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Статті в журналах з теми "Levelized cost of heat":
1
Sing, Calvin Kong Leng, Jeng Shiun Lim, Timothy Gordon Walmsley, Peng Yen Liew, Masafumi Goto, and Sheikh Ahmad Zaki Bin Shaikh Salim. "Time-Dependent Integration of Solar Thermal Technology in Industrial Processes." Sustainability 12, no. 6 (March 16, 2020): 2322. http://dx.doi.org/10.3390/su12062322.
Solar energy is currently an underutilized renewable energy source that could fulfill low-temperature industrial heat demands with significant potential in high solar irradiance counties such as Malaysia. This study proposes a new systematic method for optimization of solar heat integration for different process options to minimize the levelized cost of heat by combining different methods from the literature. A case study from the literature is presented to demonstrate the proposed method combined with meteorological data in Malaysia. The method estimates capital cost and levelized cost of solar heating considering important physical constraints (e.g., available space) and recovery of waste heat. The method determines and optimizes important physical dimensions, including collector area, storage size, and control design. As the result of the case study, the solar thermal integration with Clean-In-Place streams (hot water) gives the lowest levelized cost of heat with RM 0.63/kWh (0.13 EUR/kWh) due to its lowest process temperature requirement. The sensitivity analysis indicates that collector price and collector efficiency are the critical parameters of solar thermal integration.
2
Gabbrielli, R., P. Castrataro, F. Del Medico, M. Di Palo, and B. Lenzo. "Levelized Cost of Heat for Linear Fresnel Concentrated Solar Systems." Energy Procedia 49 (2014): 1340–49. http://dx.doi.org/10.1016/j.egypro.2014.03.143.
Kearney, D., U. Herrmann, P. Nava, B. Kelly, R. Mahoney, J. Pacheco, R. Cable, N. Potrovitza, D. Blake, and H. Price. "Assessment of a Molten Salt Heat Transfer Fluid in a Parabolic Trough Solar Field." Journal of Solar Energy Engineering 125, no. 2 (May 1, 2003): 170–76. http://dx.doi.org/10.1115/1.1565087.
An evaluation was carried out to investigate the feasibility of utilizing a molten salt as the heat transfer fluid (HTF) and for thermal storage in a parabolic trough solar field to improve system performance and to reduce the levelized electricity cost. The operating SEGS (Solar Electric Generating Systems located in Mojave Desert, California) plants currently use a high temperature synthetic oil consisting of a eutectic mixture of biphenyl/diphenyl oxide. The scope of this investigation included examination of known critical issues, postulating solutions or possible approaches where potential problems exist, and the quantification of performance and electricity cost using preliminary cost inputs. The two leading candidates were the so-called solar salt (a binary salt consisting of 60% NaNO3 and 40% KNO3) and a salt sold commercially as HitecXL (a ternary salt consisting of 48% CaNO32, 7% NaNO3, and 45% KNO3). Assuming a two-tank storage system and a maximum operation temperature of 450°C, the evaluation showed that the levelized electricity cost can be reduced by 14.2% compared to a state-of-the-art parabolic trough plant such as the SEGS plants. If higher temperatures are possible, the improvement may be as high as 17.6%. Thermocline salt storage systems offer even greater benefits.
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Coppitters, Diederik, Ward De Paepe, and Francesco Contino. "Robust design optimization of a renewable-powered demand with energy storage using imprecise probabilities." E3S Web of Conferences 238 (2021): 10004. http://dx.doi.org/10.1051/e3sconf/202123810004.
During renewable energy system design, parameters are generally fixed or characterized by a precise distribution. This leads to a representation that fails to distinguish between uncertainty related to natural variation (i.e. future, aleatory uncertainty) and uncertainty related to lack of data (i.e. present, epistemic uncertainty). Consequently, the main driver of uncertainty and effective guidelines to reduce the uncertainty remain undetermined. To assess these limitations on a grid-connected household supported by a photovoltaic-battery system, we distinguish between present and future uncertainty. Thereafter, we performed a robust design optimization and global sensitivity analysis. This paper provides the optimized designs, the main drivers of the variation in levelized cost of electricity and the effect of present uncertainty on these drivers. To reduce the levelized cost of electricity variance for an optimized photovoltaic array and optimized photovoltaic-battery design, improving the determination of the electricity price for every specific scenario is the most effective action. For the photovoltaic-battery robust design, the present uncertainty on the prediction accuracy of the electricity price should be addressed first, before the most effective action to reduce the levelized cost of electricity variance can be determined. Future work aims at the integration of a heat demand and hydrogen-based energy systems.
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Mehrdad, Sina, Reza Dadsetani, Alireza Amiriyoon, Arturo S. Leon, Mohammad Reza Safaei, and Marjan Goodarzi. "Exergo-Economic Optimization of Organic Rankine Cycle for Saving of Thermal Energy in a Sample Power Plant by Using of Strength Pareto Evolutionary Algorithm II." Processes 8, no. 3 (February 26, 2020): 264. http://dx.doi.org/10.3390/pr8030264.
