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1
Yuliansyah, Rendy, Aditya Idamsyah, Irwan Paundra und Bambang Priyono. „Techno Economy Comparison of Conventional Generating Unit and Lithium Battery Energy Storage as a Primary Frequency Regulation of Variable Renewable Energy Penetrated Grid System, Case Study: Southern Sulawesi of Indonesia“. European Journal of Engineering Science and Technology 4, Nr. 3 (20.12.2021): 25–38. http://dx.doi.org/10.33422/ejest.v4i3.739.
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Integrating higher shares energy mix of variable renewable energy (VRE) technologies, such as wind and solar PV, in the energy transition process presents many challenges in its operation. One of the required services needed in this activity is the Primary Frequency Regulation (PFR). Many studies have studied various ways to provide PFR services, such as using the Conventional Generating Unit (CGU) and Lithium Battery Energy Storage (LiBESS). This paper presents several battery sizing methods used for comparison between the Levelized Cost of Electricity (LCOE) of a CGU and the Levelized Cost of Storage (LCOS) of a LiBESS, which used as PFR of a VRE penetrated grid system in a case study: the grid of southern Sulawesi, Indonesia. The results show that the LCOE of LiBESS is still below the LCOE of the CGU, but for projections in 2030, the LCOS LiBESS shows a competitive number compared to the LCOE of CGU.
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Tahir, Mustafa, Sideng Hu und Haoqi Zhu. „Advanced Levelized Cost Evaluation Method for Electric Vehicle Stations Concurrently Producing Electricity and Hydrogen“. Energies 17, Nr. 11 (31.05.2024): 2682. http://dx.doi.org/10.3390/en17112682.
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This study develops a new method to evaluate the economic viability of co-generation electric vehicle stations that concurrently generate electricity and hydrogen for charging battery electric vehicles and refueling hydrogen vehicles. The approach uniquely differentiates the costs associated with various energy outputs in co-generation stations and includes often-overlooked peripheral devices critical for accurate evaluation of the levelized cost of electricity (LCOE) and hydrogen (LCOH). The method was tested across three design configurations: two featuring single storage options (battery and fuel cell, respectively) and a third using hybrid storage employing both. Each configuration was modeled, simulated, and optimized using HOMER Pro 3.14.2 to determine the most optimal sizing solution. Then, based on the optimal sizing of each design, LCOE and LCOH were evaluated using the proposed method in this study. The analysis revealed that excluding often-overlooked peripheral devices could lead to a 27.7% error in LCOH evaluation, while the impact on LCOE was less than 1%. Among different configurations, the design with hybrid storage proved economically superior, achieving a total levelized cost of energy (TLCOE) for the entire system of USD 0.113/kWh, with the LCOE at USD 0.025/kWh and LCOH at USD 0.088/kWh (or USD 3.46/kg). Comparative analysis with state-of-the-art studies confirmed the accuracy of the proposed method. This study provides a more precise and holistic approach that can be leveraged for the feasibility analysis of electric vehicle stations globally, enhancing strategic decision-making in sustainable energy planning.
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Urs, Rahul Rajeevkumar, Muhammad Sadiq, Ahmad Mayyas und Ameena Al Sumaiti. „Technoeconomic Assessment of Various Configurations Photovoltaic Systems for Energy and Hydrogen Production“. International Journal of Energy Research 2023 (06.02.2023): 1–13. http://dx.doi.org/10.1155/2023/1612600.
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Photovoltaic (PV) system grid integration is becoming more global to minimize carbon emissions from traditional power systems. However, alternative solution investigation for maximum technical and economic benefits is often neglected when integrating PV systems. This study utilizes a methodology for evaluating the lifecycle energy generation and levelized cost of energy (LCOE) of PV systems with various configurations using a holistic approach that considers PV system expenditures from installation to the end-of-life PV system operation. In addition, this work focuses on finding a better configuration with different PV modules (monofacial or bifacial) and structure types (mounted or single-axis) for three different utility scale PV sizes (300 kW, 500 kW, and 1000 kW) in Abu Dhabi, UAE, with the maximum power generation and minimal energy losses. Furthermore, the best suitable configuration was identified to be the configuration with a single-axis tracking structure and bifacial PV modules based on their technical and economic performance for the location with two different surface albedo, 0.2 and 0.8. We also study the PV system’s connection in a standalone off-grid solar-electrolyzer combination to produce green hydrogen. Levelized cost of electricity (LCOE) and levelized cost of hydrogen production (LCOH) are calculated, and results show that such PV systems can be used to generate electricity and produce hydrogen at competitive costs that can reach as low as 2.1 cent/kWh and $2.53/kg-H2 for LCOE and LCOH, respectively. Such a low cost is very competitive and can be used to attract new investments in green hydrogen technology in the United Arab Emirates.
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Homeida, Azzam, Omar Algrouni, Shafiqur Rehman und Zeeshan Anwar. „Techno-economic analysis of a wind/ solar PV hybrid power system to provide electricity for green hydrogen production“. FME Transactions 52, Nr. 4 (2024): 647–58. http://dx.doi.org/10.5937/fme2404647h.
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Green hydrogen (GH) is recognized as a fundamental pillar in shaping a sustainable global future. The process involves the hydrolysis of water with sustainable electrical sources. This paper presents a techno-economic assessment of hybrid renewable wind and solar power systems in Yanbu, Saudi Arabia, to provide clean energy to enhance carbon-natural petrochemical operations. The implementation of Energy Compensation Policies, such as Net Energy Metering or Net Energy Billing Mechanisms, has a substantial influence on the financial viability of GH Plant. The present research compared the impact of such a mechanism on the levelized cost of Energy (LCOE) and the Levelized cost of Hydrogen (LCOH). The study recommended the adoption of a Net Metering Mechanism as a highly efficient strategy to encourage private sector investment in renewable energy production in the Kingdom of Saudi Arabia (KSA). This approach was found to be effective, resulting in an accumulated electricity tariff of 26.5 $/MWh and a levelized cost of hydrogen (LCOH) of 1.65 $/kg.
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Thai, Clinton, und Jack Brouwer. „Comparative Levelized Cost Analysis of Transmitting Renewable Solar Energy“. Energies 16, Nr. 4 (14.02.2023): 1880. http://dx.doi.org/10.3390/en16041880.
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A bottom-up cost analysis for delivering utility-scale PV-generated electricity as hydrogen through pipelines and as electricity through power is undertaken. Techno-economic, generation, and demand data for California are used to calculate the levelized cost of transmitting (LCOT) energy and the levelized cost of electricity (LCOE) prior to distribution. High-voltage levels of 230 kV and 500 kV and 24-inch and 36-inch pipelines for 100 to 700 miles of transmission are considered. At 100 miles of transmission, the cost of transmission between each medium is comparable. At longer distances, the pipeline scenarios become increasingly cheaper at low utilization levels. The all-electric pathways utilizing battery energy storage systems can meet 95% of the load for as low as 356 USD/MWh, whereas when meeting 100% of load with the hydrogen gas turbine and fuel cell pathways, the costs are 278 and 322 USD/MWh, respectively.
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Lucio, Cesar, Omar Behar und Bassam Dally. „Techno-Economic Assessment of CPVT Spectral Splitting Technology: A Case Study on Saudi Arabia“. Energies 16, Nr. 14 (14.07.2023): 5392. http://dx.doi.org/10.3390/en16145392.
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Concentrating PV thermal (CPVT) collector with spectral splitting technology is a promising solution for heat and electricity production. To extend the use of this technology, a novel and cost-effective CPVT collector for harsh environments, such as those in Saudi Arabia, is presented and evaluated using theoretical energy, economy, and environmental analysis. Two questions are answered in this study, namely: which is the best operation strategy, and which is the best energy storage technology for CPVT. The potential of using a CPVT under the climate conditions of six cities in Saudi Arabia is also evaluated. It is found that a heat/electricity production strategy and a thermal energy storage are the most suitable for the CPVT technology. The economic assessment shows a levelized cost of electricity (LCOE) of $0.0847/kWh and a levelized cost of heat (LCOH) of $0.0536/kWh when water is used as a spectral filter, and a LCOE of $0.0906/kWh and a LCOH of $0.0462/kWh when ZnO nanoparticles are added. The CO2-equivalent emissions in a 20 MW CPVT plant are cut from 5675 tonnes to 7822 tonnes per year for Saudi Arabian weather and present power generation conditions.
