No full-text available
To read the full-text of this research,
you can request a copy directly from the authors.
Evaluation of Five Alternative CO 2 Capture Technologies with Insights to Inform Further Development
Abstract
The high cost of CO2 capture using amine solvents from combustion sources such as natural gas-fired power plants remains a barrier to the adoption of CO2 Capture and Storage (CCS) as a climate change mitigation measure. The objective of the work reported in this paper was to carry out a preliminary assessment of the potential of five alternative technologies suitable for post-combustion CO2 capture from natural gas derived exhaust gases:
• CO2 permeable membranes
• Molten Carbonate Fuel Cells
• High-pressure solvent absorption from high-pressure exhaust gas from pressurised combustion / power generation
• High-pressure solvent absorption supported by exhaust gas compression
• Supersonic flow driven CO2 deposition
The results of the performance and cost evaluation for each technology are explained and the prospects for significant cost reduction compared to a state-of-the-art CO2 capture process are discussed. Recommendations for further technology development activity are summarised in the conclusion of the paper.
... The study reported in this paper focuses on CO 2 capture from flue gas produced from natural gas sources, is funded by the CCP and carried out by a group of LEAP (Laboratorio Energia e Ambiente Piacenza) and GECOS (Group of Energy Conversion Systems)-Politecnico di Milano researchers, together with the CCP team. This work originates from the preliminary study reported by Forsyth et al. in 2017 [25], and focuses on the preliminary assessment of the following four promising technologies for post-combustion CO 2 capture from NGCCs: ...
... Compared to the introductory work by Forsyth et al. [25], this paper provides the following novel contributions: ...
... Simplified process flow diagram of the pressurized CO 2 solvent absorption integrated with multi-shaft gas turbine and Heat Recovery Steam Cycle (HRCS)[25]. The High Pressure Solvent Technology box is a simplified version of the CO 2 capture unit based on hot potassium carbonate (detailed scheme reported by Christensen et al.[11]), aiming at highlighting the main connections of the power plant with the absorber (process column in blue) and the regenerator (process column in red).(Picture ...
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), 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.
... According to the recent study [12], the MCFC-based capture system looks promising when compared to amines and other four novel CO 2 capture systems. As conceptually illustrated in Fig. 1, if CO 2 -rich flue gas is fed to the fuel cell cathode, the MCFC electrochemical reaction makes possible the CO 2 separation from the cathode stream, and its migration towards the anode (fed with internally reformed fuel) due to the permeation of CO 3 2 ions through a liquid carbonate electrolyte retained in a ceramic matrix. ...
... The energy and economic performance of the MCFC-based power plants are compared with those of a benchmark amine scrubbing postcombustion processes previously assessed elsewhere [12]. ...
... The correlation used in this study to estimate the MCFC voltage results from a polarization curve interpolated on the data gathered during an experimental analysis, which was previously carried out internally at Fuel Cell Energy Inc. (FCE) using simulated coal and NG power plant effluents (as discussed in Refs. [12,27]). The correlation allows computing the MCFC voltage as a difference between Nernst potential and all the polarization losses (according to eq. (1)). ...
This work explores two configurations of natural gas-fired combined cycles (NGCC) with molten carbonate fuel cells (MCFC) for CO2 capture. Special attention is devoted to the selection of MCFC operating conditions (trade-off between CO2 capture and voltage losses), heat integration scheme, fuel use and CO2 purification. Two schemes are considered: (i) in the first “integrated” scheme, MCFC modules are installed between the gas turbine and the heat recovery steam generator (HRSG) to maximize the efficiency of the integrated power plant; (ii) in the second “non-integrated” layout, the MCFC is located downstream of the HRSG and a regenerative heat exchanger is designed to preheat cathode reactants up to the MCFC working temperature. This study includes a full techno-economic analysis of the two layouts based on a preliminary sizing of the key-components, and a sensitivity analysis on the CO2 utilization factor. Compared to a benchmark amine scrubbing process, the “integrated” configuration shows considerably better performance (Specific Primary Energy Consumption for CO2 Avoided - SPECCA = 0.31 MJ kgCO2⁻¹; Cost of CO2 avoided - CCA = 50 tCO2⁻¹).