Waste heat recovery plays an important role in energy source management. Organic Rankine Cycle (ORC) can be used to recover low-temperature waste heat. In the present work a sample power plant waste heat was used to operate an ORC. First, two pure working fluids were selected based on their merits. Four possible thermodynamic models were considered in the analysis. They were defined based on where the condenser and evaporator temperatures are located. Four main thermal parameters, evaporator temperature, condenser temperature, degree of superheat and pinch point temperature difference were taken as key parameters. Levelized energy cost values and exergy efficiency were calculated as the optimization criteria. To optimize exergy and economic aspects of the system, Strength Pareto evolutionary algorithm II (SPEA II) was implemented. The Pareto frontier solutions were ordered and chose by TOPSIS. Model 3 outperformed all other models. After evaluating exergy efficiency by mixture mass fraction, R245fa [0.6]/Pentane [0.4] selected as the most efficient working fluid. Finally, every component’s role in determining the levelized energy cost and the exergy efficiency and were discussed. The turbine, condenser and evaporator were found as the costliest components.
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Doračić, Borna, Tomislav Pukšec, Daniel Rolph Schneider, and Neven Duić. "The effect of different parameters of the excess heat source on the levelized cost of excess heat." Energy 201 (June 2020): 117686. http://dx.doi.org/10.1016/j.energy.2020.117686.
Buongiorno, Jacopo, Ben Carmichael, Bradley Dunkin, John Parsons, and Dirk Smit. "Can Nuclear Batteries Be Economically Competitive in Large Markets?" Energies 14, no. 14 (July 20, 2021): 4385. http://dx.doi.org/10.3390/en14144385.
We introduce the concept of the nuclear battery, a standardized, factory-fabricated, road transportable, plug-and-play micro-reactor. Nuclear batteries have the potential to provide on-demand, carbon-free, economic, resilient, and safe energy for distributed heat and electricity applications in every sector of the economy. The cost targets for nuclear batteries in these markets are 20–50 USD/MWht (6–15 USD/MMBTU) and 70–115 USD/MWhe for heat and electricity, respectively. We present a parametric study of the nuclear battery’s levelized cost of heat and electricity, suggesting that those cost targets are within reach. The cost of heat and electricity from nuclear batteries is expected to depend strongly on core power rating, fuel enrichment, fuel burnup, size of the onsite staff, fabrication costs and financing. Notional examples of cheap and expensive nuclear battery designs are provided.
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Peppas, Antonis, Konstantinos Kollias, Hussam Jouhara, Michele Scotton, and Theodoros Kakardakos. "Cross-Cutting Technologies for Developing Innovative BIPV Systems in the Framework of the PVadapt Project." Proceedings 65, no. 1 (December 23, 2020): 6. http://dx.doi.org/10.3390/proceedings2020065006.
In the framework of the PVadapt H2020 project, a sustainable and fully adaptable building-integrated photovoltaic–thermal (BIPVT) system of substantially lower cost than conventional in-market solutions will be developed. A flexible automated process will be employed to produce PV modules as well as elements with integrated heat pipe-based heat recovery. These active energy components will be combined with passive components with structural, thermal, and other functions to produce prefabricated modules. A smart envelope System, featuring grid connectivity, load prediction/shifting, and insolation/temperature predictive algorithms, will be integrated in the BIPVT to maximize energy efficiency and cost saving. The unit cost of production, the levelized cost of energy (LCOE), and the payback period of the multifunctional BIPVT module will be below 200 €/m2, 2 ct/kWh, and 10 years, respectively.
9
Al-Ansary, Hany. "Prospects for Use of Solar Thermal Energy in High-Temperature Process Heat Applications." Applied Mechanics and Materials 819 (January 2016): 16–20. http://dx.doi.org/10.4028/www.scientific.net/amm.819.16.
Concentrating solar power is a family of solar energy technologies that have been used for decades to produce power. These technologies have a unique advantage, which is the ability to store thermal energy for prolonged periods of time such that stable and dispatchable energy can be provided to the electricity grid. However, concentrating solar power has been recently losing market share to photovoltaic technology due to the former’s significantly higher initial cost. There are many efforts worldwide to develop innovative solutions that reduce the cost and/or increase efficiency of concentrating solar power systems. However, concentrating solar thermal energy already has great promising area of application that is still largely unexplored, and that is high-temperature industrial process heat. This study attempts to make the case for using concentrating solar thermal energy in process heat applications by examining the economic feasibility (represented by the levelized cost of energy) for three scenarios of deployment, where the temperature levels are 400°C, 550°C, and 700°C, respectively. The first scenario uses parabolic trough collectors, while the second uses a central receiver system, both with 12 hours of molten salt storage. The third scenario uses a central receiver system that employs the innovative falling particle receiver concept to push the operating limit to 700°C, and silica sand is used to store thermal energy for 12 hours. The location chosen for this analysis is Alice Springs, Australia, due to its high direct normal irradiance and the presence of mining industries in its vicinity. The analysis shows that all three scenarios have a lower levelized cost of energy when compared to natural gas. To further confirm these findings, the analysis needs to be extended to other locations to account for different solar resources and different economic constraints.