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Lee, Chul-Yong, und Jaekyun Ahn. „Stochastic Modeling of the Levelized Cost of Electricity for Solar PV“. Energies 13, Nr. 11 (11.06.2020): 3017. http://dx.doi.org/10.3390/en13113017.
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With the development of renewable energy, a key measure for reducing greenhouse gas emissions, interest in the levelized cost of electricity (LCOE) is increasing. Although the input variables used in the LCOE calculation, such as capacity factor, capital expenditure, annual power plant operations and maintenance cost, discount and interest rate, and economic life, vary according to region and project, most existing studies estimate the LCOE by using a deterministic methodology. In this study, the stochastic approach was used to estimate the LCOE for solar photovoltaic (PV) in South Korea. In addition, this study contributed to deriving realistic analysis results by securing the actual data generated in the solar PV project compared to the existing studies. The results indicate that the LCOE for commercial solar power ranged from KRW 115 (10 cents)/kWh to KRW 197.4 (18 cents)/kWh at a confidence level of 95%. The median was estimated at KRW 160.03 (15 cents)/kWh. The LCOE for residential solar power ranged from KRW 109.7 (10 cents)/kWh to KRW 194.1 (18 cents)/kWh at a 95% confidence level and a median value of KRW 160.03 (15 cents)/kWh. A sensitivity analysis shows that capital expenditure has the most significant impact on the LCOE for solar power, followed by the discount rate and corporate tax. This study proposes that policymakers implement energy policies to reduce solar PV hardware and soft costs.
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Oueslati, Fakher. „HOMER optimization of standalone PV/Wind/Battery powered hydrogen refueling stations located at twenty selected French cities“. International Journal of Renewable Energy Development 12, Nr. 6 (20.10.2023): 1070–90. http://dx.doi.org/10.14710/ijred.2023.58218.
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The current study proposes a model of autonomous Hydrogen Refuelling Stations (HRFS) installed on different sites in twenty French cities powered by renewable clean energy sources. The station is fully powered by photovoltaic (PV) panels, wind turbines with battery storage and involving an electrolyzer and hydrogen tank for producing and storing hydrogen. Using Homer simulation, three scenarios are investigated to propose an optimized model, namely Scenario 1 containing (PV-Wind-Battery) system, Scenario 2 with (Wind-Battery) technologies and Scenario 3 with (PV-Battery) components. The otimization process executed demonstrates very competitive levelized cost of energy (LCOE) and levelized cost of hydrogen (LCOH) especially for the third scenario solely based on PV power with LCOE in range $0.354-0.435/kWh and a LCOH varying within $13.5-16.5/kg, for all 20 cities. An average net present cost (NPC) value of $ 1,561,429 and $ 2,522,727 are predicted for the first and second architectures while least net present cost of $1,038,117 is estimated for the third combination solely based on solar power according to all sites considered. For instance, minimum values are obtained for Marseille city with LCOE=$ 0.354/kWh and a LCOH=$ 13.5 /kg in conformity with the minimum obtained value of NPC value of $886,464 with respect to the winner third scenario. In addition, more costly hydrogen production is expected for Grenoble city especially for scenario 1 and 2 where wind turbine technology is introduced. On another hand, thorough analysis of PV/wind hydrogen techno-economic operation is provided including improvements recommendations, scenarios comparison and environmental impact discussion.
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Guo, Chenglong, Wanan Sheng, Dakshina G. De Silva und George Aggidis. „A Review of the Levelized Cost of Wave Energy Based on a Techno-Economic Model“. Energies 16, Nr. 5 (22.02.2023): 2144. http://dx.doi.org/10.3390/en16052144.
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Wave energy provides a renewable and clear power for the future energy mix and fights against climate change. Currently, there are many different wave energy converters, but their costs of extracting wave energy are still much higher than other matured renewables. One of the best indicators of calculating the generating cost of wave energy is the ‘levelized cost of energy’ (LCOE), which is the combined capital expenditure (CAPEX), operational expenditure (OPEX), and decommissioning cost with the inclusion of the annual energy production, discount factor, and project’s lifespan. However, the results of the LCOE are in disagreement. Hence, it is important to explore the cost breakdown of wave energy by the wave energy converter (WEC), so for finding potential ways to decrease the cost, and finally compare it with other renewable energies. Different WECs have been installed in the same place; the Wave Dragon LCOE platform is the best one, with an energy conversion of EUR 316.90/MWh, followed by Pelamis with EUR 735.94/MWh and AquaBuOY with EUR 2967.85/MWh. Even when using different locations to test, the rank of the LCOE would remain unchanged with the different value. As the CAPEX and OPEX dramatically drop, the availability and capacity factors slowly increase, and the LCOE decreases from a maximum of USD 470/MWh to a minimum of USD 120/MWh. When the discount rate is down from 11% to 6%, the LCOE reduces from USD 160/MWh to USD 102/MWh. Under the ideal condition of the optimal combination of multiple factors, in theory, the LCOE can be less than USD 0.3/KWh. To better explore the LCOE for WECs, the detailed cost elements found in the CAPEX and OPEX have been examined for the scenarios of the undiscounted, half-discounted, and discounted cost models. When the AEP is discounted, the lowest LCOE is equal to USD 1.171/kWh in scene 2 when using a five-step investment, which is below the LCOE value of USD 1.211/kWh in scene 1 when using a two-step investment. Meanwhile, the highest LCOE amounts to USD 2.416/kWh using the five-step investment, whose value is below the LCOE of a two-step investment. When using a one-step investment in scene 3, the lowest LCOE is equal to USD 0.296/kWh, which accounts for 25% of the lowest value in the five-step investment. Meanwhile, the highest LCOE amounts to USD 0.616/kWh, which accounts for 24% of the highest value in the two-step investment. The results of the case study show that a one-step investment program in the half-discounted model is superior to the multi-step investment in the discounted model. This paper examines the viability of wave energy technologies, which is a critical factor for the LCOE of wave energy; furthermore, the form of investment in the wave energy project is also important when calculating the LCOE.
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Xia, Tian, Mostafa Rezaei, Udaya Dampage, Sulaiman Ali Alharbi, Omaima Nasif, Piotr F. Borowski und Mohamed A. Mohamed. „Techno-Economic Assessment of a Grid-Independent Hybrid Power Plant for Co-Supplying a Remote Micro-Community with Electricity and Hydrogen“. Processes 9, Nr. 8 (06.08.2021): 1375. http://dx.doi.org/10.3390/pr9081375.
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This study investigates the techno-economic feasibility of an off-grid integrated solar/wind/hydrokinetic plant to co-generate electricity and hydrogen for a remote micro-community. In addition to the techno-economic viability assessment of the proposed system via HOMER (hybrid optimization of multiple energy resources), a sensitivity analysis is conducted to ascertain the impact of ±10% fluctuations in wind speed, solar radiation, temperature, and water velocity on annual electric production, unmet electricity load, LCOE (levelized cost of electricity), and NPC (net present cost). For this, a far-off village with 15 households is selected as the case study. The results reveal that the NPC, LCOE, and LCOH (levelized cost of hydrogen) of the system are equal to $333,074, 0.1155 $/kWh, and 4.59 $/kg, respectively. Technical analysis indicates that the PV system with the rated capacity of 40 kW accounts for 43.7% of total electricity generation. This portion for the wind turbine and the hydrokinetic turbine with nominal capacities of 10 kW and 20 kW equates to 23.6% and 32.6%, respectively. Finally, the results of sensitivity assessment show that among the four variables only a +10% fluctuation in water velocity causes a 20% decline in NPC and LCOE.
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Gaborieau, Maëlig, Ozlem Ceyhan Yilmaz und Katherine Dykes. „Economic impact assessment of Hydrogen generated from Offshore Wind: A case study for Belgium“. Journal of Physics: Conference Series 2507, Nr. 1 (01.05.2023): 012012. http://dx.doi.org/10.1088/1742-6596/2507/1/012012.