... • Simulation of base CCGT power plant, cross checked against public data such as Gas Turbine World • CO 2 capture process cost and performance provided by Shell Cansolv for proprietary amine solvent case and various technical papers and public domain references for FuelCell Energy's DCF3000 units for the MCFC case (International Journal of Hydrogen Energy, 2010;Fuel Cell et al., 2015;Consonni et al., 2016;Forsyth et al., 2016;Fuel cell Energy, 2018). ...
... The scheme above has the anticipated advantage of being able to more directly control the purity of the CO 2 product. Subsequent work by the Carbon Capture Project (CCP) (Forsyth et al., 2016) found that slightly higher thermal efficiency of the overall scheme could be achieved by recycling the recovered unconverted fuel species to the fuel cell rather than the gas turbine and thus this following configuration was selected as our basis for further techno-economic assessment as shown in Figure 1. ...
This paper presents the findings of the techno-economic assessment undertaken by Wood for the UK Government Department for Business, Energy and Industrial Strategy on the large-scale deployment of Molten Carbonate Fuel Cells (MCFCs) for post-combustion CO2 capture integrated with a new build combined cycle gas turbine power plant for the generation of low carbon electricity. The findings are compared with a state of the art proprietary amine scrubbing technology. Based on a new build power plant to be installed in the North East of England, with a power train comprising two trains of H-class gas turbines each with a dedicated steam turbine, the configuration presented utilises MCFCs between the gas turbine exhausts and their heat recovery steam generators and cryogenic separation for unconverted fuel recycle and CO2 purification. It was found that the proposed configuration could achieve 92% CO2 capture from the overall power plant with MCFCs while achieving 42% of additional new power production with only 2.6 %-points of thermal efficiency penalty compared to a conventional proprietary amine benchmark. While the total project capital cost increased by 65%, the high overall thermal efficiency and additional power generated resulted in a Levelised Cost of Electricity almost identical to the benchmark at £70/MWh (US$97/MWh). A number of areas are identified for potential further improvement in this scheme. It is concluded that use of MCFC technology, which also has the capability to be tailored for hydrogen production and combined heat and power services, shows significant potential to be competitive with, or exceed, the cost and technical performance of current state of the art technologies for post-combustion CO2 capture.
... Among these methods, the MCFC method with 57% has the highest efficiency but unfortunately, this method did not reach the commercial stage and thus, MEA with 50% efficiency has the best efficiency. Other methods have 49%, 48%, 40% and 38% efficiencies respectively [47]. ...
There are several methods to reduce CO2 emissions, including optimization of energy consumption by increasing the efficiency of a powerplant, using renewable energy, and Carbon Capture Plant (CCP). In this study, the methods of increasing efficiency and the application of CCP have been performed simultaneously. To increase efficiency, the newly proposed method of Heat Recovery Steam Generator (HRSG) Flue-Gas Injection (FGI) into the Heller tower of the powerplant was developed. Then, the CO2 captured plant (using MEA chemical Absorption), which is embedded inside the Heller towers, was investigated. Energy and exergy analysis was performed for each component and finally for the whole powerplant under crosswind conditions.
The results show that the addition of the CCP inside the tower will even reduce the efficiency of the base cycle by as much as 9%, and in windy conditions, this reduction will be even greater. However, by using the FGI in the Heller tower, the cycle efficiency will increase by 1%.
The highest destruction of exergy (41% relatively) happened in the combustion chamber. The CCP had the second-highest exergy destruction, which was estimated to be about 22% for no injection mode and 20% for injection mode relatively. HRSG and the cooling tower had the highest exergy destruction after the CCP.