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Aprile, Marcello, Rossano Scoccia, Alice Dénarié, Pál Kiss, Marcell Dombrovszky, Damian Gwerder, Philipp Schuetz, Peru Elguezabal, and Beñat Arregi. "District Power-To-Heat/Cool Complemented by Sewage Heat Recovery." Energies 12, no. 3 (January 24, 2019): 364. http://dx.doi.org/10.3390/en12030364.
District heating and cooling (DHC), when combined with waste or renewable energy sources, is an environmentally sound alternative to individual heating and cooling systems in buildings. In this work, the theoretical energy and economic performances of a DHC network complemented by compression heat pump and sewage heat exchanger are assessed through dynamic, year-round energy simulations. The proposed system comprises also a water storage and a PV plant. The study stems from the operational experience on a DHC network in Budapest, in which a new sewage heat recovery system is in place and provided the experimental base for assessing main operational parameters of the sewage heat exchanger, like effectiveness, parasitic energy consumption and impact of cleaning. The energy and economic potential is explored for a commercial district in Italy. It is found that the overall seasonal COP and EER are 3.10 and 3.64, while the seasonal COP and EER of the heat pump alone achieve 3.74 and 4.03, respectively. The economic feasibility is investigated by means of the levelized cost of heating and cooling (LCOHC). With an overall LCOHC between 79.1 and 89.9 €/MWh, the proposed system can be an attractive solution with respect to individual heat pumps.
Shah, Hassim. "Integration of solar thermal collectors in the dairy industry: A techno-economic assessment : A case study of Dubai." Thesis, Uppsala universitet, Institutionen för elektroteknik, 2021. http://urn.kb.se/resolve?urn=urn:nbn:se:uu:diva-446212.
A predominant amount of energy needed in the industrial sector is in the form of heat. A significant number of industries in the world still relies on fossil fuels for meeting their heat requirements. A transition to renewable energy for heating needs is at a snail's pace due to fossil fuel lock-in, cost superiority of conventional fuels, and less government support for renewable technology for thermal requirements. The dairy industry is one of the sectors that need heat energy for its production process. This study deals with a techno-economic analysis on the integration of parabolic trough collectors in the dairy industry. The thesis finds the barriers for solar-thermal collectors to evolve in the dairy sector and the viewpoint of the dairy industry towards the acceptance of solar thermal for meeting their thermal needs. From a literature review, it is observed that the need for dairy product will increase in the coming year. To meet the demand, the production process has to be increased. For sustainable production, companies have to rely on environment-friendly energy sources to meet the thermal demand. In the thesis work, it was also found that for several solar fractions, the LevelizedCost of Heat (LCoH) of solar-assisted heating system is less than the LCoH of the fossil-fueled conventional boiler. Therefore, it is economically viable to integrate solar thermal collectors in the dairy industry. The project also compares the LCoHof solar-assisted heating system when solar integration is done at a) feed water heating, b) direct steam generation, and c) process integration. The effect of integration point on the solar fraction, LCoH, and carbon mitigation potential is presented for a real case dairy unit in Dubai. The simulations are performed using a dynamic simulation tool. Results show that minimum LCoH and solar fraction are achieved for process integration. The process integration results in up to 90 % of the solar fraction. Through process integration, the LCoH of the conventional boiler can be reduced by 60%.
2
Madaly, Kamalahasen. "Identifying the optimum storage capacity for a 100-MWe concentrating solar power plant in South Africa." Thesis, Stellenbosch : Stellenbosch University, 2014. http://hdl.handle.net/10019.1/86276.
Thesis (MEng)--Stellenbosch University, 2014. ENGLISH ABSTRACT: Central receiver power plants generate renewable electricity by exploiting the
energy provided by the sun. The conditions experienced in the Northern Cape
region of South Africa provide the ideal conditions for the development of these
plants. Without a storage medium these plants have capacity factors in the range
of 25-30%. The inclusion of a thermal energy storage medium provides the ability
to increase the capacity factors of these plants. Although storage increases the
costs, it results in better utilisation of the power block and a decrease in the
levelised electricity cost (LEC). Eskom intends building a 100MWe central
receiver dry cooled power plant in the Upington region. This research identifies
the appropriate storage medium and ideal storage capacity to achieve the lowest
LEC.
A literature survey was performed to identify the different methods of storage that
are available. The different storage methods were evaluated and the best storage
medium for a central receiver power plant based on the developments of the
various storage technologies was identified.
To determine the costs associated with a central receiver power plant, data
published by NREL was used. Different plant parameters were required to
evaluate the costs. A power plant model based on efficiencies and energy balances
was created to determine the required plant parameters. It provided the ability to
determine the effect of changing different plant parameters on the LEC and
estimate the plant output. The power block parameters were initially varied to
determine the most efficient power block configuration. Once the most efficient
power block configuration was identified the solar field and storage parameters
were varied to determine the plant configuration which resulted in the lowest
LEC.
