, which is a field scarcely assessed in the open literature. The whole process is modelled and simulated, from coal gasification to syngas cooling and cleaning, to the syngas utilization in the power island. Particular attention is paid to the capture section, based on a two-stage H 2 S-CO 2 selective separation using MDEA as solvent, which was accurately modelled with a rate based approach. The final results show competitive performance of the assessed plants in terms of efficiency and specific emissions with respect to more conventional IGCC systems based on oxygen-blown gasification.

Applied Thermal Engineering, 2007

This paper presents the results of technical and economic studies in order to evaluate, in the French context, the future production cost of electricity from IGCC coal power plants with CO 2 capture and the resulting cost per tonne of CO 2 avoided. The economic evaluation shows that the total cost of base load electricity produced in France by coal IGCC power plants with CO 2 capture could be increased by 39% for 'classical' IGCC and 28% for 'advanced' IGCC.

Chemical Engineering Journal, 2019

Vacuum, temperature and concentration swing adsorption processes, have been designed to capture 85% of the CO 2 emitted by an advanced supercritical coal fired power plant of 800 MW taken as reference, and to produce a concentrated product with 95% of CO 2 (dry basis) using a sustainable carbon adsorbent inside the tubes of a tube-bundle adsorber. Indirect heat transfer is used to increase productivity and to conserve energy within the process. Two different configurations of the cyclic process have been evaluated at cyclic steady state through dynamic process simulation, using a detailed non-isothermal non-equilibrium fixed bed adsorption model that takes into consideration competitive adsorption between the main flue gas components: N 2 , CO 2 and H 2 O. Simulation results indicate that the purity and recovery constraints can be met with a specific heat duty of 2.32 MJ th kg-1 CO 2 and a specific electric consumption of 0.66 MJ e kg-1 CO 2. The main advantage of this process is that the specific heat duty, which is lower than the benchmark amine absorption technology, could be satisfied using waste heat.

A promising approach to meet future global energy needs while minimizing the carbon foot print is Integrated Gasification Combined Cycle(IGCC) with pre-combustion CO2 capture. The key challenge to use this technology is removing CO2 from syngas (H2+CO+CO2) before sending to turbine. Conventional solvent based absorption techniques need cooling of syngas to facilitate scrubbing process. This limitation results in significant energy penalty and reduced efficiency. Pressure Swing Adsorption (PSA) is a widely accepted technique for CO2 capture at elevated temperatures. PSA process is characterized by preferential adsorption of desired gas species on a porous adsorbent at high pressure and recovery of the same at lower pressure. However main issues of this technology are low recovery rate, development of suitable regenerable adsorbents for high temperature applications. Key factors that will decide the commercial worthiness of adsorbents are selectivity, stability, adsorption/desorption ...

International Journal of Hydrogen Energy, 2014

Hot gas decarbonation CO 2 capture IGCC a b s t r a c t Solid sorbents can be used to capture CO 2 from pre-combustion sources at various temperatures. MgO and CaO are typical medium-and high-temperature CO 2 sorbents.

Separation and Purification Technology, 2013

Two new MOF materials, i.e. USO-2-Ni MOF and UiO-67/MCM-41 hybrid, are evaluated as regards their potential for pre-combustion CO 2 capture within an IGCC power plant. Both materials have been formulated as particles, thus allowing for a meaningful characterization in view of process scale-up. This is done by first conducting fixed bed experiments, where the adsorbent material is packed into a column and exposed to three different CO 2 /H 2 mixtures at a given temperature (25 °C) and in a broad range of pressures (1-25 bar) in order to determine the corresponding transfer parameters. Second, complete PSA simulations are conducted. More precisely, a multi-objective analysis is carried out having the CO 2 purity and recovery as objectives. A fixed process configuration is considered and the optimization is repeated for different process conditions. The results of this analysis are then compared to a benchmark which has activated carbon as adsorbent. This comparison shows that the USO-2-Ni MOF indeed increases both the separation performance and the productivity of the PSA process with respect to activated carbon. UiO-67/MCM-41 hybrid exhibits a slightly worse separation performance, but a better specific adsorbent productivity than activated carbon. Furthermore, it is shown that the particle formulation is crucial, as it has a big impact on the packing characteristics, which in turn have a big impact on the process performance.