Finally, in view of rising carbon prices in the coming years, among the three proposals, the second plan (FGI with CCP) is economically feasible from 2030 with a return-on-investment rate of 35.63% and the Net Present Value (NPV) of 142480. Moreover, this plan is worthwhile from the environmental point of view.
... 20,21 The molten carbonate fuel cell (MCFC) technology offers strong potential for both power generation and power-chemical cogeneration in an environmentally friendly way. 22,23 Likewise, MACs have been proposed for gas separation operations, in particular for CO 2 capture and valorization, 24 which are of great relevance for CO 2 abatement, and are used in MCFCs, 25,26 and absorption on the liquid phase. 27,28 Moreover, MAC-based membranes for gas (CO 2 ) separation applications have been reported considering several supports. ...
The properties of single walled nanotubes and carbon fullerenes in molten alkali carbonates were studies as a function of the considered nanomaterial and the ions in the molten salt using classical molecular dynamics simulations. The adsorption and confinement in carbon nanotubes is developed by efficient adsorption of carbonate ions in inner and outer walls of the nanotubes whereas alkali cations do not show remarkable interaction with the nanomaterial. Analogous solvation mechanisms are inferred for carbon fullerenes with large disruption of the liquid structuring of molten alkali carbonate at high fullerene concentrations. The solvation ability of the studied lithium-sodium-potassium carbonate eutectic mixture for both types of nanomaterials are suitable for considering this fluid in the development of mixed materials for technological applications.
Structured sorbents with better adsorption kinetics and lower pressure drop than packed beds of conventional adsorbents are gaining increasing attention due to the potential advantages of smaller footprint and lower energy consumption in a CO2 capture process. The aim of this computational study is to examine the potential improvement in productivity of a CO2 capture process using 3D printed, structured sorbents compared to a conventional packed bed system. The sorbents chosen in this work are silica pellets and 3D printed structures, both grafted with an amino silane. A representative flue gas/FCC regenerator off-gas containing 15 vol % CO2, 5% H2O and 80% N2 and an SMR-off gas containing 21% CO2, 5% H2O, and 74% N2 were considered as feed streams. Detailed genetic algorithm-based optimization of a 6-step vacuum swing adsorption cycle for both adsorbents was carried out to identify the minimum specific energy and maximum productivity for concentrating the CO2 to 95 vol% purity on a dry basis and capturing 90% of the CO2. The simulations indicate that use of the 3D printed adsorbent may achieve a 3-fold increase in productivity with about 25-38% reduction in energy consumption relative to the conventional packed bed. Scaling the process to a real system revealed a 1.8 times reduction in the capture footprint for a VSA process using 3D printed sorbents instead of a traditional packed bed.
This article presents a new technology for the generation of power and steam, or other process heat, with very low CO2 emissions. It is well known that cogeneration of electricity and steam is highly efficient and that amine units can be used to remove CO2 from combustion flue gas, but that the amine unit consumes a significant amount of steam and power, reducing the overall system efficiency. In this report, the use of molten carbonate fuel cells (MCFCs) to capture CO2 from cogen units is investigated and shown to be highly efficient due to the additional power that they produce while capturing the CO2. Furthermore, the MCFCs are capable of reforming methane to hydrogen simultaneous to the power production and CO2 capture. This hydrogen can either be recycled as fuel for consumption by the cogen or MCFCs, or exported to an independent combustion unit as low carbon fuel, thereby decarbonizing that unit as well. The efficiency of MCFCs for CO2 capture is higher than use of amines in all cases studied, often by a substantial margin, while at the same time the MCFCs avoid more CO2 than the amine technology. As one example, the use of amines on a cogeneration unit can avoid 87.6% of CO2 but requires 4.91 MJ/kg of additional primary energy to do so. In contrast, the MCFCs avoid 89.4% of CO2 but require only 1.37 MJ/kg of additional primary energy. The high thermal efficiency and hydrogen export option demonstrate the potential of this technology for widespread deployment in a low carbon energy economy.
