Thematische Bibliographien / Levelized cost of energy (LCOE)

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Auswahl der wissenschaftlichen Literatur zum Thema „Levelized cost of energy (LCOE)“

Autor: Grafiati

Veröffentlicht am 11. Januar 2025

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Zeitschriftenartikel zum Thema "Levelized cost of energy (LCOE)"

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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Dissertationen zum Thema "Levelized cost of energy (LCOE)"

Heidari, Shayan. „Economic Modelling of Floating Offshore Wind Power : Calculation of Levelized Cost of Energy“. Thesis, Mälardalens högskola, Industriell ekonomi och organisation, 2017. http://urn.kb.se/resolve?urn=urn:nbn:se:mdh:diva-36130.

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Floating offshore wind power is a relatively new technology that enables wind turbines to float above the sea level, tied by anchors at the seabed. The purpose of this work is to develop an economic model for the technology in order to calculate the total cost of a planned wind farm. Cost data are retrieved from reports and academic journals available online. Based on these data, a model in Microsoft Excel is developed which calculates the Levelized cost of energy (LCOE) for floating wind power plants as a function of several input values. As an addition to this model, financing offshore projects are described using literature study and by doing interviews with three major companies, currently investing in offshore wind. As a result, the model allows the user to calculate Capital expenditures, Operating expenditures and LCOE for projects at any given size and at any given site. The current LCOE for a large floating offshore wind farm is indicated to be in the range of 138-147 £/MWh. The outline from interviews was that today there is no shortage of capital for funding wind projects. However, in order to attract capital, the governmental regulatory of that market has to be suitable since it has a crucial impact on price risks of a project.

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Englund-Karlsson, Simon. „Energy storage and their combination with wind power compared to new nuclear power in Sweden : A review and cost analysis“. Thesis, Högskolan i Gävle, Energisystem och byggnadsteknik, 2020. http://urn.kb.se/resolve?urn=urn:nbn:se:hig:diva-32749.

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As intermittent renewable energy sources such as wind and solar power gradually increase around the world, older technologies such as nuclear power is phased out in Sweden and many other countries. It is then important to ensure that the total power need is secured, and that the power grid can remain stable. One way of managing intermittent renewables is by using energy storage. The main goal of this thesis was to compare energy storage methods and their costs. A secondary aim was to investigate how the cost of developing more renewable energy sources, in combination with different energy storage methods, compares to erecting new nuclear power. This thesis was limited to three energy storage technologies, namely pumped hydro storage (PHS), compressed air energy storage (CAES), and four battery storage technologies. They were combined with wind power in the cost analysis. The comparison was done by performing a literature review and economical calculations, which focused especially on levelized cost of storage (LCOS). The results from the economic calculations indicated that PHS and CAES had lower LCOS than battery storage technologies. Similar results could be seen in the literature review as well. When comparing levelized cost of energy (LCOE) nuclear power had the lowest, €0.03-0.12 kWh-1, followed by wind power in combination with PHS and CAES, both around €0.07-0.24 kWh-1. This result was maintained also at sensitivity analysis regarding the discount rate, which both nuclear power and PHS proved rather sensitive to. Keywords: energy storage, nuclear power, wind power, pumped hydro storage, compressed air energy storage, battery energy storage, levelized cost of energy, Sweden

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Mattsson, Helen, und Jonatan Lindberg. „Vätgasens roll i det regionala energisystemet : Tekno-ekonomiska förutsättningar för Power-to-Power“. Thesis, Linköpings universitet, Energisystem, 2020. http://urn.kb.se/resolve?urn=urn:nbn:se:liu:diva-173577.