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Abstract Green hydrogen is increasingly cited as a solution to the decarbonisation of industry. Its large-scale production is still a recent topic with uncertainties. In this paper, an economic impact assessment (EIA) method is explained. A modular and flexible cost model is generated, which estimates the LCOE (Levelized Cost of Energy) of an offshore wind farm and the LCOH (Levelized Cost of Hydrogen) of a hydrogen generation plant either as a hybrid renewable energy system (HRES) or independent from each other. The costs are estimated using a schedule-based approach, which considers the reliability, maintenance operations as well as production of both the offshore wind farm and the hydrogen generation plant. Developed EIA is demonstrated for Belgium using Mermaid Offshore Wind Farm.
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Fairuz, Riadhi, Eko Adhi Setiawan und Ikhsan Hernanda. „Mapping and Analysis of Initial cost Against Levelized Cost of Energy for Residential PV Rooftoop in Indonesia“. E3S Web of Conferences 67 (2018): 01024. http://dx.doi.org/10.1051/e3sconf/20186701024.
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Future electricity tariffs are expected to increase. To overcome this condition, arise the idea how the residential can generate its own electricity by exploiting the potential of solar energy. However, there are some constraints in its implementation due to the difference of the initial cost and sales from solar PV systems in various region of Indonesia. The purpose of this study is to determine the impact of initial cost on the levelized cost of energy from the system. This study uses the calculation of Levelized Cost of Energy (LCoE) and economic feasibility analysis through the calculation of net present value with net metering scheme. Manado is the most optimal city to implement this system. The initial cost will affect to the LCoE, the high initial cost can be covered by the amount of cash flow generated by the system which has huge solar irradiation potentials.
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Mbouteu Megaptche, Christelle Arielle, Hanki Kim, Peter Moses Musau, Sebastian Waita und Bernard Aduda. „Techno-Economic Comparative Analysis of Two Hybrid Renewable Energy Systems for Powering a Simulated House, including a Hydrogen Vehicle Load at Jeju Island“. Energies 16, Nr. 23 (29.11.2023): 7836. http://dx.doi.org/10.3390/en16237836.
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This work undertakes a techno-economic comparative analysis of the design of photovoltaic panel/wind turbine/electrolyzer-H2 tank–fuel cell/electrolyzer-H2 tank (configuration 1) and photovoltaic panel/wind turbine/battery/electrolyzer-H2 tank (configuration 2) to supply electricity to a simulated house and a hydrogen-powered vehicle on Jeju Island. The aim is to find a system that will make optimum use of the excess energy produced by renewable energies to power the hydrogen vehicle while guaranteeing the reliability and cost-effectiveness of the entire system. In addition to evaluating the Loss of Power Supply Probability (LPSP) and the Levelized Cost of Energy (LCOE), the search for achieving that objective leads to the evaluation of two new performance indicators: Loss of Hydrogen Supply Probability (LHSP) and Levelized Cost of Hydrogen (LCOH). After analysis, for 0 < LPSP < 1 and 0 < LHSP < 1 used as the constraints in a multi-objective genetic algorithm, configuration 1 turns out to be the most efficient loads feeder with an LCOE of 0.3322 USD/kWh, an LPSP of 0% concerning the simulated house load, an LCOH of 11.5671 USD/kg for a 5 kg hydrogen storage, and an LHSP of 0.0043% regarding the hydrogen vehicle load.
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Khojasteh, Hasanali, Younes Noorollahi, Mojtaba Tahani und Mehran Masdari. „Optimization of Power and Levelized Cost for Shrouded Small Wind Turbine“. Inventions 5, Nr. 4 (09.12.2020): 59. http://dx.doi.org/10.3390/inventions5040059.
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Nowadays, by increasing energy demand and considering the importance of environmental issues in recent decades, the use of renewable energies is expanding. Among renewable energies, wind power and its technology are growing and evolving more rapidly. Resource assessment in Iran has revealed the significant potential of wind energy around the country. To further develop wind energy in the country and create large-scale wind power plants, the consideration of distributed power generation using small wind turbines for applications in agricultural and residential use is needed. Conventional small wind turbines and small wind lens turbines have been developed in recent years. In this research project, a small wind lens turbine is designed. The advantages of this turbine are an increased production capacity and reduced cut-in speed and noise pollution. In this study, a lens (or shroud) is added to a small turbine, and the maximized annual energy production (AEP) and minimization of the levelized cost of energy (LCOE) are modeled. We applied the NSGA-II algorithm for optimization to find the best answer. The input parameters in the objective function of the AEP are cut-in, cut-out, rated speeds, scale factor, and shape factor. Additionally, the input parameters in the objective function of the LCOE are the power production, initial capital cost, annual operating expenses, and balance of energy. The results indicate that installing a wind lens turbine in Kish Island led to an LCOE decrease of 56% on average, and we can see an 83% increase in the AEP. In the Firoozkooh area, an average reduction of 59% in the LCOE and 74% increase in the AEP for a wind lens turbine is observed.
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Mehta, Mihir, Michiel Zaaijer und Dominic von Terzi. „Optimum Turbine Design for Hydrogen Production from Offshore Wind“. Journal of Physics: Conference Series 2265, Nr. 4 (01.05.2022): 042061. http://dx.doi.org/10.1088/1742-6596/2265/4/042061.
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Abstract To limit the consequences of climate change, generation from renewables coupled with large scale electrification is necessary. However, the deployment of renewables has its own challenges and not all sectors can be electrified. Hydrogen production from wind energy emerges as a promising solution that can alleviate these challenges. The current costs of green hydrogen production are high due to the high costs of electricity used for electrolysis. This study looks into the benefits of optimizing a turbine specifically for hydrogen production and the reduction in the Levelized Cost of Hydrogen (LCoH) compared to the use of conventional Levelized Cost of Energy (LCoE) optimized turbine. The case presented shows that turbines designed specifically for hydrogen production tend to have a higher specific power but these provide only a marginal advantage over using LCoE-optimized turbines for hydrogen production. Oversizing the electrolyzer compared to the turbine was shown to be a good design strategy. In the future, designing turbines specifically for hydrogen production could have certain benefits, depending on how the electrolyzer efficiencies, hydrogen production costs and the hydrogen market evolve.
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Kuckshinrichs, Wilhelm. „LCOE: A Useful and Valid Indicator—Replica to James Loewen and Adam Szymanski“. Energies 14, Nr. 2 (13.01.2021): 406. http://dx.doi.org/10.3390/en14020406.
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Chai, Zhe, Xing Chen, Shuo Yin, Man Jin, Xin Wang, Xingwu Guo und Yao Lu. „Construction of a new levelled cost model for energy storage based on LCOE and learning curve“. E3S Web of Conferences 338 (2022): 01049. http://dx.doi.org/10.1051/e3sconf/202233801049.
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New energy storage is essential to the realization of the “dual carbon” goal and the new power system with new energy as the main body, but its cost is relatively high and the economy is poor at present. This paper studies the levelized cost of new energy storage based on the whole life cycle perspective. Based on LCOE and learning curve methods, a new levelled cost estimation model and prediction model for energy storage are constructed. Based on the latest development status of electrochemical new energy storage, the levelized cost of energy of lithium-ion batteries, flow-aluminum batteries, and flow-zinc batteries were measured, the cost composition and proportion of various types of energy storage are analyzed, and on this basis, the levelized cost of lithium-ion batteries was predicted. Comparative analysis shows that the levelized cost per kilowatt-hour of lithium-ion batteries is the lowest. This article provides a certain reference for the construction and layout of energy storage on three sides of the source network and load.
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Li, Taiqi. „The influence of photovoltaic panel spacing on levelized cost of electricity“. Journal of Physics: Conference Series 2786, Nr. 1 (01.06.2024): 012020. http://dx.doi.org/10.1088/1742-6596/2786/1/012020.
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Abstract The efficiency and economic viability of photovoltaic (PV) systems are key determinants of solar energy adoption and diffusion. In order to investigate the correlation between PV panel spacing and levelised cost of electricity (LCOE), the existing methods for optimizing PV design are first investigated and summarized. Numerical methods are then chosen to simulate the construction of a PV farm in Brisbane, and modelling simulations are carried out with PVsyst and SAM to derive the Shading loss and LCOE for different panel spacing. It is found that closer panel spacing may increase the number of panels per unit area, but also cause shading loss during peak hours. Conversely, wider spacing can reduce potential shading effects and increase the efficiency of individual panels, but it requires more land or installation infrastructure. The analysis reveals a non-linear relationship between panel spacing and LCOE, with the optimal spacing range providing the lowest LCOE. This study highlights the need for site-specific spacing optimization to achieve cost-effective PV deployments.