Molten carbonate electrolysis cells have recently gained interest for the sustainable production of H2 or syngas to substitute fossil fuels. However, they can be also used for CO2 sequestration, as they pump it from one electrode inlet to the opposite electrode outlet. Thus, they can easily be applied to segregation of CO2 from H2 based fuels while also increasing the fuel heat of combustion for example after a steam reforming reactor.
To explore the use of molten carbonate electrolysis cell for this application, in this work the authors investigate the performance of the cell under different operating conditions in term of both operating temperature and fuel electrode gas composition. Polarization curves, gas crossover and electrochemical impedance spectroscopy are used to evaluate specific issues (high electrolyte losses due to water and temperature) or benefits (excess of H2O in regard to CO2 that allows for higher CO2 capture rate). After, a series of long-term tests at −150 mA cm⁻² and 650 °C are performed to demonstrate long term stability. In particular, before electrolyte loss made the performance unstable, different cells are operated for about 1000 h with an average voltage of about 1.14 V demonstrating also the repeatability of such tests.
In the present study, surface modification of Fe3O4 particles with ascorbic acid (AA-Fe3O4) is carried out to enhance the absorption and regeneration performances of Fe3O4 nanoabsorbents with magnetic fields. The surface modified AA-Fe3O4 particles compensate for the defects of commercial magnetic nanoparticles by enhanced hydrophilicity and increased surface area. Methanol, which is widely used as a conventional industrial physical absorbent of CO2 capture, is used as a base fluid; however, the absorption process must be operated at low temperature for high absorption performance. In addition, a substantial amount of energy input is required to reach the regeneration operating temperature. Manufactured AA-Fe3O4 is analyzed using various analysis methods to assess absorption characteristics. Furthermore, a property analysis of 0.005 vol% AA-Fe3O4 dispersed in methanol shows that a high dispersion stability is obtained compared to 0.005 vol% commercial Fe3O4 dispersed in methanol. An evaluation on the performance of AA-Fe3O4 at 25 °C in the presence of external rotating magnetic fields shows an enhancement of 23.3 % in absorption. According to the specific energy consumption analysis, it is concluded that AA-Fe3O4/methanol nanoabsorbents will be beneficial for industrial applications in efficient energy savings for CO2 capture.
The present research work provides a quantitative evaluation of the CO2 absorption performance of potassium prolinate by setting a reliable and cost-effective approach for solvent screening, based on both experimental activities and data analysis. Potassium prolinate has been chosen as a promising green solvent to be tested at two different concentrations (30% and 43.38% w/w ProK aqueous solutions).
The applied methodology involves direct comparison of the alternative solvent against a reference case, such as 30% w/w MEA solution. The test has been carried out on a bench-scale facility composed of a glass column with internal random packing located at Sotacarbo Research Center (Sardinia); the facility has been run in open and closed cycle mode, assessing the performance in terms of CO2 removal from NGCC synthetic flue gases (e.g.: 4% mol/mol CO2 concentration).
The outcome of this work provides new information based on experimental data on removal, maximum achievable loading, loading increment rate and solvent capacity, and it constitutes a novel contribution to the literature. Moreover, it represents a tangible effort in delivering an insight on non-precipitating amino acid viability for flue gas decarbonization in CCS technologies.
The properties and structure of relevant interfaces involving molten alkali carbonates are studied using molecular dynamics simulations. Lithium carbonate and the Li/Na/K carbonate eutectic mixture are considered. Gas phase composed of pure CO2 or a model flue gas mixture are analysed. Likewise, the adsorption of these gas phases on graphene are studied, showing competitive CO2 and N2 adsorption that develops liquid-like layers and damped oscillation behaviour for density. The interaction of the studied carbonates with graphene is also characterized by development of adsorption layers through strong graphene – carbonate interactions and the development of hexagonal lattice arrangements, especially for lithium carbonate. The development of molten salts – vacuum interfaces is also considered, analysing the ionic rearrangement in the interfacial region. The behaviour of the selected gas phases on top of molten alkyl carbonate is also studied, showing the preferential adsorption of CO2 molecules when flue gases are considered.