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Alltmer intermittent elkraft byggs idag i Sverige för att öka andelen förnybar el i energisystemet. Detta leder till mer ojämn elproduktion, vilket skapar problem i form av mer volatila och oförutsägbara elpriser. Ett sätt att dämpa effekten av den ökande intermittenta kraften är att använda förnybar vätgasproduktion som lastutjämning. På detta sätt kan vätgasen potentiellt bli en viktig del i den fossilfria energimixen. Att använda vätgas som energilager i en Power-to-Power-applikation (P2P) möjliggör även utnyttjandet av prisarbitrage på elmarknaden. Ett ökat klimatfokus har återuppväckt intresset för hur vätgasproduktion kan göras lönsamt. Några tecken på att satsningar sker är att flera länder satsar stora pengar på vätgastekniker och infrastruktur, där flertalet samarbeten över nationella gränser har etablerats.Denna studie syftar till att undersöka de tekno-ekonomiska förutsättningarna för produktion av förnybar vätgas där lönsamheten av arbitragehandel på elmarknaden Elspot bedöms. Detta innefattar en gedigen granskning av kommersiella tekniker lämpade för Linköpings energisystem, däribland elektrolys, ångreformering och bränslecell. Tre fall konstruerades med olika uppsättningar av ingående komponenter. Sedan utfördes en driftoptimering som tog fram övre och undre prisgränser för produktion respektive konvertering av vätgas mot spotpriset. Optimeringsverktyget Problemlösaren i Excel användes för att få fram dessa gränser. Visual Basic (VBA) användes sedan för att genomföra en lagersimulering som visualiserar lagersaldot för alla årets timmar. För att få fram kostnaden för varje kilogram producerad vätgas användes nuvärdesberäkningen Levelised Cost of Energy (LCOE), vilket även underlättade jämförelsen av de tre fallen. Vilka effekter i form av växthusgasutsläpp de olika anläggningarna medför utvärderades också genom beräkningssättet konsekvensanalys. Där jämfördes effekten i form av nettoutsläpp i koldioxidekvivalenter för integrering av respektive anläggning. Resultaten visar på att det finns kommersiella tekniker som kan integreras med det befintliga energisystemet på ett resurseffektivt sätt, däremot är de ekonomiska förutsättningarna inte lika bra och P2P-lösningarna är idag långt ifrån lönsamma. Anledningen tros vara en kombination av otillräckliga elprisfluktuationer samt låg total systemverkningsgrad (som högst 14%) för samtliga konstruerade fall. De årliga intäkterna från elförsäljningen motsvarar cirka 1 procent av de årliga kostnaderna för anläggningen, och LCOE landade på cirka 1500 kronor. Resultaten från investeringskalkyleringen visar på att en högre utnyttjandegrad leder till en lägre LCOE. Lagersimuleringen visar på att säsongslagring krävs för denna typ av anläggning då fluktuationerna inte är tillräcklig stora på en daglig, veckovis eller månatlig basis. Känslighetsanalys på LCOE och driftoptimeringen visar inte heller på lönsamhetsmöjligheter i P2P-fallen även vid gynnsamma justeringar på parametrarna investeringskostnad, elpris och verkningsgrad. Ur ett klimatperspektiv visar samtliga fall, med ett undantag, på en minskade växthusgasutsläpp i regionen. Slutsatsen som dras av resultaten från fallstudien är att, trots goda tekniska förutsättningar och positiv inverkan på lokala växthusgasutsläpp, kan en P2P-applikation med vätgaslagring inte göras lönsam i en svensk kontext inom en nära framtid. Däremot visar ett Power-to-Gas-fall potential för lönsamhet, då dess investeringskostnad är mindre samt att systemverkningsgraden är högre.
More and more intermittent electric power is being built in Sweden today to increase the share of renewable electricity in the energy system. This leads to more uneven electricity generation, which creates problems in terms of more volatile and unpredictable electricity prices. One way to dampen the effect of the increasing intermittent power is to use renewable hydrogen production as load shedding. In this way, the hydrogen gas can potentially become an important part of the fossil-free energy mix. Using hydrogen as energy storage in a Power-to-Power application (P2P) also enables the use of price arbitrage in the electricity market. An increased climate focus has rekindled interest in how hydrogen production can be made profitable. Some signs that investments are taking place are that several countries are investing big money on hydrogen technologies and infrastructure, and collaborations across national borders have been established. This study aims to investigate the techno-economic prerequisites for renewable hydrogen production where the profitability of arbitrage on the Elspot market is explored. This comprises a thorough investigation of commercial technologies suited for Linköping’s energy system. Three cases where constructed with different component constellations. Then the operational strategy was optimised which generated a lower and upper price limit for production and conversion of hydrogen with input price data from Elspot. The optimisation tool in Excel was used in order to obtain these price limits. Visual Basic (VBA) was then used for storage simulation in order to get a perception of the storage development through all the hours of the year. The cost of every kilogram of hydrogen produced was then calculated through Levelized Cost of Energy (LCOE), which made the comparison of the three cases easier. The resulting greenhouse gas emissions when integrating the facilities in each case were also evaluated with a so-called impact analysis. The effect was compared in net emissions in carbon dioxide equivalents for an integration of each facility. The results show that there are commercial technologies that can be integrated with the existing energy system in a resource efficient manner, whereas the economic prerequisites are not as good, where today’s Power-to-Power (P2P) solutions are not profitable. The reason seems to be the combination of insufficient spot price fluctuations and a low system efficiency (14% at best) for each case. The annual revenues correspond to 1 percent of the annual costs and that LCOE lands at about 1500 SEK. A higher utilization percentage of the plant shows a lower LCOE in the investment calculation. The storage simulation indicates that a seasonal storage is needed for this type of facility because of that the spot price fluctuations are not big enough on a daily, weekly or monthly basis. The sensitivity analysis made on the investment calculation and operational strategy also shows that there is no profitability in the P2P cases where parameters regarding investment cost, efficiency and electricity price were set optimistically. The Power-to-Gas case on the other hand shows potential for profitability, all because of lower total investment costs and higher efficiency. All cases except the case with steam methane reforming shows reductions in greenhouse gas emissions when integrated in the regional energy system. The conclusion that can be drawn from the results in the case study is that, in spite of good technological prerequisites and a positive effect on local greenhouse gas emissions, a P2P-application with hydrogen storage cannot be made profitable in a Swedish context in the near future. However, a Power-to-Gas case shows potential for profitability because of its lesser investment cost and that the system efficiency is higher.

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Babajide, Nathaniel Akinrinde. „The electricity crisis in Nigeria : building a new future to accommodate 20% renewable electricity generation by 2030“. Thesis, University of Dundee, 2017. https://discovery.dundee.ac.uk/en/studentTheses/7c6df776-e790-4afc-8970-3877d91a2663.

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As part of efforts to curb the protracted electricity problem in Nigeria, the government enacted the National Renewable Energy and Energy Efficiency Policy (NREEEP) in 2014. Through this policy, the country plans to increase its electricity generation from renewables to 20% by 2030. This thesis investigates the economic feasibility of this lofty goal, and as well determine the best hybrid configuration for off-grid rural/remote power generation across the six geopolitical zones of Nigeria The economic feasibility results, using Long-range Energy Alternative Planning (LEAP) tool, show that the 20% renewables goal in the Nigerian power generation mix by 2030 is economically feasible but will require vast investment, appropriate supportive mechanisms, both fiscal and non-fiscal (especially for solar PV) and unalloyed commitment on the part of the government. Moreover, the techno-economic results with Hybrid Optimization Model for Electric Renewable (HOMER) reveal Small hydro/Solar PV/Diesel generator/Battery design as the most cost-effective combination for power supply in remote/rural areas of Nigeria. Findings also highlight the better performance of this system in terms of fuel consumption and GHGs emission reduction. Lastly, the study identifies factors influencing RE development, and offers strategic and policy suggestions to advance RE deployment in Nigeria.

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Almutairi, Badriya L. „Investigating the feasibility and soil-structure integrity of onshore wind turbine systems in Kuwait“. Thesis, Loughborough University, 2017. https://dspace.lboro.ac.uk/2134/27612.

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Wind energy technologies are considered to be among the most promising types of renewable energy sources, which have since attracted broad considerations through recent years due to the soaring oil prices and the growing concerns over climate change and energy security. In Kuwait, rapid industrialisation, population growth and increasing water desalination are resulting in high energy demand growth, increasing the concern of oil diminishing as a main source of energy and the climate change caused by CO2 emissions from fossil fuel based energy. These demands and challenges compelled governments to embark on a diversification strategy to meet growing energy demand and support continued economic growth. Kuwait looked for alternative forms of energy by assessing potential renewable energy resources, including wind and sun. Kuwait is attempting to use and invest in renewable energy due to the fluctuating price of oil, diminishing reserves, the rapid increase in population, the high consumption of electricity and the environment protection. In this research, wind energy will be investigated as an attractive source of energy in Kuwait.