The most efficient power block configuration of 0.4206 was found for a system
comprising of six feedwater heaters with the feedwater temperature of 230°C,
main steam pressure 140 bar and an exit steam generator salt temperature of
290°C. A solar multiple of 3.0 with 16 hours of storage resulted in a LEC of
R1.41/kWh with no system constraints. A capacity factor constraint of 60%
resulted in a solar multiple of 1.8 with 8 hours of storage and a LEC of
R1.78/kWh. AFRIKAANSE OPSOMMING: Sonkragaanlegte met sentrale ontvangers wek hernubare elektrisiteit op deur
sonenergie te ontgin. Die klimaat in die Noord Kaap-streek van Suid-Afrika is
ideaal vir die oprigting van hierdie aanlegte. Sonder ’n bergingsmedium is die
kapasiteitsfaktore van sulke aanlegte ongeveer 25-30%. Met die insluiting van ’n
bergingsmedium vir termiese energie kan die kapasiteitsfaktore egter verhoog
word. Hoewel berging aanlegkoste verhoog, lei dit terselfdertyd tot beter
aanwending van die kragblok en ’n afname in die konstante eenheidskoste van
elektrisiteit (LEC). Eskom beplan om ’n droogverkoelde kragaanleg van 100 MW
met ’n sentrale ontvanger in die Upington-streek op te rig. Hierdie navorsing was
dus daarop toegespits om die mees geskikte bergingsmedium en ideale
bergingskapasiteit te bepaal om die laagste moontlike LEC uit die aanleg te
verkry.
’n Literatuurstudie is onderneem om die verskeie beskikbare bergingsmetodes te
bestudeer. Die verskillende metodes is beoordeel, waarna die beste
bergingsmedium vir ’n kragaanleg met ’n sentrale ontvanger op grond van die
ontwikkelings in die verskillende bergingstegnologieë bepaal is.
Om die koste van ’n kragaanleg met ’n sentrale ontvanger te bepaal, is
gepubliseerde data van die Amerikaanse Nasionale Laboratorium vir Hernubare
Energie (NREL) gebruik. Verskillende aanlegparameters was egter nodig om die
koste te beoordeel. Dié parameters is gevolglik bepaal deur ’n kragaanlegmodel
op grond van doeltreffendheidsfaktore en energiebalanse te skep. Sodoende kon
vasgestel word watter uitwerking veranderinge in die verskillende parameters op
die LEC sou hê, en kon die aanleguitset geraam word. Die kragblokparameters is
aanvanklik afgewissel om die doeltreffendste kragbloksamestel te bepaal. Nadat
dít bepaal is, is die sonenergieveld en bergingsparameters weer afgewissel om vas
te stel watter aanlegsamestel die laagste LEC tot gevolg sou hê. Die beste termiese benuttingsgraad is behaal vir ʼn stoom siklus met ses water
verhitters en ʼn water temperatuur van 230 °C by die ketel se inlaat, ʼn stoom druk
van 140 bar, en sout uitlaat temperatuur van 290 °C. ʼn Vermenigvuldigingsfaktor
van drie vir die heliostaat veld, en 16 uur termiese energie storing gee ʼn
opwekkingskoste van R 1.41/kW/h indien daar geen beperkings op die grootte of
koste van die stelsel geplaas word nie. Indien die kapitaal uitgawe ʼn perk van
60 % op die kapasitiet van die stelsel plaas, verander die optimale ontwerpspunt
na ʼn vermenigvuldigingsfaktor van 1.8, en die termiese stoorkapasitiet verlaag na
8 uur. In hierdie geval is die opwekkingskoste R 1.78/kWh.
3
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.
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.
4
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.
Kang, Moon Hee. "Development of high-efficiency silicon solar cells and modeling the impact of system parameters on levelized cost of electricity." Diss., Georgia Institute of Technology, 2013. http://hdl.handle.net/1853/47647.
The objective of this thesis is to develop low-cost high-efficiency crystalline silicon solar cells which are at the right intersection of cost and performance to make photovoltaics (PV) affordable. The goal was addressed by improving the optical and electrical performance of silicon solar cells through process optimization, device modeling, clever cell design, fundamental understanding, and minimization of loss mechanisms. To define the right intersection of cost and performance, analytical models to assess the premium or value associated with efficiency, temperature coefficient, balance of system cost, and solar insolation were developed and detailed cost analysis was performed to quantify the impact of key system and financial parameters in the levelized cost of electricity from PV.
6
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.
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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Akpomiemie, Mary Onome. "Cost effective retrofit methods for heat exchanger networks." Thesis, University of Manchester, 2016. https://www.research.manchester.ac.uk/portal/en/theses/cost-effective-retrofit-methods-for-heat-exchanger-networks(19a15828-0bb8-44ca-9669-be590409bd88).html.