Partnering in Innovation, Inc. (Pi-Innovation) introduces an aqueous post-combustion carbon dioxide (CO2) capture system (Pi- CO2) that offers high market value by directly addressing the primary constraints limiting beneficial re-use markets (lowering parasitic energy costs, reducing delivered cost of capture, eliminating the need for special solvents, etc.). A highly experienced team has completed initial design, modeling, manufacturing verification, and financial analysis for commercial market entry. Coupled thermodynamic and thermal-hydraulic mass transfer modeling results fully support proof of concept. Pi-CO2 has the potential to lower total cost and risk to levels sufficient to stimulate global demand for CO2 from local industrial sources.
CO2 capture from gas turbine based off-shore application face challenges such as size (foot-print), weight and stability (wave motion) in addition to the challenges faced by on-shore industry. Space- and weight challenges are given priority, and the size of the capture installations will be of importance when selecting capture technology rather than process efficiency alone. In this work, CO2 capture from an FPSO turbine exhaust gas using a supersonic separator is investigated. To assess the operational performance of the capture process, a Laval nozzle (converging-diverging geometry) model is implemented and successfully integrated in a steady-state process flow sheet simulator. The model includes equilibrium thermodynamics describing freeze-out of dry ice from a gas mixture containing CO2 . To determine under which conditions this process is thermodynamically and fluid dynamically feasible, different boundary conditions are explored. By integrating the supersonic separator unit in a flow sheet model, the interaction between the capture and the rest of the process is studied. The results indicate that supersonic expansion is a viable strategy for capturing CO2 from off-shore gas turbines.
Driven by the search for high efficiency power generation with low CO2 emissions, several works in the last years investigated the integration of gas turbine cycles and high temperature fuel cells to arrange power plants with CO2 capture. One of the most promising configurations in a mid-term perspective relies on the use of Molten Carbonate Fuel Cells (MCFC) as "active CO2 concentrator" in natural gas combined cycles (NGCC). This work presents an assessment of the economic perspectives of the two most promising configurations, previously analyzed through detailed simulations carried out at Politecnico di Milano, discussing their potential for the long-term (2025+) technology portfolio of an electric utility. The fuel cell cathode side receives the gas turbine exhausts, in order to transfer CO2 from this stream to the anode side. While doing this, the MCFC requires about 20% of the total fuel input and contributes to the plant electric power output by a similar fraction. Downstream the MCFC is placed the heat recovery steam generator (HRSG); exhaust heat released to the cell effluents is recovered in the bottoming steam cycle. Two different approaches were considered for purification of the CO2-rich flow exiting the fuel cell anode: (i) a cryogenic process that separates CO2 from the residual combustible compounds, which are recycled back to the gas turbines, or (ii) an oxy-combustion of residual combustible species, followed by heat recovery, cooling and water separation by condensation. In all cases, purification yields a high purity CO2 stream, pumped to liquid form for storage. Both these plant configurations can capture up to 70-85% of CO2 with small or negligible efficiency penalties compared to a baseline NGCC while increasing remarkably the plant power output, thus yielding relevant advantages with respect to competitive CO2 capture technologies. Moreover, the relatively limited power output of the fuel cell section suggests a plausible mid-term feasibility of the proposed concept, by taking into account that largest existing MCFC plants built so far surpassed the 50 MWel size. After an introduction about MCFC technological status and economic outlook, this work analyzes the economic performances of the proposed plants in order to evaluate their economic viability, considering all plant components and adopting a detailed bottom-up approach to determine the component cost distribution and the total plant costs. The final effect on cost of electricity and CO2 capture cost are addressed, allowing to evidence whether and how this solution might be competitive in the future. It is shown that current MCFC costs do not allow an economic advantage with respect to 'traditional' carbon capture cycles (i.e., NGCC with ammines scrubbing); while the situation would change assuming more aggressive mid-term MCFC cost targets. The breakeven specific costs that MCFC should achieve to successfully compete on an economic basis results close to 1500 (sic)/kW(el) (in terms of Total Equipment Cost, TEC) for a cost of natural gas equal to 6.5 (sic)/GJ, increasing to 2000 (sic)e/kW(el) assuming NG cost of 9 (sic)/GJ.