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Pettit, Erica S. „WindLCOEA MATLAB TOOL FOR OPTIMIZING THE LEVELIZED COST OF ENERGY FOR WIND TURBINE DESIGNS“. Case Western Reserve University School of Graduate Studies / OhioLINK, 2014. http://rave.ohiolink.edu/etdc/view?acc_num=case1396621758.

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Samuelsson, Mattias. „What are the drivers and forces for companies within the energy sector to invest in renewable energy technologies“. Thesis, KTH, Entreprenörskap och Innovation, 2016. http://urn.kb.se/resolve?urn=urn:nbn:se:kth:diva-189286.

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Climate change and renewable energy technologies are internationally discussed topics. Recently the subject was discussed during the Paris climate conference, COP21. Which lead to the establishing of the first ever universal agreement, legally binding climate deal, which include 195 countries around the world. With the goal to decrease global warming by 1.5 degrees Celsius the need of new innovative technologies are increasing dramatically. This thesis will examine the characteristics of renewable energy technology investment behavior by identifying drivers and forces for companies to invest in relatively new and less mature technologies, which are usually associated with high investment costs. Is it possible to financially justify investments in renewable energy technologies during the current market situation with historically low energy prices and with a production surplus? By examining the market and investments the aim is to identify and understand what drives companies to invest in renewable energy technologies and if it is profitable from a financial sustainable perspective. The main results and derived conclusions are that RET investments behavior are influenced by several forces and drivers. The findings indicate that investments in RETs aren’t necessarily economical sustainable but rather that other objectives are of more importance than profitability in the short term.

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Washika, Tony. „Renewables Based Power generation for Kenya Pipeline Company“. Thesis, KTH, Kraft- och värmeteknologi, 2011. http://urn.kb.se/resolve?urn=urn:nbn:se:kth:diva-131315.

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This study presents a Techno-economic assessment of a renewables based power generation project for PS 21, a Pumping Station for Kenya Pipeline Company located in Nairobi, Kenya. The load for the pumping station is 1135 kW Continuous. The assessment criteria used was levelized cost of energy. The hybrid renewable energy system software HOMER was used for assessment, and modeling was done using hourly TMY data for solar irradiance and wind. According to the results, Hybrid Solar PV-Wind- Battery renewable energy systems can supply adequate power for pumping station purposes. Optimization modeling at 2010 prices gave a levelized cost of energy of $0.2 per kWh for the most optimal solution which consisted of 2 No. 1650 kW Vestas V 82 Wind Turbines and 4070 kW of PV modules. This cost of energy just matches the purchase price from the National grid which varies between $0.14 and $0.2 per kWh, and therefore, the project is economically feasible. Mainly due to concerns of global warming, the view in the Kenyan government and society towards renewable energy is very favorable and the project is also politically and socially feasible. Sensitivity analysis demonstrated that wind energy is more viable than solar PV energy in areas of high wind speeds, with about 7.5 m/s annual average wind speeds. The results show that the levelised cost of energy may be significantly decreased in future due to the fact that the cost of PV modules is progressively reducing. Payments for CERs under CDM mechanism of the Kyoto Protocol would lower the levelised cost of energy further. The Project was found to be feasible.

I was a distance student and did the presentation online via centra.

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Zuniga, Gustavo Camilo Rosero. „Proposta de regulamentação para usinas eólicas através da sua energia firme“. reponame:Biblioteca Digital de Teses e Dissertações da UFRGS, 2015. http://hdl.handle.net/10183/127893.

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Dentro das fontes renováveis de energia, a energia eólica é uma das mais estudadas e que tem uma importante participação na capacidade instalada no mundo. Porém, é uma alternativa que está concentrada em poucos países como uma verdadeira opção para cobrir a demanda de energia elétrica. As principais razões dessa concentração estão ligadas a questões climáticas, econômicas e de regulamentação. Em relação à questão econômica a principal limitação é o custo da energia em comparação com fontes tradicionais; na questão de regulamentação o limitante é a carência de métodos de cálculo e regras que incentivem a instalação de usinas. Para vencer essas limitações é proposta uma regulamentação do tipo econômica baseada na energia firme das usinas eólicas. A influência desse incentivo pode ser medida no comportamento de uma usina eólica hipotética atuando sem regulamentação no mercado elétrico e em um cenário com a regulamentação proposta. A energia firme é um conceito que existe para fontes hidráulicas e térmicas. Usando esse conceito com as características da energia eólica, é possível desenvolver uma metodologia de cálculo que incentiva a implementação de projetos em países com escassa tradição eólica. O resultado permite calcular um fator característico de energia firme para cada tipo de aerogerador e uma forma de remuneração que atua no valor presente líquido do projeto.
Among renewable energy sources, wind energy is one of the most studied and has an important stake in installed capacity in the world. However, it is an alternative concentrated in a few countries as a real option to cover the energy demand. The main reasons for this concentration are linked to climate, economic and regulatory issues. Regarding the economic issue the main limitation is the cost of energy production in comparison to other sources; the limitation of the regulatory issue is the lack of calculation methods and rules that encourage the installation of wind power plants. To overcome these limitations, it is proposed an economic regulation based on firm energy of wind farms. The influence of this incentive can be measured in the behavior of a hypothetical wind farm operating in an electricity market without regulation and in a scenario with the proposed regulation. The firm energy is a concept that exists for hydraulic and thermal sources. Using this concept with the characteristics of wind power, it is possible to develop a methodology for calculation that encourages the implementation of projects in countries with small wind power installed capacity. The result allows calculating a characteristic factor of firm energy for each type of wind turbine and a method of remuneration, which operates on the net present value of a project.

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Gadkari, Sagar A. „A HYBRID RECONFIGURABLE SOLAR AND WIND ENERGY SYSTEM“. Cleveland State University / OhioLINK, 2008. http://rave.ohiolink.edu/etdc/view?acc_num=csu1225821057.

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Mehr Quellen

Bücher zum Thema "Levelized cost of energy (LCOE)"

Cory, Karlynn S. Wind levelized cost of energy: A comparison of technical and financing input variables. Golden, Colo: National Renewable Energy Laboratory, 2009.

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Simón-Martín, Miguel de, Giorgio Piazza, Luisa Carlotta Pagnini, Alberto González-Martínez und Stefano Bracco. Levelized Cost of Energy in Sustainable Energy Communities: A Systematic Approach for Multi-Vector Energy Systems. Springer International Publishing AG, 2022.

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Meier, Paul F. The Changing Energy Mix. Oxford University Press, 2020. http://dx.doi.org/10.1093/oso/9780190098391.001.0001.