Improving the energy efficiency of process plants is central to minimising operatingcosts and increasing profitability. Growing concerns on climate change is also anissue due to the increasing level of carbon dioxide emissions. Process industriesremain one of the largest consumers of energy. Maximising energy recovery in heatexchanger networks (HENs) reduce the total energy consumption in processindustries. However, cost effective retrofit of HENs remains a great challenge. Anideal retrofit design is one that has the right balance between efficient use of existingequipment and limited amount of modifications and downtime, while maximisingenergy recovery. The key objective of this thesis is to present novel methodologiesfor cost effective retrofit of HENs, while ensuring industrial applicability. The cost associated with the application of structural modifications and additionalheat transfer area, has led to an increased interest into the use of heat transferenhancement for retrofit. Heat transfer enhancement is beneficial, as it usuallyrequires low capital investment for fixed network topology, and no additional heattransfer area in existing heat exchangers. However, the challenges of heat transferenhancement for industrial applications are: (1) identifying the best heat exchangerto enhance; (2) dealing with downstream effects on the HEN after applyingenhancement; and (3) dealing with its effect on pressure drop. This thesis presentssequential based methodologies consisting of a combination of heuristics and a profitbased non-linear optimisation model for tackling these three issues. The robustnessof the new approach lies in its ability to provide useful insights into the interaction ofvarious units in a HEN whilst being pertinent for automation. Notwithstanding the drawbacks of structural modifications in retrofit, the degree ofenergy savings that can be obtained cannot be ignored. A robust retrofit strategy forthe application of structural modifications in retrofit is required. This thesis presentsa methodology that provides new fundamental insights into the application ofstructural modifications that ultimately leads to a faster retrofit procedure, withoutcompromising the performance and feasibility of the retrofitted HEN. The newapproach: (1) identifies the best location to apply a series of modifications; and (2)presents an algorithm that can be automated for the identification of the best singleand multiple modifications that provides maximum energy recovery for a givenHEN. The robustness of the new approach is tested by a comparison with the wellestablishedstochastic optimisation approach for structural modifications i.e.simulated annealing. To improve the retrofit result, this work also considerscombining the use of structural modifications and heat transfer enhancement. Theaim is to harnesses the benefits of both methods to obtain a cost effective retrofitdesign. The analysis carried out in this work is subject to minimising the energyconsumption and maximising the retrofit profit. A decision on the best retrofitstrategy to apply to a given HEN depends on the given retrofit objective. However,this work provides an adequate basis on which the decision can be made based onindustrial applicability, profit and energy saving.
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Ahmad, S. "Heat exchanger networks : Cost tradeoffs in energy and capital." Thesis, University of Manchester, 1985. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.376511.
Lamberts, R. "Heat transfer through roofs of low cost Brazilian houses." Thesis, University of Leeds, 1988. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.383003.
Colberg, Richard Dale Morari Manfred Morari Manfred. "Area, cost and resilience targets for heat exchanger networks /." Diss., Pasadena, Calif. : California Institute of Technology, 1989. http://resolver.caltech.edu/CaltechETD:etd-02062007-104756.
Fang, J. B. Minimum life cycle cost heat losses for shallow trench underground heat distribution systems. Gaithersburg, Md: U.S. Dept. of Commerce, National Bureau of Standards, 1986.
Rebello, Wilfred. Cost/performance analysis of high temperature waste heat recovery equipment: Final report. Washington, D.C: U.S. Dept. of Energy, Office of Industrial Programs, 1987.
Flanders, Stephen N. Measuring thermal performance of building envelopes: Nine case studies. [Hanover, N.H.]: US Army Corps of Engineers, Cold Regions Research & Engineering Laboratory, 1985.
Bogoslavska, Olga, Valentyna Stanytsina, Volodymyr Artemchuk, Oleksandr Garmata, and Viktoriia Lavrinenko. "Comparative Efficiency Assessment of Using Biofuels in Heat Supply Systems by Levelized Cost of Heat into Account Environmental Taxes." In Studies in Systems, Decision and Control, 167–85. Cham: Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-030-69189-9_10.
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.
Kozlova, Mariia, Leonid Chechurin, and Nikolai Efimov-Soini. "Levelized Function Cost: Economic Consideration for Design Concept Evaluation." In Advances in Systematic Creativity, 267–97. Cham: Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-319-78075-7_16.
Andagoya Alba, Daniel, Ximena Guamán Gavilanes, and Daniel Isaías Barzallo Núñez. "Levelized Cost of Storage (LCOS) Considering the Reliability of Battery Life." In Innovation and Research, 246–56. Cham: Springer International Publishing, 2020. http://dx.doi.org/10.1007/978-3-030-60467-7_21.
Cunha, Jorge, and Paula Ferreira. "Integration of Risk and Uncertainty on Levelized Cost of Electricity Calculation." In Innovation, Engineering and Entrepreneurship, 825–31. Cham: Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-319-91334-6_113.
Singh, Poonam, Manjaree Pandit, and 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.
Wahed, Arifeen, Monika Bieri, Tse K. Kui, and 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.
Dang, Genye, Hongsheng Su, and Biao Yue. "Levelized Cost of Energy Optimization Method for the Dish Solar Thermal Power Generation System." In Advances in Natural Computation, Fuzzy Systems and Knowledge Discovery, 132–40. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-32456-8_14.
