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Thomas Turek - One of the best experts on this subject based on the ideXlab platform.
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materials system designs and modelling approaches in techno economic Assessment of all vanadium redox flow batteries a review
Journal of Power Sources, 2018Co-Authors: Christine Minke, Thomas TurekAbstract:Abstract The vanadium redox flow battery (VFB) is one of the most promising stationary electrochemical storage systems. The reduction of system costs is a major challenge in the realization of its widespread application. The high complexity of this technology requires a close linking of technologic and economic aspects in system cost Assessment. The present review provides an extensive literature analysis with a focus on Techno-Economic Assessment of VFB. Considered materials, system designs and modelling approaches are assessed and compared in order to present and evaluate the current status of system cost Assessment in a transparent way. Systems in a range of 2 kW–50 MW providing energy for up to 150 h are covered in literature resulting in an immense range of specific total system costs of 564–12931 € kW−1 or 89–1738 € (kWh)−1. Based on the data from the reviewed studies, guide values of 650 € (kWh)−1 and 550 € (kWh)−1 for installed VFB systems in a power range of 10–1000 kW providing energy for 4 h and 8 h respectively are derived from literature. Moreover, the relevance of precision in the definition of scope and components for meaningful results of Techno-Economic Assessments of VFB systems is pointed out.
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Techno-Economic Assessment of novel vanadium redox flow batteries with large-area cells
Journal of Power Sources, 2017Co-Authors: Christine Minke, Ulrich Kunz, Thomas TurekAbstract:Abstract The vanadium redox flow battery (VRFB) is a promising electrochemical storage system for stationary megawatt-class applications. The currently limited cell area determined by the bipolar plate (BPP) could be enlarged significantly with a novel extruded large-area plate. For the first time a Techno-Economic Assessment of VRFB in a power range of 1 MW–20 MW and energy capacities of up to 160 MWh is presented on the basis of the production cost model of large-area BPP. The economic model is based on the configuration of a 250 kW stack and the overall system including stacks, power electronics, electrolyte and auxiliaries. Final results include a simple function for the calculation of system costs within the above described scope. In addition, the impact of cost reduction potentials for key components (membrane, electrode, BPP, vanadium electrolyte) on stack and system costs is quantified and validated.
Christine Minke - One of the best experts on this subject based on the ideXlab platform.
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materials system designs and modelling approaches in techno economic Assessment of all vanadium redox flow batteries a review
Journal of Power Sources, 2018Co-Authors: Christine Minke, Thomas TurekAbstract:Abstract The vanadium redox flow battery (VFB) is one of the most promising stationary electrochemical storage systems. The reduction of system costs is a major challenge in the realization of its widespread application. The high complexity of this technology requires a close linking of technologic and economic aspects in system cost Assessment. The present review provides an extensive literature analysis with a focus on Techno-Economic Assessment of VFB. Considered materials, system designs and modelling approaches are assessed and compared in order to present and evaluate the current status of system cost Assessment in a transparent way. Systems in a range of 2 kW–50 MW providing energy for up to 150 h are covered in literature resulting in an immense range of specific total system costs of 564–12931 € kW−1 or 89–1738 € (kWh)−1. Based on the data from the reviewed studies, guide values of 650 € (kWh)−1 and 550 € (kWh)−1 for installed VFB systems in a power range of 10–1000 kW providing energy for 4 h and 8 h respectively are derived from literature. Moreover, the relevance of precision in the definition of scope and components for meaningful results of Techno-Economic Assessments of VFB systems is pointed out.
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Techno-Economic Assessment of novel vanadium redox flow batteries with large-area cells
Journal of Power Sources, 2017Co-Authors: Christine Minke, Ulrich Kunz, Thomas TurekAbstract:Abstract The vanadium redox flow battery (VRFB) is a promising electrochemical storage system for stationary megawatt-class applications. The currently limited cell area determined by the bipolar plate (BPP) could be enlarged significantly with a novel extruded large-area plate. For the first time a Techno-Economic Assessment of VRFB in a power range of 1 MW–20 MW and energy capacities of up to 160 MWh is presented on the basis of the production cost model of large-area BPP. The economic model is based on the configuration of a 250 kW stack and the overall system including stacks, power electronics, electrolyte and auxiliaries. Final results include a simple function for the calculation of system costs within the above described scope. In addition, the impact of cost reduction potentials for key components (membrane, electrode, BPP, vanadium electrolyte) on stack and system costs is quantified and validated.