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The energy mix is changing, and renewable energy is growing in importance. If you were born before 1989, you lived in a United States where no electricity was generated from either wind or solar power and very little from geothermal and biomass. By 2018, the combined generation from wind and solar had surpassed hydroelectricity. Fourteen states generated more than 10% of their electricity from wind and three generated more than 30%. And bioethanol, produced from corn grain, made up 10% of the US gasoline market. Changes have also occurred in the nonrenewable energy mix. Coal, which was responsible for 53% of the US electricity generation in 1998 is now only 28%, as natural gas has taken the leadership role, surpassing coal in 2015 as the primary energy for producing electricity. Similarly, the world did not see any electricity generation from wind until 1985 and none from solar until 1989. Now solar plus wind generate 7% of the worldwide electricity. The worldwide demand for all energy types is also increasing rapidly, as energy usage has increased 84% over the last twenty years. This book makes a systematic comparison of twelve different energy types to help understand the driving forces for this changing energy mix. Twelve common criteria are used to provide tools to make these comparisons, such as proven reserves, the levelized cost for each energy type, energy balances, environmental issues, and the energy footprint. Proven reserves are also projected for each renewable energy type.

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Buchteile zum Thema "Levelized cost of energy (LCOE)"

Hosseini, Seyed Vahid, Ali Izadi, Seyed Hossein Madani, Yong Chen und Mahmoud Chizari. „Design Procedure of a Hybrid Renewable Power Generation System“. In Springer Proceedings in Energy, 155–62. Cham: Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-030-63916-7_20.

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AbstractElectrification of small communities in districted off-grid area remains as a challenge for power generation industries. In the current study, various aspects of design of a standalone renewable power plant are examined and implemented in a case study of a rural area in Cape Town, South Africa. Estimating required electricity based on local demand profile, investment, operability, and maintenance costs of different generation technologies are studied in order to investigate their potential in an off-grid clean energy generation system. Several configurations of hybridization of solar system, wind, and micro gas turbine in combination with a battery are investigated. The Levelized Cost of Electricity (LCOE) and number of days with more than 3 h black out are compared.

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Roy, Riya, Abdullah Al Jubayer, Kazi Sadman Sakib, Najmus Sakib, Avijit Saha, M. Rezwan Khan und M. Shahedul Alam. „Policy Options While Increasing Share of Renewable Energy: Technology Choices for Peaking Power in the Context of Bangladesh“. In Energiepolitik und Klimaschutz. Energy Policy and Climate Protection, 67–86. Wiesbaden: Springer Fachmedien Wiesbaden, 2022. http://dx.doi.org/10.1007/978-3-658-38215-5_4.

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AbstractIn Bangladesh, the peaking power plants that serve the peak time loads use conventional fossil fuels for power generation. These power stations remain idle for a good part of their operating life, which therefore results in a high overhead cost. Continuous integration of renewables into the grid is increasing the dependency on these, so far, feasibility of no other less-expensive options has been studied. In this context, this paper aims to analyze the financial feasibility of different alternative options. Three possible options were analyzed and the levelized cost of energy (LCOE) was compared with that of conventional peaking power plants. It was found that Battery-based storage systems are not financially feasible at this moment, while the nation’s lone hydro power plant promises financial feasibility if solar PV driven pumped hydro storage is implemented. We also report that if the nation continues to add solar PV power stations even with costly peaking power plants using traditional fuels, this hybrid option was counter intuitively found to be financially feasible.

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Broughel, Anna, und Rolf Wüstenhagen. „The Influence of Policy Risk on Swiss Wind Power Investment“. In Swiss Energy Governance, 345–68. Cham: Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-030-80787-0_14.

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AbstractWind energy is one of the most affordable and fastest-growing sources of electricity worldwide. As a large share of wind power generation occurs in the winter season, it could make an important contribution to seasonal diversification of domestic electricity supply. However, the development of wind energy projects in Switzerland has been characterized by long and complex administrative processes, with the planning phase taking up to a decade, more than twice as long as the European average. The objective of this chapter is to quantify the risk premium that lengthy permitting processes imply for wind energy investors in Switzerland and to suggest ways to reduce policy risk. The data have been gathered through 22 confidential interviews with project developers and several cantonal permitting agencies as well as a review of federal and cantonal regulatory documents. Furthermore, a discounted cash flow model was built to compare the profitability indicators (IRR, NPV) and the levelized cost of electricity (LCOE) of a reference case to scenarios with various risks—for example, delays in the permitting process, downsizing the project, or changes in the regulatory environment such as phasing out feed-in tariffs. The model shows that the highest profitability risks are related to the availability of a feed-in tariff, but other changes in the permitting process can also have a critical impact on the project’s bottom line. The findings illustrate a significant policy risk premium in the pre-construction stage faced by wind energy project developers in Switzerland.

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Mahaver, Vineet Kumar, und K. V. S. Rao. „Estimation of Levelized Cost of Electricity (LCOE) of 1 MW SPV Plants Installed at 33 Different Locations in Rajasthan, India“. In Advances in Renewable Energy and Electric Vehicles, 199–208. Singapore: Springer Singapore, 2021. http://dx.doi.org/10.1007/978-981-16-1642-6_16.

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Bammeke, Daniel, Jonathan D. Nixon, James Brusey und Elena Gaura. „Multi-objective Energy Management Model for Stand-Alone Photovoltaic-Battery Systems: Application to Refugee Camps“. In Springer Proceedings in Energy, 81–91. Cham: Springer Nature Switzerland, 2023. http://dx.doi.org/10.1007/978-3-031-30960-1_9.

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AbstractDespite the benefits of stand-alone solar photovoltaic (PV) systems in the context of refugee camps, these systems fail within the first few years of operations—typically the first three years. The leading causes of the failure of solar PV systems in refugee camps are lack of technical personnel and maintenance, lack of training and education, and demand modification leading to overconsumption of energy from lead-acid batteries. This paper proposes a multi-objective energy management model that aims to increase the longevity of lead-acid batteries while considering the Levelized Cost of Used Energy (LCUE) and user satisfaction. Scenarios incorporating different levels of demand modification are proposed to verify the effectiveness of the proposed model. A weighted sum approach was applied to solve the multi-objective optimization problem. A sensitivity analysis was performed to illustrate the effect of varying the battery objective weight, on the model’s performance. Results show that the proposed model can increase battery lifetime by up to 9 years with a 33% decrease in LCUE in some cases. The results indicate that the proposed model is likely to be useful for refugee camps that experience rapidly increasing energy demand.