In recent years, several research groups have proposed the combination of Molten Carbonate Fuel Cells (MCFCs) and gas turbine cycles for the application to CO2 capture. One of the most promising configuration relies on the use of MCFCs as “active CO2 concentrator” in combined cycles (CCs): the fuel cell is placed downstream the gas turbine and ahead the heat recovery steam generator (HRSG), to concentrate the CO2 from the gas turbine exhaust feeding the cathode, to the anode (where CO2 is transferred together with oxygen) and generate electricity; while exhaust heat released by the cell effluents is recovered by the steam cycle. It has been shown that such plant configuration can capture 70–85% of CO2 with small efficiency penalties compared to the combined cycle, and increasing by about 20% the overall power output (mainly given by the MCFC section); hence, this configuration could have relevant advantages with respect to competitive carbon capture technologies.
Low natural gas prices are contributing to rapid growth in natural gas combined cycle (NGCC) power production in the United States. CO2 capture from the exhaust gas of these plants is complicated by the relatively low CO2 concentration in this flue gas (3%–4%). A membrane process using incoming combustion air as a sweep stream in a selective exhaust gas recycle configuration can be used to preconcentrate CO2 from 4% to 15%–20% with almost no energy input. Depending on the process configuration, the selective recycle membrane design reduces the minimum energy of a CO2 capture step by up to 40%. An all-membrane design using a capture step in series with a selective recycle membrane can capture 90% of CO2 from an NGCC power plant using less energy and at a lower cost than the base-case amine process analyzed by the U.S. Department of Energy. The current state-of-the-art membranes for use in this process have a CO2 permeance of 2200 gpu and a CO2/N2 selectivity of 50. Higher CO2 permeance will improve the economics and reduce the footprint of a membrane CO2 capture system, while higher CO2/N2 selectivity is of less benefit, because the process is limited by the affordable pressure ratio.
This paper investigates an advanced cycle with limited CO2 emissions based on the integration of Molten Carbonate Fuel Cells (MCFC) in a natural gas fired combined cycle power plant in order to capture CO2 from the exhaust of the gas turbine. The gas turbine flue gases actually are used as cathode feeding for an MCFC, where CO2 is moved from the cathode to anode side, concentrating the CO2 in the anode exhaust. This stream is then cooled in the heat recovery steam generator and sent to a cryogenic CO2 removal section. The plant shows the potential to achieve a carbon capture ratio of 80%, while taking advantage from the introduction of the fuel cell, the final electric efficiency is about the same of the original combined cycle (58.7% LHV), and the power output increases by about 22%, giving a potentially relevant advantage with respect to competitive carbon capture technologies.
In this paper Molten Carbonate Fuel Cells (MCFCs) are considered for their potential application in carbon dioxide separation when integrated into natural gas fired combined cycles. The MCFC performs on the anode side an electrochemical oxidation of natural gas by means of CO32− ions which, as far as carbon capture is concerned, results in a twofold advantage: the cell removes CO2 fed at the cathode to promote carbonate ion transport across the electrolyte and any dilution of the oxidized products is avoided.The MCFC can be “retrofitted” into a combined cycle, giving the opportunity to remove most of the CO2 contained in the gas turbine exhaust gases before they enter the heat recovery steam generator (HRSG), and allowing to exploit the heat recovery steam cycle in an efficient “hybrid” fuel cell+steam turbine configuration. The carbon dioxide can be easily recovered from the cell anode exhaust after combustion with pure oxygen (supplied by an air separation unit) of the residual fuel, cooling of the combustion products in the HRSG and water separation. The resulting power cycle has the potential to keep the overall cycle electrical efficiency approximately unchanged with respect to the original combined cycle, while separating 80% of the CO2 otherwise vented and limiting the size of the fuel cell, which contributes to about 17% of the total power output so that most of the power capacity relies on conventional low cost turbo-machinery. The calculated specific energy for CO2 avoided is about 4 times lower than average values for conventional post-combustion capture technology. A sensitivity analysis shows that positive results hold also changing significantly a number of MCFC and plant design parameters.