Wan Azlina Wan Ab Karim Ghani - One of the best experts on this subject based on the ideXlab platform.
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techno economic Assessment of a novel integrated system of mechanical biological treatment and valorisation of residual municipal solid waste into hydrogen a case study in the uk
Journal of Cleaner Production, 2021Co-Authors: Anh N Phan, Eleni Iacovidou, Wan Azlina Wan Ab Karim GhaniAbstract:Abstract Resources embedded in the waste streams are not properly recovered and most of them are ended up in landfills or only recovered as energy via energy-from-waste (EfW) facilities. Innovative resource recovery from waste strategies are urgently needed to maximise resource efficiency, divert waste from landfills and reduce reliance on EfW. This study proposes a novel mechanical-biological treatment with valorisation concept (MBT-v) which combines material recovery and fuel production, as alternatives to EfW for residual municipal solid waste (MSW) treatment. The polygeneration feature exhibited by the MBT-v system enhances resource efficiency and product diversification. The proposed MBT-v system involves valorisation of rejected materials from MBT into hydrogen by incorporating an additional gasification system. A comprehensive Techno-Economic Assessment is conducted for the proposed MBT-v system and compared against a conventional MBT. The results reveal that the conventional MBT strongly relies on gate fees to be economically viable while it is heavily impacted by the rejects disposal cost. The analysis also shows that higher economic potential (36.4 M£/y) for MBT-v can be obtained compared to that of conventional MBT (3.4 M£/y) for a 100 kt/y residual MSW system. The minimum hydrogen selling price (MHSP) from the Gasification-H2 system is estimated to be at 3.4 £/kg (28.2 £/GJ), with potential for further reduction through upscaling the facility. This study concludes that producing high value product such as hydrogen (with the current assumed market price of hydrogen of 10 £/kg) can significantly improve the economic performance and minimise financial instability of the facilities. It is recommended that the scale and optimal configuration of MBT-v needs to be designed based on local conditions.
Johnsson Filip - One of the best experts on this subject based on the ideXlab platform.
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Techno-Economic Assessment of Fluidized Bed Calcium Looping for Thermochemical Energy Storage with CO2 Capture
SINTEF Academic Press, 2021Co-Authors: Castilla, Guillermo Martinez, Papadokonstantakis Stavros, Guío-pérez, Diana Carolina, Pallarès David, Johnsson FilipAbstract:The multicyclic carbonation-calcination of CaCO3 in fluidized bed reactors is a promising process for both thermochemical energy storage (TCES) and CO2 capture. In this paper, a Techno-Economic Assessment of the calcium loop (CaL) process with simultaneous TCES and CO2 capture from an existing CO2-emitting facility is carried out. Inputs to the process are non-dispatchable high temperature heat and a stream of flue gas, while the process outputs are electricity (both dispatchable and non-dispatchable) and CO2 for compression and storage. The process is sized so the charging section can run steadily during 12h per day and the discharging section to operate steadily 24h per day. The study assesses the economic performance of the process through the breakeven electricity price (BESP) and cost per CO2 captured. The study excludes the costs of the renewable energy plant and the CO2 transport and storage. The sensitivity of the results to the main process and economic parameters is also assessed. Results show that the BESP of the case with the most realistic set of economic predictions ranges between 141 and -20 $/MWh for varying plant size. When assessed as a carbon capture facility with a revenue made from both the electricity sale and the carbon capture services, the cost ranges between 178 and 4 $/tCO2-captured. The investment cost of the reactors is found to be the largest fraction of the computed costs, while the sensitivity analysis points at the degree of conversion in the carbonator as the most crucial parameter, with large cost reductions for increased conversion.publishedVersio
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Techno-Economic Assessment of fluidized bed calcium looping for thermochemical energy storage with CO2 capture