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Campbell, Matthew. „Levelized Cost of Energy for Utility-Scale Photovoltaics“. In Solar Cells and their Applications, 251–70. Hoboken, NJ, USA: John Wiley & Sons, Inc., 2010. http://dx.doi.org/10.1002/9780470636886.ch11.

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Hosseini, SeyedVahid, Ali Izadi, Afsaneh Sadat Boloorchi, Seyed Hossein Madani, Yong Chen und Mahmoud Chizari. „Optimal Design of Environmental-Friendly Hybrid Power Generation System“. In Springer Proceedings in Energy, 171–77. Cham: Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-030-63916-7_22.

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AbstractCombination of both renewable and fuel-based generation systems is an advantageous approach to develop off-grid distributed power plants. This approach requires evaluation of the techno-economic potential of each source in a selected site as well as optimization of load sharing strategy between them. Development of a remote hybrid power plant in an off-grid area is the interest of this study. Defining all available combinations, characteristics of performance, cost and availability of them evaluated. Applying constraints, multi-objective target domain based on load following and Levelized Cost of Electricity is established in which by utilizing Pareto front approach, optimized scenarios is achieved.

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Ellis, Timothy W., John A. Howes und Roger D. Feldman. „Engineering, Scientific, and Policy Inputs for Developing a Levelized Cost of Energy Storage Model“. In Energy Technology 2018, 309–17. Cham: Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-319-72362-4_27.

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Singh, Poonam, Manjaree Pandit und Laxmi Srivastava. „PSO-Based Optimization of Levelized Cost of Energy for Hybrid Renewable Energy System“. In Nature Inspired Optimization for Electrical Power System, 31–42. Singapore: Springer Singapore, 2020. http://dx.doi.org/10.1007/978-981-15-4004-2_3.

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Wahed, Arifeen, Monika Bieri, Tse K. Kui und Thomas Reindl. „Levelized Cost of Solar Thermal System for Process Heating Applications in the Tropics“. In Transition Towards 100% Renewable Energy, 441–50. Cham: Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-319-69844-1_40.

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Konferenzberichte zum Thema "Levelized cost of energy (LCOE)"

Schmitt, Joshua, Bikram Roychowdhury, Adam Swanger, Marcel Otto und Jayanta Kapat. „Techno-Economic Analysis of Green Hydrogen Energy Storage in a Cryogenic Flux Capacitor“. In ASME Turbo Expo 2024: Turbomachinery Technical Conference and Exposition. American Society of Mechanical Engineers, 2024. http://dx.doi.org/10.1115/gt2024-129208.

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Abstract The Cryogenic Flux Capacitor (CFC) is a cold, dense energy storage core that is being studied in the cryo-compressed, about 300 bar and 80K, region of gaseous hydrogen (GH2) storage and liquid hydrogen (LH2) region near the normal boiling point. Hydrogen storage is improved by physically bonding the molecules within the nanoscale pores of the aerogel composite blanket material. The process of bonding or debonding is governed by principles of physical adsorption (physisorption) and thermodynamics. The large surface area afforded by the nanoporous aerogel (∼1,000 m2/g) allows its storage performance to easily exceed capacities of high-pressure GH2 storage for an equivalent volume. With the integrated aerogel, subscale tests have shown that storage is increased by about 36% over a simple tank filled with GH2 at the same operating temperature and pressure. For LH2 conditions, the CFC is shown to operate at improved densities, but testing is ongoing. For the techno-economic analysis (TEA), the source of hydrogen is compared between onsite steam methane reforming (SMR) and onsite solar photovoltaic (PV) panels providing power to electrolyzers to produce green GH2. The TEA compares pure hydrogen produced at a small scale for a 25 MW power system and at a large scale in a 500 MW power system. The system allowed for hydrogen imports and exports at a set price with a tank sized for 10 hours of power production. The two power producing technologies are a combined cycle gas turbine (CCGT) and hydrogen fuel cells. The SMR system uses natural gas as an input and includes a carbon capture and storage (CCS) system. The levelized cost of electricity (LCOE), levelized cost of hydrogen (LCOH), and levelized cost of storage (LCOS) are developed based on the capital cost and operating cost of the systems. The results are shown for current costs using a 2021 benchmark and DOE projections for cost improvements by 2030. The TEA showed that onsite hydrogen generation from SMR has an LCOH of about 1.4 to 2 USD per kg over the life of the plant and the PV hydrogen production LCOH is about 5.2 to 5.5 USD per kg. The LCOS of conventional GH2 systems is estimated to be $210/MWh and cost of storage for LH2 systems is $205/MWh for fuel cell systems and $249/MWh for CCGT systems. CFC improved the LCOS of all these systems to $198/MWh, $191/MWh and $233/MWh respectively. The LCOE also improved with conventional systems between $171/MWh and $228/MWh improved by CFC to between $167/MWh and $212/MWh. Using projections for improvement in costs following DOE’s goals by 2030, green hydrogen improved to as low as $78/MWh LCOS and LCOE for conventional cases. CFC improved over conventional storage with the lowest LCOS being $62/MWh and the lowest LCOE being $73/MWh. These results correspond to an LCOH of $2/kg. Finally, the TEA shows how LCOE is improved for hydrogen conditioning and storage over conventional systems and caverns in the 10 to 50 hour range.

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Gobereit, Birgit, Lars Amsbeck, Reiner Buck und Csaba Singer. „Cost Analysis of Different Operation Strategies for Falling Particle Receivers“. In ASME 2015 9th International Conference on Energy Sustainability collocated with the ASME 2015 Power Conference, the ASME 2015 13th International Conference on Fuel Cell Science, Engineering and Technology, and the ASME 2015 Nuclear Forum. American Society of Mechanical Engineers, 2015. http://dx.doi.org/10.1115/es2015-49354.