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Barthelmie, Rebecca J., Gunner C. Larsen und Sara C. Pryor. „Modeling Annual Electricity Production and Levelized Cost of Energy from the US East Coast Offshore Wind Energy Lease Areas“. Energies 16, Nr. 12 (06.06.2023): 4550. http://dx.doi.org/10.3390/en16124550.
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Offshore wind energy development along the East Coast of the US is proceeding quickly as a result of large areas with an excellent wind resource, low water depths and proximity to large electricity markets. Careful planning of wind turbine deployments in these offshore wind energy lease areas (LA) is required to maximize power output and to minimize wake losses between neighboring wind farms as well as those internal to each wind farm. Here, we used microscale wind modeling with two wake parameterizations to evaluate the potential annual energy production (AEP) and wake losses in the different LA areas, and we developed and applied a levelized cost of energy (LCoE) model to quantify the impact of different wind turbine layouts on LCoE. The modeling illustrated that if the current suite of LA is subject to deployment of 15 MW wind turbines at a spacing of 1.85 km, they will generate 4 to 4.6% of total national electricity demand. The LCoE ranged from $68 to $102/MWh depending on the precise layout selected, which is cost competitive with many other generation sources. The scale of the wind farms that will be deployed greatly exceed those currently operating and mean that wake-induced power losses are considerable but still relatively poorly constrained. AEP and LCoE exhibited significant dependence on the precise wake model applied. For the largest LA, the AEP differed by over 10% depending on the wake model used, leading to a $10/MWh difference in LCoE for the wind turbine layout with 1.85 km spacing.
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Hwang, Kyu-Won, und Chul-Yong Lee. „Estimating the Deterministic and Stochastic Levelized Cost of the Energy of Fence-Type Agrivoltaics“. Energies 17, Nr. 8 (18.04.2024): 1932. http://dx.doi.org/10.3390/en17081932.
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Agrivoltaics can be used to supply energy and produce agricultural products in order to meet the growing demand for energy and food. The amount of power generation is affected by the solar panel direction, spacing, tilt, and panel technology; however, there is insufficient empirical data-based research on the operation of agrivoltaics. This study estimates the levelized cost of energy (LCOE) for a fence-based agrivoltaics system using bifacial modules. This study installed and operated photovoltaic (PV) systems on a rice paddy and saltern in South Korea to estimate the input variables that could affect their economic efficiency and LCOE. For the research methods, this study used Monte Carlo simulation (a stochastic analysis method that reflects the uncertainty of the input variables), a deterministic LCOE analysis, and a sensitivity analysis of the input variables. In terms of space utilization, the LCOE of the paddy system (139.07~141.19 KRW/kWh) was found to be relatively lower than that of the saltern system (145.43~146.18 KRW/kWh), implying that the PV system on the paddy was economically favorable. In terms of installation direction, it was more economical to operate the southwest-facing panels (139.07~145.43 KRW/kWh) than the southeast-facing panels (141.19~146.18 KRW/kWh). This study provides foundational policy data for the adoption of fence-based agrivoltaics and contributes to the widespread and active use of agrivoltaics.
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Tadbiri-Nooshabadi, Morteza, Jean-Luc Schanen, Shahrokh Farhangi, Hossein Iman-Eini und Corentin Rizet. „Optimal Design of PV Inverter Using LCOE Index“. Energies 16, Nr. 5 (24.02.2023): 2213. http://dx.doi.org/10.3390/en16052213.
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This work uses design optimization of a power electronics converter to achieve the best levelized cost of energy in a PV application. The methodology uses detailed models of power electronics’ active and passive components to determine the cost and performances of the solid-state energy conversion and connect them to the system-level vision. The deterministic algorithm used for converter sizing allows taking into account a large number of variables and constraints. Methodology, models, and some illustrations of the results are provided in this paper. A sensitivity analysis was also conducted on the cost model.
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Sung, Sanghyun, und Wooyong Jung. „Economic Competitiveness Evaluation of the Energy Sources: Comparison between a Financial Model and Levelized Cost of Electricity Analysis“. Energies 12, Nr. 21 (27.10.2019): 4101. http://dx.doi.org/10.3390/en12214101.
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The levelized cost of electricity (LCOE) is used widely to compare the economic competitiveness of the energy mix. This method is easy to understand and simple to apply, which makes it preferable for many energy policymakers. However, the method has several disadvantages from the energy business perspective. First, the LCOE approach does not consider revenue, and a high-interest rate usually correlates with the tariff growth rate. Thus, if a high-interest rate increases the cost, that high rate increases the revenue, which can affect economic competitiveness. Second, the LCOE does not consider different stakeholders. Equity investors and loan investors have different interests depending on different financial indicators, which influence the same energy sources’ differential economic attractiveness. This study analyzes and compares the LCOE, Project Internal Rate of Return (Project IRR), Equity Internal Rate of Return (Equity IRR), and Debt Service Coverage Ratio (DSCR) of an illustrative wind, coal, and nuclear power project using Monte-Carlo simulations. The results show that energy sources’ economic competitiveness can vary depending on financial indicators. This study will help energy policymakers develop more economically realistic energy portfolios.
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Mendonça, Anny Key de Souza, und Antonio Cezar Bornia. „Electric power generation in wind farms with pumping kites: levelized cost of energy and sensitivity analysis“. Research, Society and Development 9, Nr. 7 (01.06.2020): e666974528. http://dx.doi.org/10.33448/rsd-v9i7.4528.
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This research aims to analyze the levelized level energy cost of energy (LCOE) of wind farms with tethered airfoils. For this, it was considering the technical characteristics of the system, the location of operation, the necessary investments and the characteristics of the Brazilian market, to analyze the levelized cost of energy of three wind farm scenarios: Classic wind farm, Wind farm with tethered airfoils operating in Pumping Kite mode and a hybrid park with the two park configurations studied. The research makes use of the LCOE method. The results indicate that the technology with wired airfoils requires less investment and that wind farms with this technology can generate more energy than a classic wind farm of the same nominal power, since the wired airfoils can exploit high altitude winds, where they are more frequent and strong. The results also indicate that wind farms with wired airfoils are not only economically viable, but produce energy at a level cost, well below the values currently practiced for the sale of energy in the domestic market.
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Villada, F., J. D. Saldarriaga-Loaiza und J. M. López-Lezama. „Incentives for Renewable Energies in Colombia“. Renewable Energy and Power Quality Journal 19 (September 2021): 24–26. http://dx.doi.org/10.24084/repqj19.203.
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This work analyses the potential effects of the incentives for renewable energies approved in Colombia by two main acts. A methodology involving adjustments for tax reductions and accelerated depreciation is used to evaluate the Levelized Cost of Electricity (LCOE) for the four main clean energy resources available in Colombia. The results show important reductions in the LCOE specially, under the act approved in the development plan of the new government, where the LCOE of three technologies is below the grid parity.
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Vlaykova, Olga, Teodora Hristova, Boris Evstatiev und Martin Boyadjiev. „Methodology for choosing a hydrogen source based on a point system“. E3S Web of Conferences 551 (2024): 02003. http://dx.doi.org/10.1051/e3sconf/202455102003.
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The article examines the usage of hydrogen in gas transmission pipes as one of the measures to achieve the criteria of sustainable development and reduction of carbon emissions. Regarding choosing an appropriate kind, hydrogen sources have been analyzed. Due to the multifactorial nature of the task, such as raw material, price, efficiency, popularity, and the availability of many studies, a point system was developed to evaluate the alternatives with significant criteria. On its basis, it was established that the cheapest and gentlest natural method is the electrolysis of water. For this purpose, electrolysis methods have been evaluated, and efficiency depends on the energy source. Given the dependence of the price of energy on the country's energy mix, a point system is proposed based on the parameters: hydrogen's levelized cost LCOH and levelized cost of electricity (LCOE). The newest criterion is the citation rating which gives popularity and an opportunity for new research.