Ellis, Timothy W., John A. Howes, and 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.
Тези доповідей конференцій з теми "Levelized cost of heat":
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González-Portillo, Luis F., Kevin J. Albrecht, Jeremy Sment, Brantley Mills, and 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.
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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Albrecht, Kevin J., Matthew L. Bauer, and Clifford K. Ho. "Parametric Analysis of Particle CSP System Performance and Cost to Intrinsic Particle Properties and Operating Conditions." In ASME 2019 13th International Conference on Energy Sustainability collocated with the ASME 2019 Heat Transfer Summer Conference. American Society of Mechanical Engineers, 2019. http://dx.doi.org/10.1115/es2019-3893.
Abstract The use of solid particles as a heat-transfer fluid and thermal storage media for concentrating solar power is a promising candidate for meeting levelized cost of electricity (LCOE) targets for next-generation CSP concepts. Meeting these cost targets for a given system concept will require optimization of the particle heat-transfer fluid with simultaneous consideration of all system components and operating conditions. This paper explores the trade-offs in system operating conditions and particle thermophysical properties on the levelized cost of electricity through parametric analysis. A steady-state modeling methodology for design point simulations dispatched against typical meteorological year (TMY) data is presented, which includes computationally efficient submodels of a falling particle receiver, moving packed-bed heat exchanger, storage bin, particle lift, and recompression supercritical CO2 (sCO2) cycle. The components selected for the baseline system configuration presents the most near-term realization of a particle-based CSP system that has been developed to date. However, the methodology could be extended to consider alternative particle receiver and heat exchanger concepts. The detailed system-level model coupled to component cost models is capable of propagating component design and performance information directly into the plant performance and economics. The system-level model is used to investigate how the levelized cost of electricity varies with changes in particle absorptivity, hot storage bin temperature, heat exchanger approach temperature, and sCO2 cycle operating parameters. Trade-offs in system capital cost and solar-to-electric efficiency due to changes in the size of the heliostat field, storage bins, primary heat exchanger, and receiver efficiency are observed. Optimal system operating conditions are reported, which approach levelized costs of electricity of $0.06 kWe−1hr−1.
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Gobereit, Birgit, Lars Amsbeck, Reiner Buck, and 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.
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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Singer, Cs, R. Buck, R. Pitz-Paal, and H. Mu¨ller-Steinhagen. "Assessment of Solar Power Tower Driven Ultra Supercritical Steam Cycles Applying Tubular Central Receivers With Varied Heat Transfer Media." In ASME 2009 3rd International Conference on Energy Sustainability collocated with the Heat Transfer and InterPACK09 Conferences. ASMEDC, 2009. http://dx.doi.org/10.1115/es2009-90476.
In commercial power plant technology, the market introduction of ultra supercritical (USC) steam cycle power plants with steam parameters around 350bar and 720°C is the next development step. USC steam cycles are also proposed to decrease the levelized electricity costs of future solar power towers due to their highly efficient energy conversion. A 55% thermal efficiency with decreased specific investment costs is within the potential of USC steam cycles. The required process parameters can be achieved using nickel based alloys in the solar receiver, the tubing and other plant components. For solar tower applications, appropriate high temperature heat transfer media (HTM), high temperature heat exchangers and storage options are additionally required. Using the current development for molten salt power towers (Solar Tres) as a reference, several tower concepts with USC power plants were compared. The ECOSTAR methodology provided by [1] was applied for predicting the cost reduction potential and the annual performance of these power tower concepts applying tubular receivers with various HTM. The considered HTM include alkali nitrate salts, alkali chloride salts and liquid metals such as a Bi-Pb eutectic, tin or sodium. For the assessment, an analytical model of the heat transfer in a parametric 360° cylindrical, tubular central receiver was developed to examine the receiver characteristics for different geometries. The sensitivity of the specific cost assumptions for the levelized electricity costs (LEC) was evaluated for each concept variation. No detailed evaluation was done for the thermal storage, but comparable costs were assumed for all cases. The results indicate a significant cost reduction potential for the liquid metal HTM processes.
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Lee, Young Duk, Kook Young Ahn, T. Morosuk, and G. Tsatsaronis. "Exergoeconomic Evaluation of a Solid-Oxide Fuel-Cell-Based Combined Heat and Power Generation System." In ASME 2013 International Mechanical Engineering Congress and Exposition. American Society of Mechanical Engineers, 2013. http://dx.doi.org/10.1115/imece2013-64527.
An exergoeconomic evaluation has been conducted for a 100kW-class SOFC power generation system, in order to evaluate the cost effectiveness of the system. The exergoeconomic analysis is an appropriate combination of an exergy analysis and an economic analysis. Through an exergoeconomic analysis, we obtain the real cost associated with each stream and component in a system. We also can calculate the portion of the cost that is associated with the exergy destruction within each component. The analyzed system, a 100kW SOFC power generation system, consists of SOFC stack, reformer, catalytic combustor, heat exchangers, pumps, blowers, inverter, and HRSG for heat recovery. As a first step, mass, energy, and exergy balances were formulated. Then a conventional exergetic analysis (based on the concept of exergy of fuel/exergy of product) was performed. Next, a levelized cost for each component was calculated based on the purchased equipment costs using the Total Revenue Requirement (TRR) method with appropriate economic assumptions. Finally, the cost structure of the SOFC was figured out through an exergoeconomic evaluation. Finally suggestions have been made for reducing the cost associated with the product of the system.