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The potential for highly efficient and cost competitive solar energy collection at high temperatures drives the actual research and development activities for particle tower systems. One promising concept for particle receivers is the falling particle receiver. This paper is related to a particle receiver, in which falling ceramic particles form a particle curtain, which absorbs the concentrated solar radiation. Complex operation strategies will result in higher receiver costs, for both investment and operation. The objective of this paper is to assess the influence of the simultaneous variation of receiver costs and efficiency characteristics on levelized cost of heat (LCOH) and on levelized cost of electricity (LCOE). Applying cost assumptions for the particle receiver and the particle transport system, the LCOE are estimated and compared for each considered concept. The power level of the compared concepts is 125 MWel output at design point. The sensitivity of the results on the specific cost assumptions is analyzed. No detailed evaluation is done for the thermal storage, but comparable storage utilization and costs are assumed for all cases.

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González-Portillo, Luis F., Kevin J. Albrecht, Jeremy Sment, Brantley Mills und Clifford K. Ho. „Sensitivity Analysis of the Levelized Cost of Electricity for a Particle-Based CSP System“. In ASME 2021 15th International Conference on Energy Sustainability collocated with the ASME 2021 Heat Transfer Summer Conference. American Society of Mechanical Engineers, 2021. http://dx.doi.org/10.1115/es2021-63223.

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Abstract This study presents a sensitivity analysis of the LCOE for a particle-based system with the costs of the most current components. New models for the primary heat exchanger, thermal energy storage and tower are presented and used to establish lower and upper bounds for these three components. The rest of component costs such as particle cost, cavity cost, lift cost and balance of power are set to lower and upper bounds estimating a 25% of uncertainty. Some relevant parameters such as lift efficiency and storage thermal resistance are also included in the analysis with a 25% uncertainty. This study also includes an upgrade to the receiver model by including the wind effect in the efficiency, which was not included in previous publications. A parametric analysis shows the optimum values of solar multiple, storage hours, tower height and concentration ratio, and a probabilistic analysis provides a cumulative distribution function for a range of LCOE values. The results show that the LCOE could be below $0.06/kWh with a probability of 90%, where the highest uncertainty is on the primary heat exchanger cost.

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Luo, Jun, Michael Schuller und Thomas Lalk. „Trough Type Concentrating Solar Power Plant Cost Assessment With Component Scaling“. In ASME 2012 6th International Conference on Energy Sustainability collocated with the ASME 2012 10th International Conference on Fuel Cell Science, Engineering and Technology. American Society of Mechanical Engineers, 2012. http://dx.doi.org/10.1115/es2012-91392.

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A detailed numerical and empirical systems analysis tool was developed which incorporated component scaling cost equations. It was benchmarked against the known data from the Andasol-1 plant in Spain, and then used to evaluate the effect of changes in the size of the solar field, the thermal energy storage system, and the power block on the levelized cost of electricity (LCOE) for the plant. The simulation result indicates that when the power plant capacity increases from 50 MW to 400 MW, the LCOE decreases by 32%. Also, the model’s results indicate that an oversized field and thermal energy storage tanks help to lower the LCOE.

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Bruck, Maira, Navid Goudarzi und Peter Sandborn. „A Levelized Cost of Energy (LCOE) Model for Wind Farms That Includes Power Purchase Agreement (PPA) Energy Delivery Limits“. In ASME 2016 Power Conference collocated with the ASME 2016 10th International Conference on Energy Sustainability and the ASME 2016 14th International Conference on Fuel Cell Science, Engineering and Technology. American Society of Mechanical Engineers, 2016. http://dx.doi.org/10.1115/power2016-59608.

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The cost of energy is an increasingly important issue in the world as renewable energy resources are growing in demand. Performance-based energy contracts are designed to keep the price of energy as low as possible while controlling the risk for both parties (i.e., the Buyer and the Seller). Price and risk are often balanced using complex Power Purchase Agreements (PPAs). Since wind is not a constant supply source, to keep risk low, wind PPAs contain clauses that require the purchase and sale of energy to fall within reasonable limits. However, the existence of those limits also creates pressure on prices causing increases in the Levelized Cost of Energy (LCOE). Depending on the variation in capacity factor (CF), the power generator (the Seller) may find that the limitations on power purchasing given by the utility (the Buyer) are not favorable and will result in higher costs of energy than predicted. Existing cost models do not take into account energy purchase limitations or variations in energy production when calculating an LCOE. A new cost model is developed to evaluate the price of electricity from wind energy under a PPA contract. This study develops a method that an energy Seller can use to negotiate delivery penalties within their PPA. This model has been tested on a controlled wind farm and with real wind farm data. The results show that LCOE depends on the limitations on energy purchase within a PPA contract as well as the expected performance characteristics associated with wind farms.

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Haynes, Megan W., Andrey Gunawan und Shannon K. Yee. „Techno-Economic Comparison Between Conventional and Innovative Combined Solar Thermal Power and Desalination Methods for Cogeneration“. In ASME 2018 Power Conference collocated with the ASME 2018 12th International Conference on Energy Sustainability and the ASME 2018 Nuclear Forum. American Society of Mechanical Engineers, 2018. http://dx.doi.org/10.1115/power2018-7515.

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The U.S. Department of Energy (DOE) has determined that solar power coupled desalination could be the next step in helping to resolve the water-energy nexus. For many decades, integration of concentrating solar power (CSP) electricity generation for combined power and water production has typically utilized the conventional method of steam Rankine cycles. Current research focuses on an enticing innovative method which combines CSP with Brayton cycles and uses supercritical CO2 (sCO2) as a working fluid, allowing for a broader temperature range. This techno-economic study analyzes the power and possible freshwater generation of each cycle and provides a comparison of the techno-economic advantages associated with each technology when applied to desalination processes. The results of this study suggest that recompression-closed Brayton (RCBR) cycle is likely to have the most significant impact in decreasing the levelized cost of electricity (LCOE), almost halving it from combining CSP with the traditional Rankine cycle. Also, to minimize levelized cost of water (LCOW) a smaller scale desalination facility which utilizes multi-effect distillation with thermal vapor compression (MED/TVC) instead of multi-stage flash distillation (MSF) is most applicable. Although the lowest LCOE values are for wet-cooled RCBR with MSF and MED/TVC, in areas where freshwater generation is crucial to be optimized there is only a 0.04 cents/kWh increase for dry-cooled RCBR with MED/TVC to a cost of 9.8 cents/kWh. This suggests the best candidate for optimizing freshwater generation while minimizing both LCOW and LCOE is dry-cooled RCBR with MED/TVC desalination.