As part of its climate change mitigation initiative, BP is evaluating technologies for the separation and capture of CO2 from combustion sources, for subsequent geologic storage. Ansaldo Fuel Cells S.p.A. is developing molten carbonate fuel cell (MCFC) technology targeted at industrial applications from 50 kW to 10 MW. This paper describes the conceptual design of a hybrid MCFC system to generate power and simultaneously capture CO2 from small (<10 MW) gas turbine exhaust streams. Initial modeling studies indicated that a 1.6 MW MCFC could reduce the CO2 emissions from a 4.6 MW gas turbine by 50% on a per kWh basis. Experimental studies are in progress to understand the system behaviour, operating envelope and impact of contaminants. Initial data from these investigations are presented, which confirm that the fuel cell can operate at sub-optimal CO2 levels with limited loss in power and efficiency.
Global technology roadmap for CCS in industry Sectoral Assessment CO2 Enhanced Oil Recovery
- M L Godec
Godec, M. L., Global technology roadmap for CCS in industry Sectoral Assessment CO2 Enhanced Oil Recovery, Advanced Resources
International, Inc., Arlington, VA 22203 USA, 5 May 2011.
Cost and performance baseline for Fossil Energy Plants
- T Fout
Fout, T. et al, Cost and performance baseline for Fossil Energy Plants Volume 1a: Bituminous Coal (PC) and Natural Gas to Electricity,
Revision 3, DOE/NETL-2015/1723 published by US Department of Energy, 6 July 2016
Increasing Efficiency of Hot Potassium Carbonate CO2 Removal Systems, UOP LLC
- S Milidovich
- E Zbacnik
Milidovich S., Zbacnik E., Increasing Efficiency of Hot Potassium Carbonate CO2 Removal Systems, UOP LLC, 2013.
Improved Benfield Process for Ammonia Plants”, internal UOP technical paper
- R K Bartoo
- S K Furukawa
Bartoo, R. K., Furukawa, S. K.: "Improved Benfield Process for Ammonia Plants", internal UOP technical paper, January 1997.
Mass transfer apparatus and method for separation of gases
- G C Blount
G. C. Blount, "Mass transfer apparatus and method for separation of gases," US 2015/0075375 A1, 2015.
Supersonic Post-Combustion Inertial CO2 Extraction System Bench Scale Project Status Update. Presented at 2014 NETL CO2 Capture Technology Meeting
- Balepin
Balepin et al., 2014. Supersonic Post-Combustion Inertial CO2 Extraction System Bench Scale Project Status Update. Presented at 2014
NETL CO2 Capture Technology Meeting.
Project-factsheet of the US DOE Office of Fossil Energy NETL Program. A high efficiency inertial CO2 extraction system - ICES
- B Calayag
- A Castrogiovanni
Calayag B, Castrogiovanni A, Project-factsheet of the US DOE Office of Fossil Energy NETL Program. A high efficiency inertial CO2
extraction system -ICES, 2014.
An experimental investigation into the use of molten carbonate fuel cells to capture CO2 from gas turbine exhaust gases, Green House Gas Control Technologies
- A Amorelli
- M B Wilkinson
- P Bedont
- P Capobianco
- B Marcenaro
- F Parodi
- A Torazza