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Turchi, Craig S., Parthiv Kurup, and Guangdong Zhu. "Revisiting Parabolic Trough Concentrators for Industrial Process Heat in the United States." 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/power2016-59621.
After significant interest in the 1970s, but relatively few deployments, the use of concentrating solar collectors for thermal applications, including enhanced oil recovery, desalination, and industrial process heat (IPH), is again increasing in global interest. In particular, recent advances in collector design and manufacturing have led to reduced cost per square meter of aperture area. In this study, analysis of a modern parabolic trough that is suited for use in small solar IPH (SIPH) applications predicts that the installed solar field cost can be as low as $170/m2. A slightly higher cost of $200/m2 is estimated for facilities typical of a SIPH plant size. Full project costs will include additional costs for contingency, piping and heat exchanger interface, and project indirect costs. The cost for solar-generated heat by SIPH is quantified by defining the levelized cost of heat (LCOH). California offers a favorable environment for SIPH given its good insolation, gas prices typically higher than the national average, and policies promoting solar-thermal deployment. Given historically low gas prices, competing with natural gas remains the primary challenge to deployment. However, this study finds that the solar LCOH for many regions in California is lower than the LCOH from natural gas, using a representative installed solar hardware price and the average price for industrial natural gas in California. Lastly, modification are in progress to the parabolic trough model within NREL’s System Advisor Model (SAM) to allow users to more easily predict performance for these steam-generation applications.
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Yellowhair, Julius, and Charles E. Andraka. "A Cost/Performance Evaluation of Advanced Low-Cost Heliostat Reflective Facets." In ASME 2013 7th International Conference on Energy Sustainability collocated with the ASME 2013 Heat Transfer Summer Conference and the ASME 2013 11th International Conference on Fuel Cell Science, Engineering and Technology. American Society of Mechanical Engineers, 2013. http://dx.doi.org/10.1115/es2013-18348.
Heliostat reflective facets have traditionally been constructed with glass/silver and a metal back support. During the past year, Sandia National Laboratories evaluated low-cost materials and alternative manufacturing methods to construct facets with the goal of reducing current facet cost by at least 25% while maintaining surface slope errors at 1 milli-radians rms or below. Several companies developed prototype facet samples, which were optically evaluated at Sandia and compared to baseline facet samples using a proposed cost-to-performance metric. A cost-performance metric for comparing facets was developed by modeling and optimizing a 200 MWe power tower plant scenario in DELSOL, a computer code for system-level modeling of power tower systems. We varied the slope error on the facets and adjusted the cost on the facets to maintain the constant plant levelized cost of energy. The result of these models provides a chart of the facet optical performance and the allowable facet cost for a constant plant LCOE. The size of the prototype facet samples ranged from 1.4 to 3 m2. The measured optical slope errors were between 1 and 2 milli-radians rms when compared to a flat mirror design shape. Despite slope errors greater than 1 mrad rms, some of the prototype samples met the cost goals for this project using the cost-performance metric. Next steps are to work with the companies to improve the manufacturing processes and further reduce the cost and improve on the optical performance to reach DOE SunShot goal of $75/m2 for heliostats.
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Kearney, D., U. Herrmann, P. Nava, B. Kelly, R. Mahoney, J. Pacheco, R. Cable, N. Potrovitza, D. Blake, and H. Price. "Evaluation of a Molten Salt Heat Transfer Fluid in a Parabolic Trough Solar Field." In ASME Solar 2002: International Solar Energy Conference. ASMEDC, 2002. http://dx.doi.org/10.1115/sed2002-1065.
An evaluation was carried out to investigate the feasibility of utilizing a molten salt as the heat transfer fluid (HTF) and for thermal storage in a parabolic trough solar field to improve system performance and to reduce the levelized electricity cost. The operating SEGS plants currently use a high temperature synthetic oil consisting of a eutectic mixture of biphenyl/diphenyl oxide. The scope of this investigation included examination of known critical issues, postulating solutions or possible approaches where potential problems existed, and the quantification of performance and electricity cost using preliminary, but reasonable, cost inputs. The two leading candidates were the so-called solar salt (a binary salt consisting of 60% NaNO3 and 40% KNO3) and a salt sold commercially as HitecXL (a ternary salt consisting of 48% Ca(NO3)2, 7% NaNO3, and 45% KNO3).
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Feldhoff, Jan Fabian, Daniel Benitez, Markus Eck, and Klaus-Ju¨rgen Riffelmann. "Economic Potential of Solar Thermal Power Plants With Direct Steam Generation Compared to HTF Plants." In ASME 2009 3rd International Conference on Energy Sustainability collocated with the Heat Transfer and InterPACK09 Conferences. ASMEDC, 2009. http://dx.doi.org/10.1115/es2009-90298.