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Kinne, Marko, Muhammad Farhan, Ronald Schneider und Sebastian Thöns. „Influence of the structural integrity management on the levelized cost of energy of offshore wind: a parametric sensitivity analysis“. Acta Polytechnica CTU Proceedings 36 (18.08.2022): 90–98. http://dx.doi.org/10.14311/app.2022.36.0090.
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The levelized cost of energy (LCoE) is an important measure to quantify the macro-economic efficiency of an offshore wind farm and to enable a quantitative comparison with other types of energy production. The costs of the structural integrity management - which is required to ensure an adequate lifetime reliability of the turbine support structures - are part of the operational expenditures of an offshore wind farm. An optimization of the structural integrity management may reduce the operational expenditures and consequently the LCoE. However, the effect of the structural integrity management on the LCoE is hardly known. To investigate this effect, this paper presents a sensitivity analysis of the LCoE of a generic offshore wind farm. The probabilistic models of the parameters influencing the LCoE are based on a literature study including an explicit model for the structural integrity management. The analysis reveals that LCoE may potentially be reduced if an optimization of the structural integrity management enables a service life extension.
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Timalsina, Dipak, und Davoud Ghahremanlou. „Optimizing Wind-to-Hydrogen Production in Newfoundland for Export: A Techno-Economic Perspective“. European Journal of Energy Research 4, Nr. 2 (18.06.2024): 28–35. http://dx.doi.org/10.24018/ejenergy.2024.4.2.139.
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This study explores the feasibility of generating green hydrogen using wind energy in Newfoundland and Labrador (NL) for potential export to Germany, aiming to reduce their heavy reliance on grey hydrogen. NL features abundant wind resources, deep-water export harbours, and proximity to Europe, making it an ideal location to contribute to Europe’s energy security. Utilizing the Hybrid Optimization of Multiple Energy Resources (HOMER Pro) microgrid software, we conducted a techno-economic analysis of a wind-to-hydrogen case study at the Port au Port location aimed at offsetting 1% of Germany’s grey hydrogen consumption. The optimal system comprises 49 wind turbines, each with 4.2 MW capacity, a 130 MW PEM electrolyzer, a liquid hydrogen storage facility, and a grid as a backup. We evaluated various financial metrics, including Net Present Cost (NPC), Levelized Cost of Energy (LCoE), and Levelized Cost of Hydrogen (LCoH) for short-term, mid-term, and long-term storage scenarios. The financial metrics were compared with similar case studies around the globe to highlight the economic competitiveness of clean hydrogen production in Newfoundland and Labrador.
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Sundaram, Arunachalam, Abdullahi Abubakar Mas’ud, Hassan Z. Al Garni und Surajudeen Adewusi. „Assessment of off-shore wind turbines for application in Saudi Arabia“. International Journal of Electrical and Computer Engineering (IJECE) 10, Nr. 5 (01.10.2020): 4507. http://dx.doi.org/10.11591/ijece.v10i5.pp4507-4513.
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This paper presents models and economic analysis of ten different wind turbines for the region of Yanbu, Saudi Arabia using the hybrid optimization models for energy resources (HOMER) software. This study serves as a guide for decision makers to choose the most suitable wind turbine for Yanbu to meet the target of 58.7GW of renewable energy as part of Saudi Vision 2030. The analysis was carried out based on the turbines initial capital cost, operating cost, net present cost (NPC) and the levelized cost of energy (LCOE). Additionally, the wind turbines were compared based on their electricity production, excess energy and the size of the storage devices required. The results show that Enercon E-126 EP4 wind turbine has the least LCOE (0.0885 $/kWh) and NPC ($23.8), while WES 30 has the highest LCOE (0.142 $/kWh) and NPC ($38.3) for a typical load profile of a village in Yanbu.
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Lee, Bong Jae, Jeong Il Lee, Soo Young Yun, Cheol-Soo Lim und Young-Kwon Park. „Economic Evaluation of Carbon Capture and Utilization Applying the Technology of Mineral Carbonation at Coal-Fired Power Plant“. Sustainability 12, Nr. 15 (31.07.2020): 6175. http://dx.doi.org/10.3390/su12156175.
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Based on the operating data of a 40 tCO2/day (2 megawatt (MW)) class carbon capture and utilization (CCU) pilot plant, the scaled-up 400 tCO2/day (20 MW) class CCU plant at 500 MW power plant was economically analyzed by applying the levelized cost of energy analysis (LCOE) and CO2 avoided cost. This study shows that the LCOE and CO2 avoided cost for 400 tCO2/day class CCU plant of mineral carbonation technology were 26 USD/MWh and 64 USD/tCO2, representing low LCOE and CO2 avoided cost, compared to other carbon capture and storage CCS and CCU plants. Based on the results of this study, the LCOE and CO2 avoided cost may become lower by the economy of scale, even if the CO2 treatment capacity of the CCU plant could be extended as much as for similar businesses. Therefore, the CCU technology by mineral carbonation has an economic advantage in energy penalty, power plant construction, and operating cost over other CCS and CCU with other technology.
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Matsuo, Yuhji. „Re-Defining System LCOE: Costs and Values of Power Sources“. Energies 15, Nr. 18 (19.09.2022): 6845. http://dx.doi.org/10.3390/en15186845.
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The mass introduction of variable renewable energies, including wind and solar photovoltaic, leads to additional costs caused by the intermittency. Many recent studies have addressed these “integration costs,” and proposed novel metrics that replace the traditional metric known as the levelized cost of electricity (LCOE). However, the policy relevance of those metrics remains unclear. In this study, the author investigates and re-defines the concept of system LCOE, referring to prior studies, and proposes concrete methods to estimate them. Average system LCOE allocates the integration cost to each power source, dividing that by the adjusted power output. Marginal system LCOE revises the concept of system LCOE and value-adjusted LCOE proposed by prior studies, to be clearer and more policy-relevant. These metrics are also applied to Japan’s power sector in 2050, suggesting the necessity of aiming for a “well-balanced energy mix” in future power systems with decarbonised power sources.
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Li, Honglin, Mingxin Li, James Carroll und Jie Zhang. „Techno-Economic Analysis Incorporating Intelligent Operation and Maintenance Management: A Case Study of An Integrated Offshore Wind and Hydrogen Energy System“. Journal of Physics: Conference Series 2767, Nr. 6 (01.06.2024): 062016. http://dx.doi.org/10.1088/1742-6596/2767/6/062016.
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Abstract In this study, a comprehensive examination of wind-hydrogen energy systems is conducted through detailed techno-economic analysis and sensitivity analysis. The primary emphasis is on optimizing operation and maintenance (O&M) strategies and understanding the impacts of market dynamics. Utilizing Monte Carlo simulations, we first identify the optimal intelligent O&M plan, leading to significant reductions in annual O&M costs ($39.9/MW) and downtime (6.59 days per turbine) compared to conventional methods. The incorporation of prognostics and health management (PHM) further demonstrate a notable impact, leading to a 9.9% reduction in O&M costs and a 10.7% decrease in downtime. In the broader context, these outcomes translate into reductions in the O&M expenditures, total lifecycle costs of the system, Levelized Cost of Hydrogen (LCOH) and Levelized Cost of Energy (LCOE) by 3.9%, 0.75%, 2.4%, and 1.8%, respectively, highlighting the economic benefits of intelligent O&M strategies. The extensive sensitivity analysis, encompassing 54 scenarios, delves into the effects of maintenance strategies, hydrogen prices, wind energy share, and subsidies, revealing nuanced insights into cost savings and operational efficiencies. Notably, intelligent maintenance and favorable hydrogen subsidies effectively reduce LCOH, while the interplay between wind energy share and hydrogen pricing influences system profitability and efficiency, underscoring the complex dynamics at play in optimizing renewable energy systems.
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Brumana, Giovanni, Elisa Ghirardi und Giuseppe Franchini. „Comparison of Different Power Generation Mixes for High Penetration of Renewables“. Sustainability 16, Nr. 19 (27.09.2024): 8435. http://dx.doi.org/10.3390/su16198435.