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McCabe, Rebecca, Olivia Murphy und Maha Haji. „Multidisciplinary Optimization to Reduce Cost and Power Variation of a Wave Energy Converter“. In ASME 2022 International Design Engineering Technical Conferences and Computers and Information in Engineering Conference. American Society of Mechanical Engineers, 2022. http://dx.doi.org/10.1115/detc2022-90227.

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Abstract Wave energy converters (WECs) can advance the global energy transition by producing clean power for utility grids and offshore technologies. This paper provides a multidisciplinary, dual objective optimization of the Reference Model 3 (RM3), a two-body point absorber WEC design benchmark. The simulation model employs linear hydrodynamics with force saturation and probabilistic waves. The RM3 geometry and controller parameters are optimized using sequential quadratic programming to minimize the levelized cost of energy (LCOE) and the coefficient of variation of power. The minimum-LCOE design produces a power variation of 205% and an LCOE of $0.08/kWh, a seven-fold cost reduction and 23% lower variation from the RM3 baseline of $0.75/kWh and 255% variation. Parameter sensitivities show that LCOE depends more strongly on site and economic parameters than geometric or material parameters, while power variation is largely insensitive to all parameters. A Pareto trade-offbetween cost and power variation reveals different optimal designs depending on which objective is prioritized, suggesting application-specific design heuristics. Three representative optimal designs are investigated: a minimum-LCOE design for cost-sensitive operations like utility power, a minimum-variation design for cost-insensitive installations like small offshore systems, and a balanced design for intermediate applications. Power probability distributions are shown for each.

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Maali Amiri, Mojtaba, Jeferson Osmar de Almeida, Clarissa Bergman-Fonte, Milad Shadman und Segen F. Estefen. „Impact of Wake Effect on the Levelized Cost of Energy for a Wind Farm Offshore Rio De Janeiro“. In ASME 2023 42nd International Conference on Ocean, Offshore and Arctic Engineering. American Society of Mechanical Engineers, 2023. http://dx.doi.org/10.1115/omae2023-102271.

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Abstract The present paper aims at investigating the impact of the wake effect on the levelized cost of energy (LCOE) of a wind farm located offshore Rio de Janeiro. The study is performed using the reference 15-megawatt (MW) offshore wind turbine of the International Energy Agency (IEA). The wind farm is defined over a square area, where initially 5 × 5 × 15MW wind turbines are placed uniformly over this area. To investigate the impact of the wake effect on the LCOE, the wind farm buildable area is varied systematically from (4 × 3D) × (4 × 3D) to (4 × 15D) × (4 × 15D), where D is the rotor diameter. To perform the wind farm layout optimization, a symmetrical layout optimization algorithm available within the WindFarmer: Analyst software of DNV GL is used. Further, the wake effect is considered by using a simplified CFD-based model. Moreover, the wind data are predicted by Weather Research & Forecasting (WRF) Model at the hub height of the wind turbine. The results show that considering the optimum layout the wake effect is responsible for an increase of about 2% to 30% in the LCOE values for the studied wind farm buildable areas.

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Schwarz, Peter, Navid Goudarzi und Ercument Camadan. „Adjusting the Levelized Cost of Energy for Different Rates of Compensation for Solar Generation: A Case Study“. In ASME 2020 Power Conference collocated with the 2020 International Conference on Nuclear Engineering. American Society of Mechanical Engineers, 2020. http://dx.doi.org/10.1115/power2020-16938.

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Abstract The levelized cost of energy (LCOE) was developed for conventional, non-renewable energy sources, and can be misleading for renewable sources. The intermittent nature of renewable energy resources requires further refining the LCOE definition to prevent overvaluing renewables. Utilities must consider revenues as well as costs in comparing renewables to each other, as well as to conventional, non-renewable fuels. This paper explores the utility net revenues from solar energy — revenues from customer grid purchases net of payments made for solar generation by the customer exported to the utility — under three rate alternatives: Net Metering, Net Purchasing, and Gross Metering. Using individual customer data from Austin Energy for solar customers for the year of 2018, the net revenues to the utility under these three mechanisms were studied for two cases: increasing block rates and flat rates. The results demonstrate that even though the levelized cost of solar adoption is unaffected by the choice of rate, solar adoption by the utility is generally most favorable under gross metering, and least favorable under net metering. Moreover, the outcome can differ on whether the utility uses flat rates or increasing block rates, and on the customer’s level of consumption. This work provides a broader system-level understanding of renewable energy technologies that can be used by engineers, researchers, and government agencies when studying the life-cycle cost of power-generating systems.

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Schmitt, Joshua, Jason Wilkes, Timothy Allison, Jeffrey Bennett, Karl Wygant und Robert Pelton. „Lowering the Levelized Cost of Electricity of a Concentrating Solar Power Tower With a Supercritical Carbon Dioxide Power Cycle“. In ASME Turbo Expo 2017: Turbomachinery Technical Conference and Exposition. American Society of Mechanical Engineers, 2017. http://dx.doi.org/10.1115/gt2017-64958.

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In order to maintain viability as a future power-generating technology, concentrating solar power (CSP) must reduce its levelized cost of electricity (LCOE). The cost of CSP is assessed with the System Advisor Model (SAM) from the National Renewable Energy Laboratory (NREL). The performance of an integrally geared compressor-expander recuperated recompression cycle with supercritical carbon dioxide (sCO2) as the working fluid is modeled. A comparison of the cycle model to the integrated SAM cycle performance is made. The cycle model incorporates innovative cycle control methods to improve the range of efficiency, including inventory control. The SAM model is modified to accommodate the predicted cycle performance. The ultimate goal of minimizing the LCOE is targeted through multiple approaches, including the cost of the power block, the impact of system scale, the sizing of the thermal system relative to the power block system, the operating approach for changes in ambient temperature and availability of sunlight. Through reduced power block cost and a detailed cycle model, the LCOE is modeled to be 5.98 ȼ/kWh, achieving targeted techno-economic performance. The LCOE of the CSP system is compared to the cost of hybrid solar and fossil-fired systems. An analysis is made on the efficacy of a fossil backup system with CSP and how that relates to potential future costs of carbon dioxide emissions.

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Berichte der Organisationen zum Thema "Levelized cost of energy (LCOE)"

Nahvi, Ali. Levelized cost of energy (LCOE) analysis of Hexcrete wind towers. Ames (Iowa): Iowa State University, Januar 2017. http://dx.doi.org/10.31274/cc-20240624-953.