The direct steam generation (DSG) in parabolic trough collectors is a promising option to improve the mature parabolic trough solar thermal power plant technology of the Solar Energy Generating Systems (SEGS) in California. According to previous studies [1–3], the cost reduction of the DSG process compared to the SEGS technology is expected to be 8 to 25%. All these studies were more or less preliminary since they lacked detailed information on the design of collector fields, absorber tubes required for steam temperatures higher than 400°C and power blocks adapted to the specific needs of the direct steam generation. To bridge this gap, a detailed system analysis was performed within the German R&D project DIVA. Power blocks and collector fields were designed for four different capacities (5, 10, 50 and 100 MWel) and different live steam parameters. The live steam temperature was varied between saturation temperature and 500°C, and live steam pressures of 40, 64 and 100 bar were investigated. To assess the different cases, detailed yield analyses of the overall system were performed using hourly data for the direct normal irradiation and the ambient temperature for typical years. Based on these results the levelized costs of electricity were determined for all cases and compared to a reference system using synthetic oil as heat transfer fluid (HTF). This paper focuses on two main project findings. First, the 50 MWel DSG system parameter comparisons are presented. Second, the detailed comparison between a DSG and a SEGS-like 100 MWel system is given. The main result of the investigation is that the benefit of the DSG process depends on the project site and can reach an 11% reduction of the levelized electricity cost (LEC).
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Frantz, Cathy, Reiner Buck, and Lars Amsbeck. "Design and Cost Study of Improved Scaled-Up Centrifugal Particle Receiver Based on Simulation." In ASME 2020 14th International Conference on Energy Sustainability. American Society of Mechanical Engineers, 2020. http://dx.doi.org/10.1115/es2020-1626.
Abstract A numerical model of the CentRec® receiver has been developed and validated using the measurement data collected during the experimental test campaign of the centrifugal particle system at the solar tower Jülich. The model has been used to calculate the thermo-optical efficiency of a scaled-up 20 MWth receiver for various receiver geometries. A cost function has been deduced and was used to perform a technoeconomic optimization on an LCOH (levelized cost of heat) basis of the CentRec® receiver concept. Attractive LCOH as low as 0.0209 €/kWhth for a system with thermal storage, or as low as 0.0150 €/kWhth for the LCOH without storage, are predicted. This study has shown that the optimal configuration from an LCOH perspective for a 20 MWth centrifugal particle receiver reaches specific receiver costs of 35 €/kWth. Hereby the costs of the receiver can be reduced by 60 % compared to the original configuration.
Звіти організацій з теми "Levelized cost of heat":
1
Schiebler, Bert, Federico Giovannetti, and Stephan Fischer. INFO Sheet B05: Levelized Cost of Heat for Solar Thermal Systems with Overheating Prevention. IEA SHC Task 54, October 2018. http://dx.doi.org/10.18777/ieashc-task54-2018-0011.
Louvet, Yoann, Stephan Fischer, Simon Furbo, Federico Giovanetti, Franz Mauthner, Daniel Mugnier, and Daniel Philippen. INFO Sheet A01: LCOH for Solar Thermal Applications - Guideline for levelized cost of heat (LCOH) calculations for solar thermal applications. IEA SHC Task 54, December 2017. http://dx.doi.org/10.18777/ieashc-task54-2017-0015.
Ho, Clifford K., and James E. Pacheco. Levelized Cost of Coating (LCOC) for selective absorber materials. Office of Scientific and Technical Information (OSTI), August 2014. http://dx.doi.org/10.2172/1096256.
Fuller, L. C. User's manual for levelized power generation cost using an IBM PC. Office of Scientific and Technical Information (OSTI), June 1985. http://dx.doi.org/10.2172/5624624.
Ennis, Brandon Lee, and 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.
Cory, K., and P. Schwabe. Wind Levelized Cost of Energy: A Comparison of Technical and Financing Input Variables. Office of Scientific and Technical Information (OSTI), October 2009. http://dx.doi.org/10.2172/966296.
Coen, J. J., and J. G. Delene. User instructions for levelized power generation cost codes using an IBM-type PC. Office of Scientific and Technical Information (OSTI), January 1989. http://dx.doi.org/10.2172/6513136.
Jenkin, Thomas J., David J. Feldman, Alan Kwan, and 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), January 2019. http://dx.doi.org/10.2172/1493401.
Ramsden, T., D. Steward, and J. Zuboy. Analyzing the Levelized Cost of Centralized and Distributed Hydrogen Production Using the H2A Production Model, Version 2. Office of Scientific and Technical Information (OSTI), September 2009. http://dx.doi.org/10.2172/965528.
Butcher, Thomas, Rebecca Trojanowski, George Wei, and Michael Worek. Low Cost Polymer heat Exchangers for Condensing Boilers. Office of Scientific and Technical Information (OSTI), September 2015. http://dx.doi.org/10.2172/1232686.