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Growing environmental concerns have driven the installation of renewable systems. Meanwhile, the continuous decline in the levelized cost of energy (LCOE), alongside the decreasing cost of photovoltaics (PVs), is compelling the power sector to accurately forecast the performance of energy plants to maximize plant profitability. This paper presents a comprehensive analysis and optimization of a hybrid power generation system for a remote community in the Middle East and North Africa (MENA) region, with a 10 MW peak power demand. The goal is to achieve 90 percent of annual load coverage from renewable energy. This study introduces a novel comparison between three different configurations: (i) concentrated solar power (parabolic troughs + thermal energy storage + steam Rankine cycle); (ii) fully electric (PVs + wind + batteries); and (iii) an energy mix that combines both solutions. The research demonstrates that the hybrid mix achieves the lowest levelized cost of energy (LCOE) at 0.1364 USD/kWh through the use of advanced transient simulation and load-following control strategies. The single-technology solutions were found to be oversized, resulting in higher costs and overproduction. This paper also explores a reduction in the economic scenario and provides insights into cost-effective renewable systems for isolated communities. The new minimum cost of 0.1153 USD/kWh underscores the importance of integrating CSP and PV technologies to meet the very stringent conditions of high renewable penetration and improved grid stability.
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Pusch, Manuel, Mandar Phadnis, Michael Jeong, Chao Qin, Eric Loth und Lucy Pao. „Impact of Blade Pitch Actuation System on Wind Turbine Cost and Energy Production“. Journal of Physics: Conference Series 2767, Nr. 8 (01.06.2024): 082006. http://dx.doi.org/10.1088/1742-6596/2767/8/082006.
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Abstract To minimize the levelized cost of energy (LCOE) of wind turbines, advanced co-design strategies are required that also consider the contribution of active blade pitch control to overall energy production and wind turbine cost. Thereby, the demanded closed-loop performance drives the requirements on the blade pitch actuation system, which needs to be carefully balanced. To enable this, an extended LCOE measure is developed in this paper using stochastic estimates for quantifying pitch actuation cost in terms of pitch power and closed-loop performance in terms of net energy production. Additionally, the impact of blade pitch deflections on structural loads and hence cost is evaluated considering both collective and individual pitch control. The interdependencies between the different design objectives are revealed in a case study carried out on a 25MW wind turbine, demonstrating the guidance for engineers toward cost-effective and efficient wind turbine designs.
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Castro-Santos, Laura, Maite deCastro, Xurxo Costoya, Almudena Filgueira-Vizoso, Isabel Lamas-Galdo, Americo Ribeiro, João M. Dias und Moncho Gómez-Gesteira. „Economic Feasibility of Floating Offshore Wind Farms Considering Near Future Wind Resources: Case Study of Iberian Coast and Bay of Biscay“. International Journal of Environmental Research and Public Health 18, Nr. 5 (04.03.2021): 2553. http://dx.doi.org/10.3390/ijerph18052553.
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Wind energy resources are subject to changes in climate, so the use of wind energy density projections in the near future is essential to determine the viability and profitability of wind farms at particular locations. Thus, a step forward in determining the economic assessment of floating offshore wind farms was taken by considering current and near-future wind energy resources in assessing the main parameters that determine the economic viability (net present value, internal rate of return, and levelized cost of energy) of wind farms. This study was carried out along the Atlantic coast from Brest to Cape St. Vincent. Results show that the future reduction in wind energy density (2%–6%) mainly affects the net present value (NPV) of the farm and has little influence on the levelized cost of energy (LCOE). This study provides a good estimate of the economic viability of OWFs (Offshore Wind Farms) by taking into account how wind resources can vary due to climate change over the lifetime of the farm.
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Wolf Ciavarra, Andreas, Rafael Valotta Rodrigues, Katherine Dykes und Pierre-Elouan Réthoré. „Wind farm optimization with multiple hub heights using gradient-based methods“. Journal of Physics: Conference Series 2265, Nr. 2 (01.05.2022): 022012. http://dx.doi.org/10.1088/1742-6596/2265/2/022012.
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Abstract Optimization of the Levelized Cost of Energy (LCoE) in wind farms helps ensure profitability and competitiveness of the project. Recent work has explored driving down LCoE by allowing multiple wind turbines in a single wind farm - with different hub heights, rotor diameters, and rated powers. In this work, we performed optimization of the Lillgrund wind farm with continuously varying hub-heights to mitigate wake interference, improve annual energy production (AEP) and reduce LCoE. The optimization converged to a configuration where the turbines were vertically staggered, resulting in an improvement in both AEP and internal rate of return (IRR) - a financial metric related to LCoE. Reducing the number of turbines to a discrete set of 2 or 3 retained nearly all the benefits of staggering but is more aligned with limitations related to manufacturing and logistics.
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Yildiz, Nurullah, Hassan Hemida und Charalampos Baniotopoulos. „Operation, Maintenance, and Decommissioning Cost in Life-Cycle Cost Analysis of Floating Wind Turbines“. Energies 17, Nr. 6 (10.03.2024): 1332. http://dx.doi.org/10.3390/en17061332.
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Offshore wind farms are great options for addressing the world’s energy and climate change challenges, as well as meeting rising energy demand while taking environmental and economic impacts into account. Floating wind turbines, in specific, depict the next horizon in the sustainable renewable energy industry. In this study, a life-cycle cost analysis for floating offshore wind turbines is developed by combining the most recent data and parametric formulas from databases and relevant papers. The cost analysis models focused on cost minimization with special emphasis on Operation and Maintenance Cost (OPEX), Decommissioning Cost (DECOM), and Levelized Cost of Energy (LCOE), which are important factors in wind power economy. Given that floating wind energy is still developing, the presented scenarios should be beneficial in making future decisions. The cost analysis scenarios include on-site and off-site maintenance scenarios for OPEX. In addition, four alternative scenarios for DECOM have been examined: mechanical recycling, mechanical-incineration, incineration processes, and landfill. According to the findings of these scenarios, OPEX varies from 16.89 to 19.93 £/MWh and DECOM between 3.47 and 3.65 £/MWh, whilst the total LCOE varied from 50.67 to 66.73 £/MWh.
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Damiani, R., und D. Davis. „Engineering a Reduction of the Levelized Cost of Energy of Distributed Wind Turbines via Rotor and Control Enhancements“. Journal of Physics: Conference Series 2265, Nr. 4 (01.05.2022): 042080. http://dx.doi.org/10.1088/1742-6596/2265/4/042080.
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Abstract Distributed wind turbines (DWTs), with rated capacity less than 100 kW, are penalized by high balance-of-system costs that lead to a high levelized cost of energy (LCOE). As a result, to contain the capital expenditure and thus LCOE, traditional designs have avoided active control systems that are standard in larger machines, e.g., active yaw and pitch control. In this paper, we present the key results of a trade-off study between larger rotor diameter, loads abatement, and simplicity in the pitch design for a typical mid-sized DWT with the overarching goal of increasing performance and decreasing LCOE. We focused on the upgrade potential for a generic downwind, passive-yaw, stall-controlled turbine model with high-speed shaft (HSS) brake and rated capacity of ∼ 60kW. A rotor and control redesign proved successful in increasing power capture through the deployment of a blade-root extender and an innovative, low-cost, independent pitch system for overspeed protection. The improvements remove the need for a mechanical brake and yield a significant decrease in LCOE. The loads in all components were kept under the target threshold by a combination of optimum blade extender length and rotor rotational velocity. The failsafe and redundant aerodynamic braking system is economical and can lend itself to retrofit applications to other turbine models.
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Hwang, Sung-Hyun, Mun-Kyeom Kim und Ho-Sung Ryu. „Real Levelized Cost of Energy with Indirect Costs and Market Value of Variable Renewables: A Study of the Korean Power Market“. Energies 12, Nr. 13 (26.06.2019): 2459. http://dx.doi.org/10.3390/en12132459.