2021Co-Authors: Martinez Castilla Guillermo, Gu\uedo-p\ue9rez, Diana Carolina, Papadokonstantakis Stavros, Pallar\ue8s David, Johnsson FilipAbstract:The multicyclic carbonation-calcination of CaCO3 in fluidized bed reactors is a promising process for both thermochemical energy storage (TCES) and CO2 capture. In this paper, a Techno-Economic Assessment of the calcium loop (CaL) process with simultaneous TCES and CO2 capture from an existing CO2-emitting facility is carried out. Inputs to the process are non-dispatchable high temperature heat and a stream of flue gas, while the process outputs are electricity (both dispatchable and non-dispatchable) and CO2 for compression and storage. The process is sized so the charging section can run steadily during 12h per day and the discharging section to operate steadily 24h per day. The study assesses the economic performance of the process through the breakeven electricity price (BESP) and cost per CO2 captured. The study excludes the costs of the renewable energy plant and the CO2 transport and storage. The sensitivity of the results to the main process and economic parameters is also assessed. Results show that the BESP of the case with the most realistic set of economic predictions ranges between 141 and-20 $/MWh for varying plant size. When assessed as a carbon capture facility with a revenue made from both the electricity sale and the carbon capture services, the cost ranges between 178 and 4 $/tCO2-captured. The investment cost of the reactors is found to be the largest fraction of the computed costs, while the sensitivity analysis points at the degree of conversion in the carbonator as the most crucial parameter, with large cost reductions for increased conversion
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Techno-Economic Assessment of Calcium Looping for Thermochemical Energy Storage with CO2 Capture
'MDPI AG', 2021Co-Authors: Martinez Castilla Guillermo, Gu\uedo-p\ue9rez, Diana Carolina, Papadokonstantakis Stavros, Pallar\ue8s David, Johnsson FilipAbstract:The cyclic carbonation-calcination of CaCO3 in fluidized bed reactors not only offers a possibility for CO2 capture but can at the same time be implemented for thermochemical energy storage (TCES), a feature which will play an important role in a future that has an increasing share of non-dispatchable variable electricity generation (e.g., from wind and solar power). This paper provides a Techno-Economic Assessment of an industrial-scale calcium looping (CaL) process with simultaneous TCES and CO2 capture. The process is assumed to make profit by selling dispatchable electricity and by providing CO2 capture services to a certain nearby emitter (i.e., transport and storage of CO2 are not accounted). Thus, the process is connected to two other facilities located nearby: a renewable non-dispatchable energy source that charges the storage and a plant from which the CO2 in its flue gas flow is captured while discharging the storage and producing dispatchable electricity. The process, which offers the possibility of long-term storage at ambient temperature without any significant energy loss, is herein sized for a given daily energy input under certain boundary conditions, which mandate that the charging section runs steadily for one 12-h period per day and that the discharging section can provide a steady output during 24 h per day. Intercoupled mass and energy balances of the process are computed for the different process elements, followed by the sizing of the main process equipment, after which the economics of the process are computed through cost functions widely used and validated in literature. The economic viability of the process is assessed through the breakeven electricity price (BESP), payback period (PBP), and as cost per ton of CO2 captured. The cost of the renewable energy is excluded from the study, although its potential impact on the process costs if included in the system is assessed. The sensitivities of the computed costs to the main process and economic parameters are also assessed. The results show that for the most realistic economic projections, the BESP ranges from 141 to −20 $/MWh for different plant sizes and a lifetime of 20 years. When the same process is assessed as a carbon capture facility, it yields a cost that ranges from 45 to −27 $/tCO2-captured. The cost of investment in the fluidized bed reactors accounts for most of the computed capital expenses, while an increase in the degree of conversion in the carbonator is identified as a technical goal of major importance for reducing the global cost
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Flexible operation of a combined cycle cogeneration plant - A Techno-Economic Assessment