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Stein, J., und G. Maugeri. Fact Sheet: Bifacial Tracking. International Energy Agency Photovoltaic Power Systems Programme, 2024. http://dx.doi.org/10.69766/ulmk1464.

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The Task 13 Fact Sheet on bifacial photovoltaic (PV) modules and advanced tracking systems highlights how these technologies revolutionize solar energy production. It details how bifacial PV modules, which capture light from both sides, paired with single-axis trackers, increase energy output by up to 35% compared to conventional systems. These systems achieve the lowest Levelized Cost of Electricity (LCOE) for over 90% of global markets, demonstrating rapid market growth and cost-effectiveness. Additionally, the fact sheet covers market development and provides an overview of system designs for optimal yield and value, including backtracking and adjustments for complex terrain and weather conditions.

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Al-Balawi, Ahmed, Shahid Hasan und Amro Elshurafa. The Economics of Offshore Wind-Based Hydrogen Production in Saudi Arabia. King Abdullah Petroleum Studies and Research Center, Dezember 2024. https://doi.org/10.30573/ks--2024-dp68.

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Offshore hydrogen production from offshore wind energy is gaining global attention as an appealing solution for scaling up green hydrogen production. The technoeconomic feasibility of integrating offshore wind into hydrogen production has been explored in various regions, but no comprehensive study exists concerning Saudi Arabia’s offshore wind potential. This work aims to assess the cost-effectiveness of producing hydrogen onshore versus offshore from wind power in the Red Sea. Via the use of a deterministic cost model, this study evaluates the levelized cost of hydrogen (LCOH) for both configurations. The results show that offshore wind farm costs and floating foundations are the major drivers of capital expenditure (CAPEX). While onshore electrolysis remains slightly less expensive than offshore electrolysis, both configurations require substantial cost reductions to compete with alternative onshore renewable energy sources.

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Kwan, Thomas, und Cedric Philibert. Optimizing Renewable Energy Integration and Grid Costs for Electrified Ammonia Production. Schneider Electric, August 2024. http://dx.doi.org/10.58284/se.sri/dghe6934.

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The global energy transition and the need to decarbonize the chemicals industry have highlighted the potential of electrified ammonia production (e-ammonia) as a sustainable, low-carbon pathway. This comprehensive techno-economic analysis integrates renewable energy, advanced process controls, and a systems-level approach to optimize e-ammonia production. The study examines five energy mix scenarios and two process flexibility configurations, optimizing key components to minimize the levelized cost of ammonia (LCOA) production. Key findings include: Renewable energy integration, particularly in hybrid grid and renewable scenarios, reduces LCOA compared to grid-only electricity. Flexible Haber-Bosch configurations outperform nonflexible setups in cost reduction and resilience to grid price variability. Optimizing energy and hydrogen storage is crucial for adapting to intermittent renewable energy sources and minimizing costs. Advanced process controls and digital technologies enhance the utilization of low-cost, clean electricity and resilience to grid pricing uncertainties. Continued research in renewable energy technologies is essential for reducing the environmental footprint of e-ammonia. The study demonstrates that e-ammonia production remains economically viable across various grid pricing scenarios, emphasizing the robustness of renewable energy integration. Achieving fully decarbonized, green ammonia production is possible through power purchase agreements and increased renewable energy penetration. The transition to sustainable ammonia has significant social and geographic implications, requiring concerted efforts from policymakers, industry leaders, researchers, and local communities to ensure a just and sustainable transition. This research provides a compelling case for the adoption of e-ammonia technologies to decarbonize the ammonia industry while maintaining economic viability.

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Ennis, Brandon Lee, und D. Todd Griffith. System Levelized Cost of Energy Analysis for Floating Offshore Vertical-Axis Wind Turbines. Office of Scientific and Technical Information (OSTI), August 2018. http://dx.doi.org/10.2172/1466530.

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Cory, K., und P. Schwabe. Wind Levelized Cost of Energy: A Comparison of Technical and Financing Input Variables. Office of Scientific and Technical Information (OSTI), Oktober 2009. http://dx.doi.org/10.2172/966296.

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Housner, Stein, und Daniel Mulas Hernando. Levelized Cost of Energy Comparison of Floating Wind Farms With and Without Shared Anchors. Office of Scientific and Technical Information (OSTI), Mai 2024. http://dx.doi.org/10.2172/2348901.

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Jenkin, Thomas J., David J. Feldman, Alan Kwan und Brian J. Walker. Estimating the Impact of Residual Value for Electricity Generation Plants on Capital Recovery, Levelized Cost of Energy, and Cost to Consumers. Office of Scientific and Technical Information (OSTI), Januar 2019. http://dx.doi.org/10.2172/1493401.

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Lee, Nathan, Ricardo Cardoso de Oliveira, Billy Roberts, Jessica Katz, Thomas Brown und Francisco Flores-Espino. Exploring Renewable Energy Opportunities in Select Southeast Asian Countries: A Geospatial Analysis of the Levelized Cost of Energy of Utility-Scale Wind and Solar Photovoltaics. Office of Scientific and Technical Information (OSTI), Juni 2019. http://dx.doi.org/10.2172/1527336.

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Hayat, Muhammad Adnan, Shahid Hasan und Amro Elshurafa. Strategic Priorities and Cost Considerations for Decarbonizing Electricity Generation Using CCS and Nuclear Energy. King Abdullah Petroleum Studies and Research Center, August 2024. http://dx.doi.org/10.30573/ks--2024-dp27.

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This paper investigates the economics of deploying carbon capture and storage (CCS) on gas-fired power plants while covering its entire value chain, i.e., carbon capture, transport, and storage, and conducting a thorough sensitivity scenario analysis. Our analysis shows that adopting CCS translates into a carbon dioxide (CO2) capture cost ranging from $86 to $130 per tonne ($/tonne) for newly built and retrofit plants, depending on the natural gas price. The latter was found to be a significant parameter impacting costs. Transport and storage will result in an additional ~$24/tonne to the overall cost of carbon management. It was also found that, even after several years of being in commission, a gas plant can be retrofitted with CCS economically from a carbon abatement cost perspective. Finally, from a purely levelized cost viewpoint, and compared with natural gas power plants, nuclear energy emerges as the more cost-effective option if the natural gas price exceeds the threshold of ~$4 per million British thermal units ($/MMBtu). Other strategic and operational aspects of natural gas and nuclear generation that impact their deployment, beyond their finances, are also discussed and contrasted.

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