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A levelized cost of energy (LCOE) is a methodology for comparing power generation costs in the transition to renewable energy (RE). However, the major limitation of evaluating RE based on the LCOE is that it does not consider indirect costs, such as the environmental and curtailment effect. This paper proposes the real LCOE (rLCOE) approach that accounts for indirect and direct generation costs. The mathematical approach to estimating indirect costs is derived from economic theory. The indirect effects, which quantify all benefits generated due to RE, is related to the variability of the share RE in the energy generation mix. The rLCOE enhances the accuracy of the economic comparison of power generation costs and the derivation of the optimal quantities of RE because external effects are incorporated into the LCOE principles. This approach has taken into account electricity demand, fuel prices, and environmental costs for each energy source to adequately compare generation costs. Simulations have been performed to demonstrate the application of the rLCOE approach in the Korean power market. Here, the unit variation of costs with the RE share were analyzed. The results show that indirect cost savings of an additional unit of RE begin to fall in scenario 3 in contrast to the result of LCOE approach indicating higher generation costs with RE share, especially, the proportion of RE in the generation mix is higher than 20%. Thus, the optimal power generation can be evaluated using the rLCOE approach.
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Kang, Dahyun, und Tae Yong Jung. „Renewable Energy Options for a Rural Village in North Korea“. Sustainability 12, Nr. 6 (20.03.2020): 2452. http://dx.doi.org/10.3390/su12062452.
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The national electrification rate of North Korea is extremely low and the situation in rural areas is even worse. Thus, this study designs a virtual electrification project for a rural village in North Pyongan and compares an off-grid energy system and on-grid system in terms of net present cost (NPC) and levelized cost of energy (LCOE) to define the most cost-effective energy system. Using Hybrid Optimization of Multiple Energy Resources (HOMER), this study designs two off-grid systems that apply different types of batteries—lead–acid and lithium-ion energy storage systems (ESS)—and determines the NPC and LCOE of the most cost-effective system. Then, it calculates the NPC and LCOE of grid extension by adding necessary costs required for generation, transmission, and distribution. The result shows that the hybrid energy system (HES) of solar photovoltaic (PV), wind turbines, lead–acid batteries, and diesel generators is the most cost-effective option for the selected location. The range of breakeven grid-extension distance is from 9.69 km to 20.57 km. The sensitivity analysis based on different discount rates shows that a higher discount rate means a shorter breakeven distance. This analysis suggests that deploying an HES is one way to improve the electrification rate for remote and rural areas in North Korea.
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Hernández Moris, Catalina, Maria Teresa Cerda Guevara, Alois Salmon und Alvaro Lorca. „Comparison between Concentrated Solar Power and Gas-Based Generation in Terms of Economic and Flexibility-Related Aspects in Chile“. Energies 14, Nr. 4 (18.02.2021): 1063. http://dx.doi.org/10.3390/en14041063.
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The energy sector in Chile demands a significant increase in renewable energy sources in the near future, and concentrated solar power (CSP) technologies are becoming increasingly competitive as compared to natural gas plants. Motivated by this, this paper presents a comparison between solar technologies such as hybrid plants and natural gas-based thermal technologies, as both technologies share several characteristics that are comparable and beneficial for the power grid. This comparison is made from an economic point of view using the Levelized Cost of Energy (LCOE) metric and in terms of the systemic benefits related to flexibility, which is very much required due to the current decarbonization scenario of Chile’s energy matrix. The results show that the LCOE of the four hybrid plant models studied is lower than the LCOE of the gas plant. A solar hybrid plant configuration composed of a photovoltaic and solar tower plant (STP) with 13 h of storage and without generation restrictions has an LCOE 53 USD/MWh, while the natural gas technology evaluated with an 85% plant factor and a variable fuel cost of 2.0 USD/MMBtu has an LCOE of 86 USD/MWh. Thus, solar hybrid plants under a particular set of conditions are shown to be more cost-effective than their closest competitor for the Chilean grid while still providing significant dispatchability and flexibility.
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Vargiu, Alberto, Riccardo Novo, Claudio Moscoloni, Enrico Giglio, Giuseppe Giorgi und Giuliana Mattiazzo. „An Energy Cost Assessment of Future Energy Scenarios: A Case Study on San Pietro Island“. Energies 15, Nr. 13 (21.06.2022): 4535. http://dx.doi.org/10.3390/en15134535.
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The need for a clean and affordable energy supply is a major challenge of the current century. The tough shift toward a sustainable energy mix becomes even more problematic when facing realities that lack infrastructures and financing, such as small islands. Energy modeling and planning is crucial at this early stage of the ecological transition. For this reason, this article aims to improve an established long-run energy model framework, known as “OSeMOSYS,” with an add-on tool able to estimate different types of Levelized Cost Of Electricity (LCOE): a real and theoretical LCOE of each technology and a real and theoretical system LCOE. This tool fills a gap in most modeling frameworks characterized by a lack of information when evaluating energy costs and aims at guiding policymakers to the most appropriate solution. The model is then used to predict future energy scenarios for the island of San Pietro, in Sardinia, which was chosen as a case study. Four energy scenarios with a time horizon from 2020 to 2050—the Business-As-Usual (BAU) scenario, the Current Policy Projection (CPP) scenario, the Sustainable Growth (SG) scenario, and the Self-Sufficient-Renewable (SSR) scenario—are explored and ranked according to the efforts made in them to achieve an energy transition. Results demonstrates the validity of the tool, showing that, in the long run, the average LCOE of the system benefits from the installation of RES plants, passing from 49.1 €/MWh in 2050 in the BAU scenario to 48.8 €/MWh in the ambitious SG scenario. On the other hand, achieving carbon neutrality and the island’s energy independence brings the LCOE to 531.5 €/MWh, questioning the convenience of large storage infrastructures in San Pietro and opening up future work on the exploration of different storage systems.
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Sergent, Philippe, Virginie Baudry, Arnaud De Bonviller, Bertrand Michard und Jérémy Dugor. „Numerical Assessment of Onshore Wave Energy in France: Wave Energy, Conversion and Cost“. Journal of Marine Science and Engineering 8, Nr. 11 (20.11.2020): 947. http://dx.doi.org/10.3390/jmse8110947.
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There are few general analyses of the interest of onshore wave energy converters (onshore WEC) in terms of resources, efficiency and cost. The case of The Channel on the Atlantic coast of France is chosen here to illustrate the issues related to onshore WEC development. The paper presents a list of potential sites with their characteristics and a more in-depth analysis of a few sites. For four onshore WEC families, the production is given with a method of calculating the efficiency and economic analysis is carried out to estimate the energy cost at two selected sites. Annual wave power levels are maximum in Bayonne with 24 kW/m, and the lengths of useful dikes vary from 60 m in Molène up to 4000 m in Cherbourg. Wave reflection on the dike is an advantage in terms of energy production. The oscillating flaps constitute the systems with the highest efficiency, and the float systems have the lowest levelized cost of energy (LCoE), followed closely by the oscillating flaps. Oscillating water columns and overtopping systems have nearly five times these LCoEs. With mass production, costs of oscillating floats and flaps will approach those of other renewable energies such as solar and wind power.
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Yoon, SeoHo, Sun Bin Kim, Gil Lim Yoon und Jin-Hak Yi. „Comparison of LCOE of the Southwest Offshore Wind Farm According to Types and Construction Methods of Supporting Structures“. Journal of Korean Society of Coastal and Ocean Engineers 35, Nr. 3 (30.06.2023): 57–66. http://dx.doi.org/10.9765/kscoe.2023.35.3.57.
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In order to understand the economic feasibility of an offshore wind farm, this paper analyzed the differences in LCOE (levelized cost of energy) according to the support type and construction method of the substructure in terms of LCOE and sensitivity analysis was conducted according to the main components of LCOE. As for the site to be studied, the Southwest Offshore Wind Farm was selected, and the capital expenditures were calculated according to the size of the offshore wind farm and the installation unit. As a result of the sensitivity analysis, major components showed high sensitivity to availability, turbine related cost, weighted average cost of capital and balance of system related cost. Moreover, the post-piling jacket method, which was representatively applied to the substructure of the offshore wind farm in Korea, was selected as a basic plan to calculate the capital expenditures, and then the capital expenditures of the pre-piling jacket method and the tripod method were calculated and compared. As a result of analyzing the LCOE, it was confirmed that the pre-piling jacket method of the supporting structure lowers the LCOE and improves economic feasibility as the installation number of turbines increases.
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Brykalov, S. M., A. S. Balyberdin, D. A. Nyrkov, N. V. Sheshina und E. A. Gushchina. „Selection of the priority option for a floating power unit based on the analysis of technical and economic indicators“. Arctic: Ecology and Economy 12, Nr. 4 (Dezember 2022): 551–58. http://dx.doi.org/10.25283/2223-4594-2022-4-551-558.