'Elsevier BV', 2020Co-Authors: Beiron Johanna, Normann Fredrik, Mochol\ued Monta\uf1\ue9s Rub\ue9n, Johnsson FilipAbstract:The need for flexibility in combined heat and power (CHP) plants is expected to increase due to the strong expansion of wind power in electricity systems. Cost-effective strategies to enhance the flexibility of CHP operation are therefore needed. This paper analyzes three types of flexibility measures for a combined cycle CHP plant and their relative impact on the plant operation and revenue. The types of flexibility are: operational flexibility of the fuel conversion system, product flexibility with variable plant product ratios (heat/electricity/primary frequency response), and thermal flexibility in a district heating network. A modeling framework consisting of steady-state and dynamic process simulation models and optimization model is developed to combine static, dynamic, technical and economic perspectives on flexibility. A reference plant serves as a basis for the process model development and validation, and an energy system model provides input profiles for future electricity price scenarios. The results indicate that product flexibility and thermal flexibility have the highest value for the cogeneration plant (up to 16.5\ua0M€ increased revenue for a 250 MWel plant), while operational flexibility (ramp rate) has a comparatively small impact (<1.4\ua0M€). A wide load span and plant versatility, e.g. electricity and heat generating potential between 0 and 139% of nominal capacity, is beneficial in future energy system contexts, but has a marginal value in the current system. Electricity price volatility is a main driver that increases the value of flexibility and promotes operating strategies that follow the electricity price profile rather than the heat demand
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A Techno-Economic Assessment of biomass co-firing in Czech Republic, France, Germany and Poland
'Wiley', 2019Co-Authors: Cutz Luis, Berndes G\uf6ran, Johnsson FilipAbstract:Biomass co-firing with coal can help to reduce greenhouse gas emissions and can act as a low-cost stepping-stone for developing biomass supply infrastructures. This paper presents a Techno-Economic Assessment of the biomass co-firing potential in coal-fired boilers in Czech Republic, France, Germany and Poland. The current coal power plant infrastructure is characterized by means of geographic location of the coal power plants, installed boiler capacity, type of boiler technology and year of commissioning, as extracted from the Chalmers Power Plant Database. The Assessment considers type of boiler technology, type of biomass, co-firing fraction, implementation costs, breakeven prices for co-firing and an alkali index to determine the risk of high-temperature corrosion. The main factors affecting the co-firing potential are the biomass price, carbon price and alkali index. Results indicate that the total co-firing potential in the four countries is around 16 TWh year−1, with the largest potential from a conversion perspective in Germany, followed by Poland. Biomass co-firing with coal is estimated to be competitive at biomass prices below 13\ua0€\ua0MWhinput−1 when the carbon price is 20\ua0€\ua0t−1 CO2. On average, 1 TWh of electricity from biomass co-firing substitutes 0.9\ua0Mt of fossil CO2 emissions. \ua9 2019 Society of Chemical Industry and John Wiley & Sons, Ltd
Amit Kumar - One of the best experts on this subject based on the ideXlab platform.
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Techno-Economic Assessment of wet and dry torrefaction of biomass feedstock
Energy, 2020Co-Authors: Maryam Akbari, Adetoyese Olajire Oyedun, Amit KumarAbstract:Abstract Biomass can be converted to coal-like products known as hydrochar or biochar. Raw biomass generally has high moisture content. Wet torrefaction has gained considerable interest recently because of the unique characteristics of processing high-moisture content to a solid coal-like product. Five biomass feedstocks – wheat straw, pine, grape pomace, animal manure, and algae – were analyzed. The characteristics, as well as mass and energy yields of hydrochars and biochars from these feedstocks, were compared. Process simulation models were developed for both processes for each feedstock and Techno-Economic Assessments conducted. The results indicate that hydrochars have superior characteristics, more coal-like properties, lower yields, and a higher cost of production (COP) than biochars for all cases except the pathways using manure as feedstock, where hydrochar COP is lower. The lowest production costs (without carbon credit) can be achieved through dry and wet torrefaction of grape pomace at 2.29 $/GJ and 4.14 $/GJ, respectively. Sensitivity and uncertainty analyses were also conducted for all pathways to understand the effects on production cost of varying different technical and economic factors. The results of this study will provide valuable insights into coal alternative products, especially in jurisdictions (like Alberta, Canada) planning to phase out coal plants.