Chemical Engineering Research and Design, 2011

Global concentration of CO 2 in the atmosphere is increasing rapidly. CO 2 emissions have an impact on global climate change. Effective CO 2 emission abatement strategies such as Carbon Capture and Storage (CCS) are required to combat this trend. There are three major approaches for CCS: Post-combustion capture, Pre-combustion capture and Oxyfuel process. Post-combustion capture offers some advantages as existing combustion technologies can still be used without radical changes on them. This makes postcombustion capture easier to implement as a retrofit option (to existing power plants) compared to the other two approaches. Therefore, post-combustion capture is probably the first technology that will be deployed. This paper aims to provide a state-of-the-art assessment of the research work carried out so far in post-combustion capture with chemical absorption. The technology will be introduced first, followed by required preparation of flue gas from power plants to use this technology. The important research programmes worldwide and the experimental studies based on pilot plants will be reviewed. This is followed by an overview of various studies based on modelling and simulation. Key issues such as energy consumption and plant flexibility will be included. Then the focus is turned to review development of different solvents and process intensification. Based on these, we try to predict challenges and potential new developments from different aspects such as new solvents, pilot plants, process heat integration (to improve efficiency), modelling and simulation, process intensification and government policy impact.

International Journal of Greenhouse Gas Control, 2012

Among various configurations of fossil fuel power plants with carbon dioxide capture, this paper focuses on pre-combustion capture technology applied to an Integrated Gasification Combined Cycle power plant using gas-liquid absorption. The paper proposes a detailed study and optimization of plant design (column height and packed dimensions) with CO 2 capture process using different solvents as: aqueous solutions of alkanolamine, dimethyl ethers of polyethylene glycol, chilled methanol and N-Methyl-2pyrolidone. By developing simulations in Aspen Plus, the following performance results of these physical and chemical solvents, mentioned above, are discussed: overall energy consumption (power consumption, heating and cooling agent consumption), CO 2 specific emissions, net electric power output and plant efficiency. The paper presents as well, the total investment capital cost of an IGCC coal mixed with biomass (sawdust) power plant generating 425-450 MW net electricity with (70% CO 2 capture, 80% CO 2 capture and 90% CO 2 capture) and without pre-combustion CO 2 capture. Simulation results show that for evaluated solvents for CO 2 capture, the physical solvent, dimethyl ethers of polyethylene glycol, is more energy efficient that the other physical and chemical solvents investigated. Regarding the economic study, implementation of pre-combustion CO 2 capture on IGCC plant, using dimethyl ethers of polyethylene glycol, leads to an increase of the capital cost with about 19.55% for 70% CO 2 capture, 20.91% for 80% CO 2 capture and 22.55% for 90% CO 2 capture.

Industrial & Engineering Chemistry Research, 2016

The key challenge in postcombustion capture from gas-fired power plants is related to the low CO 2 concentration in the flue gas (4−8% by volume). This means that conventional amine processes will result in a relatively high energy penalty, whereas novel adsorbents and adsorption processes have the potential to improve the efficiency of separation. High-selectivity adsorbents are required to achieve relatively high CO 2 uptake at low partial pressures, which means that the separation process should be based on either very strong physisorption or chemisorption with thermal regeneration. From the process point of view, the main challenge is to develop efficient separation processes with rapid thermal cycles. In this report we present a detailed overview of the methodology behind the development of novel materials and processes as part of the "Adsorption Materials and Processes for Gas-fired power plants" (AMPGas) project. Examples from a wide variety of materials tested are presented, and the design of an innovative bench-scale 12-column rotary wheel adsorber system is discussed. The strategy to design, characterize, and test novel materials (zeolites, amine-containing MOFs, amine-based silicas, amine-based activated carbons, and carbon nanotubes), specifically designed for CO 2 capture from dilute streams is presented.

Energy Procedia, 2017

A moving-bed temperature-swing adsorption (MBTSA) process has been evaluated for post-combustion CO2 capture in a natural-gas combined cycle (NGCC) context using Zeolite 13X as adsorbent. The performance of the different sections of the reactor (adsorption, regeneration and heat exchange) were modelled in gPROMS using real equilibrium and kinetic adsorption data and typical heat transfer parameters. As a consequence of the internal heat transfer between the hot adsorbent powder leaving the regenerator with the cold powder entering the regenerator, a low specific heat requirement for regeneration of 2.3 GJth/ton CO2 captured is estimated. When also including the electrical energy needed (also compression of CO2) a total energy penalty of 6.5 %-points is obtained. For regeneration, flue gas at 222 °C was used for heating and it was assumed that the flue gas was heated after the power plant by using saturated steam condensing at 230°C. A major reduction in the heat requirement for the process can be gained if the heat required for regeneration is provided from more optimal integration with the steam cycle of the power plant.