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Designs of floating power units equipped with innovative reactor installations market a new class of energy sources based on Russian nuclear shipbuilding technologies. Evaluation of various options for floating power units makes it possible to determine the most priority option based on an analysis of technical and economic indicators, including the Levelized Cost of Electricity (LCOE) index.
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Goss, Z. L., D. S. Coles und M. D. Piggott. „Identifying economically viable tidal sites within the Alderney Race through optimization of levelized cost of energy“. Philosophical Transactions of the Royal Society A: Mathematical, Physical and Engineering Sciences 378, Nr. 2178 (27.07.2020): 20190500. http://dx.doi.org/10.1098/rsta.2019.0500.
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Costs of tidal stream energy generation are anticipated to fall considerably with array expansion and time. This is due to both economies of volume, where arrays comprising of large numbers of turbines can split fixed costs over a greater number of devices, and learning rates, where the industry matures and so arrays of the same size become cheaper due to lessons learned from previous installations. This paper investigates how tidal energy arrays can be designed to minimize the levelized cost of energy (LCOE), by optimizing not only the location but also the number of devices, to find a suitable balance between decreased costs due to economies of volume and diminishing returns due to global blockage effects. It focuses on the Alderney Race as a case study site due to the high velocities found there, making it a highly suitable site for large-scale arrays. It is demonstrated that between 1 and 2 GW could be feasibly extracted as costs in the tidal industry fall, with the LCOE depending greatly on the assumed costs. A Monte–Carlo analysis is undertaken to account for variability in capital and operational cost data used as inputs to the array optimization. Once optimized, the estimated P50 LCOE of an 80 MW array is £110/MWh. This estimate aligns closely with the level of subsidy considered for tidal stream projects in the Alderney Race in the past. This article is part of the theme issue ‘New insights on tidal dynamics and tidal energy harvesting in the Alderney Race’.
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Zhong, Wei, Haitao Yu, Hao Wang und Jiahui Zhang. „Lowering the levelized cost of energy (LCOE) for mass-adjustable-buoy-based wave energy converters“. Ocean Engineering 311 (November 2024): 118878. http://dx.doi.org/10.1016/j.oceaneng.2024.118878.
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Zun, Moe Thiri, und Benjamin Craig McLellan. „Cost Projection of Global Green Hydrogen Production Scenarios“. Hydrogen 4, Nr. 4 (09.11.2023): 932–60. http://dx.doi.org/10.3390/hydrogen4040055.
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A sustainable future hydrogen economy hinges on the development of green hydrogen and the shift away from grey hydrogen, but this is highly reliant on reducing production costs, which are currently too high for green hydrogen to be competitive. This study predicts the cost trajectory of alkaline and proton exchange membrane (PEM) electrolyzers based on ongoing research and development (R&D), scale effects, and experiential learning, consequently influencing the levelized cost of hydrogen (LCOH) projections. Electrolyzer capital costs are estimated to drop to 88 USD/kW for alkaline and 60 USD/kW for PEM under an optimistic scenario by 2050, or 388 USD/kW and 286 USD/kW, respectively, under a pessimistic scenario, with PEM potentially dominating the market. Through a combination of declining electrolyzer costs and a levelized cost of electricity (LCOE), the global LCOH of green hydrogen is projected to fall below 5 USD/kgH2 for solar, onshore, and offshore wind energy sources under both scenarios by 2030. To facilitate a quicker transition, the implementation of financial strategies such as additional revenue streams, a hydrogen/carbon credit system, and an oxygen one (a minimum retail price of 2 USD/kgO2), and regulations such as a carbon tax (minimum 100 USD/tonCO2 for 40 USD/MWh electricity), and a contract-for-difference scheme could be pivotal. These initiatives would act as financial catalysts, accelerating the transition to a greener hydrogen economy.
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Kobou Ngani, Patrick, und Jean-Régis Hadji-Minaglou. „Model Predictive Control for Residential Battery Storage System: Profitability Analysis“. Batteries 9, Nr. 6 (06.06.2023): 316. http://dx.doi.org/10.3390/batteries9060316.
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For increased penetration of energy production from renewable energy sources at a utility scale, battery storage systems (BSSs) are a must. Their levelized cost of electricity (LCOE) has drastically decreased over the last decade. Residential battery storage, mostly combined with photovoltaic (PV) panels, also follow this falling prices trend. The combined effect of the COVID-19 pandemic and the war in Ukraine has caused such a dramatic increase in electricity prices that many consumers have adjusted their strategies to become prosumers and self-sufficient as feed-in subsidies continue to drop. In this study, an investigation is conducted to determine how profitable it is to install BSSs in homes with regards to battery health and the levelized cost of total managed energy. This is performed using mixed-integer linear programming (MILP) in MATLAB, along with its embedded solver Intlinprog. The results show that a reasonable optimized yearly cycling rate of the BSS can be reached by simply considering a non-zero cost for energy cycling through the batteries. This cost is simply added to the electricity cost equation of standard optimization problems and ensures a very good usage rate of the batteries. The proposed control does not overreact to small electricity price variations until it is financially worth it. The trio composed of feed-in tariffs (FITs), electricity costs, and the LCOE of BSSs represents the most significant factors. Ancillary grid service provision can represent a substantial source of revenue for BSSs, besides FITs and avoided costs.
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Lugo-Laguna, Daniel, Angel Arcos-Vargas und Fernando Nuñez-Hernandez. „A European Assessment of the Solar Energy Cost: Key Factors and Optimal Technology“. Sustainability 13, Nr. 6 (15.03.2021): 3238. http://dx.doi.org/10.3390/su13063238.
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Solar energy has become one of the most important sources of energy all around the world. Only in the European Union, between 2010 and 2019, solar photovoltaic (PV) electricity generation capacity increased from 1.9 to over 133 GW. Throughout this work, an economic analysis of the production of photovoltaic solar energy utility scale facilities is performed, previously defining some theoretical concepts relating to electricity generation by means of photovoltaic modules, as well as commenting on studies that have inspired the project. In order to carry out this economic analysis, the locations of twenty capital cities within European Union countries are selected, in order to estimate their yearly solar PV energy produced under specific conditions. The Levelized Costs of Energy (LCOE) is calculated with the goal of comparing the profitability of each photovoltaic tracking technology: fixed, one-axis tracking systems (vertical or inclined) and two-axis tracking systems; including LCOE maps country-wise for each technology. A sensitivity analysis is also presented, in order to evaluate the significance and impact of the main variables involved in the analysis. The results show that one-axis tracking systems are the best option in all countries, reducing LCOE by more than 20% when compared to two-axis tracking system. The impact of wages is also significant. In higher latitudes, in most cases, wages also increase, hence the LCOE is higher and consequently less interesting for a potential investor.
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Kikuchi, Yuka, und Takeshi Ishihara. „Availability and LCOE Analysis Considering Failure Rate and Downtime for Onshore Wind Turbines in Japan“. Energies 14, Nr. 12 (14.06.2021): 3528. http://dx.doi.org/10.3390/en14123528.
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In this study, the availability and the levelized cost of energy (LCOE) are investigated considering failure rate and downtime for onshore wind turbines in Japan. The failure mode effect analysis is conducted using the wind turbine failure database collected by the New Energy and Industrial Technology Department Organization (NEDO). The normalized failure rate and downtime between Europe and Japan are comparable. The occurrence rate is similar between Europe and Japan, but the downtime in Japan is much longer than that of Europe. Three cost-reduction scenarios are then proposed to improve availability and to reduce LCOE using assumed failure rate and downtime in each mode based on the industry interview and best practices in Japan. The availability is improved from 87.4% for the baseline scenario to 92.7%, 95.5% and 96.4% for the three scenarios, and LCOE is also reduced from 13.7 Yen/kWh to 11.9, 11.0 and 10.7 Yen/kWh. Finally, the probability distributions of downtime and repair cost are obtained for each failure mode. It is found that the probability distributions of the failure modes with the shortest downtime show similar probability distributions regardless of the size of the assembly. The effects of downtime and repair-cost uncertainties on LCOE are also evaluated.