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a comparative analysis of hydrogen production from the thermochemical conversion of algal biomass
International Journal of Hydrogen Energy, 2019Co-Authors: Mayank Kumar, Adetoyese Olajire Oyedun, Amit KumarAbstract:Abstract Gasification has the potential to convert biomass into gaseous mixtures that can be used for hydrogen production. Thermal gasification and supercritical water gasification are commonly used thermochemical methods for conversion of biomass to hydrogen. Supercritical water gasification handles wet biomass, thus eliminating the capital cost-intensive drying step. Thermal gasification is considered as an alternative means of producing hydrogen from microalgae where biomass has to be dried before gasification. The authors developed Techno-Economic models for Assessment of the production of hydrogen through supercritical gasification and thermal gasification processes. Techno-Economic Assessment was based on developed process models. Equipment was sized and costs were estimated using the developed process models, and the product value was determined assuming 20 years of plant life. The economic Assessment of supercritical water and thermal gasification show that 2000 dry tonnes/day plant requires total capital investments of 277.8 M$ and 215.3 M$ for hydrogen product values of $4.59 ± 0.10/kg and $5.66 ± 0.10/kg, respectively. The relatively higher yield obtained in supercritical water gasification compared to thermal gasification results in lower product value of hydrogen for supercritical water gasification, thereby making it more desirable. This cost of hydrogen is about 4 times the cost of hydrogen from natural gas. The sensitivity analysis indicates that biomass cost and yield are the most sensitive parameters in the economics of the supercritical or thermal gasification process; this signifies the importance of algal biomass availability. The Techno-Economic Assessment helps to identify options for the production of hydrogen fuel through these novel technologies.
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Techno-Economic Assessment of pellets produced from steam pretreated biomass feedstock
Biomass and Bioenergy, 2016Co-Authors: Hassan Shahrukh, Amit Kumar, Adetoyese Olajire Oyedun, Bahman Ghiasi, Linoj Kumar, Shahab SokhansanjAbstract:Abstract Minimum production cost and optimum plant size are determined for pellet plants for three types of biomass feedstock – forest residue, agricultural residue, and energy crops. The life cycle cost from harvesting to the delivery of the pellets to the co-firing facility is evaluated. The cost varies from 95 to 105 $ t −1 for regular pellets and 146–156 $ t −1 for steam pretreated pellets. The difference in the cost of producing regular and steam pretreated pellets per unit energy is in the range of 2–3 $ GJ −1 . The economic optimum plant size (i.e., the size at which pellet production cost is minimum) is found to be 190 kt for regular pellet production and 250 kt for steam pretreated pellet. Sensitivity and uncertainty analyses were carried out to identify sensitivity parameters and effects of model error.
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techno economic Assessment of hydrogenation derived renewable diesel production from canola and camelina
Sustainable Energy Technologies and Assessments, 2014Co-Authors: Patrick Miller, Amit KumarAbstract:Abstract In this study, production cost of hydrogenation-derived renewable diesel (HDRD) was estimated using canola oil and camelina oil as feedstocks. Process simulation models were built based on experimental data to simulate the conversion of vegetable oil to n -alkanes primarily in the range of C9–C22. These models were used to estimate capital and operating costs to conduct a Techno-Economic Assessment for a range of HDRD plant sizes (15–1161 million L/year, or 250–20,000 bbl/day) operating in Western Canada. The minimum costs of production for HDRD occurred at a plant optimum size of 812 million L/year (14,000 bbl/day). These minimum costs were $1.09/L for HDRD from canola oil, $0.85/L for HDRD from camelina oil if camelina meal can be sold, and $1.37/L for HDRD from camelina oil if camelina cannot be sold. The HDRD production cost varies significantly for small production plants but only varies by a few cents per liter for plants in the size range of 290–1161 million L/year (5000–20,000 bbl/day). Sensitivity analyses conducted indicate that HDRD production cost is not very sensitive to capital and operating costs, but is highly sensitive to feedstock cost, solvent price, and solvent recovery.
