Thèses sur le sujet « Levelized cost of energy (LCOE) »

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.

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.<br><p>I was a distance student and did the presentation online via centra.</p>

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.<br>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.

La modernisation du réseau électrique (RE) par la mise en œuvre de micro-réseaux offre un potentiel significatif pour améliorer la résilience énergétique, la durabilité et l'efficacité. Cependant, cette transition implique de naviguer dans un ensemble complexe de défis techniques, économiques et environnementaux. Les micro-réseaux nécessitent une planification et une optimisation méticuleuses pour équilibrer la génération, le stockage et la consommation d'énergie tout en minimisant les coûts et les émissions de carbone. Atteindre cet équilibre nécessite des stratégies d'optimisation avancées capables de traiter les subtilités des composants du système et des dynamiques opérationnelles. L'objectif de cette recherche est d'améliorer les capacités de prise de décision des concepteurs de micro-réseaux en fournissant une approche globale pour la planification des micro-réseaux. L'étude offre une analyse approfondie du projet sur toute sa durée de vie, du point de vue technique, économique et environnemental. Implémenté en Python et résolu à l'aide de CPLEX, le processus d'optimisation vise à minimiser à la fois le « Levelized Cost of Energy » (LCOE) et le « Life Cycle Emission » (LCE). L'étude utilise des données économiques et environnementales réelles, en tenant compte de la croissance de la charge ainsi que des données réelles d'irradiation solaire, de température ambiante et de vitesse du vent. La charge pour le bâtiment universitaire est basée sur des données de l'Université de Technologie de Compiègne, France, avec la charge des véhicules électriques (VE) modélisée à l'aide d'une modélisation probabiliste. L'étude introduit une stratégie d'optimisation multi-objectifs conjointe utilisant le « Mixed Integer Linear Programming » (MILP) pour garantir des solutions globalement optimales, facilitant ainsi des choix de conception plus informés et efficaces. Ces choix impliquent l'évaluation de diverses solutions proposées pour équilibrer les coûts et les émissions de carbone tout en abordant les complexités et les contraintes techniques du problème de gestion de l'énergie. Un aspect novateur de ce travail est l'intégration de la gestion d'énergie (GE) et du dimensionnement des composants dans un problème d'optimisation unifié, visant un écart d'optimalité de 0 % avec un temps de calcul réduit par rapport à la littérature existante. La méthode proposée évalue les compromis inhérents entre diverses solutions, identifiant le front de Pareto et permettant un équilibre optimal entre les objectifs économiques et environnementaux. Les résultats indiquent une réduction significative du LCOE et du LCE dans le GCMG par rapport à l'IMG. L'étude révèle que la capacité du système de stockage d'énergie par batterie (BESS) augmente à mesure que le LCE diminue, et que le nombre de systèmes photovoltaïques est plus élevé lorsque le LCOE est plus bas pour les deux modes de fonctionnement. Cela se produit parce que le BESS a un LCE légèrement inférieur à celui du PV, et que le LCOE du PV est également inférieur à celui du BESS. De plus, à mesure que la limite du RE augmente, les fronts de Pareto deviennent plus bas et plus raides. En outre, le même algorithme MILP est appliqué pour optimiser les micro-réseaux d'un campus universitaire tertiaire dans diverses villes. L'étude intègre également des éoliennes (WT) et des charges de VE dans le micro-réseau. L'étude fournit une analyse comparative de trois scénarios (PV/BESS, WT/BESS et PV/WT/BESS) dans différentes villes, évalue les impacts des fluctuations saisonnières sur le LCOE et le LCE, et évalue comment les technologies des composants des micro-réseaux influencent les résultats du LCOE et du LCE. Les résultats indiquent que les scénarios incluant PV/WT/BESS produisent les valeurs de LCOE et de LCE les plus basses, tandis que le scénario WT/BESS aboutit aux valeurs de LCOE et de LCE les plus élevées<br>The modernization of the electricity grid (EG) through the implementation of microgrids offers significant potential for enhancing energy resilience, sustainability, and efficiency. However, this transition involves navigating a complex web of technical, economic, and environmental challenges. Microgrids require meticulous planning and optimization to balance energygeneration, storage, and consumption while minimizing costs and carbon emissions. Achievingthis balance calls for advanced optimization strategies, which are capable of addressing theintricacies of system components and operational dynamics. The objective of this research is to enhance the decision-making capabilities of microgrid designers by providing a comprehensive approach for microgrid planning. The study offers an in-depth analysis of the project’s lifetime from technical, economic, and environmental perspectives. Implemented in Python and solved using CPLEX, the optimization process aims to minimize both the levelized cost of energy (LCOE) and the levelized cost of emissions (LCE). The study utilizes real economic and environmental data considering load growth as well as actual solar irradiation, ambient temperature, and wind speed data. The load for the university building is based on data from the Université de Technologie de Compiègne, France with the electric vehicle (EV) load modeled using probabilistic modeling. The study introduces a joint multi-objective optimization strategy usingMixed-Integer Linear Programming (MILP) to ensure globally optimal solutions, thereby that facilitates obtaining more informed and effective design choices. These choices involve evaluating various proposed solutions to balance cost and carbon emissions while addressing the complexities and technical constraints of the energy management (EM) problem. A novel aspect of this work is the integration of EM and component sizing into a unified optimization problem, aiming for an optimality gap of 0% with reduced computation time compared to existing literature. The proposed method evaluates the inherent trade-offs among various solutions by identifying the Pareto front and allowing for an optimal balance between economic and environmental objectives. The results indicate a significant reduction in LCOE and LCE in the GCMG compared to the IMG. The study reveals that Battery Energy Storage System (BESS) capacity increases as the LCE decreases, and the number of Photovoltaic (PV) systems is higher when the LCOE is lower for both operation modes. This occurs because the BESS has a slightly lower LCE compared to PV, and the LCOE of PV is also lower than that of BESS. Furthermore, as the limit of the EG increases, the Pareto fronts become lower and steeper. Additionally, the same MILP algorithm is applied to optimize microgrids from a tertiary university campus across various cities. The study further integrates wind turbines (WT) and EV loads into the microgrid. The study provides a comparative analysis of three scenarios (PV/BESS, WT/BESS, and PV/WT/BESS) across different cities for evaluating the impacts of seasonal fluctuations on LCOE and LCE, and for assessing how microgrid component technologies influence LCOE and LCE outcomes. The results indicate that scenarios including PV/WT/BESS yield the lowest LCOE and LCE values, while the WT/BESS scenario results in the highest LCOE and LCE. It is also observed that the order of cities based on average solar irradiation or wind speed does not necessarily correspond to the order of LCOE and LCE. Monthly and daily fluctuations in solar irradiation and wind speed significantly impact these results. Regarding the technologies, locally produced PV panels contribute positively to the overall LCE of the microgrid, with PV panels incorporating phase changing material showing higher LCE. The research also compares two distinct algorithms

Electrification of households in rural area and isolated regions plays a significant impact on the balanced economic development. Brazil grows with a high population growth rate, but still parts of rural area and isolated regions do not have the accessibility of electric power. This study focuses on the feasibility study of a hybrid PV-wind-biomass power system for rural electrification at Nazaré Paulista in southeast Brazil. This study was performed by using the hybrid renewable energy system software HOMER. The wind and solar data was collected from Surface meteorology and Solar Energy-NASA, and the biomass data was collected and estimated from other previous studies. The result shows, the hybrid PV-wind-biomass renewable system can meet 1,601 kWh daily demands and 360 kW peak load of the selected rural area. The power system composed of 200 kW PV panels, 200 kW biomass generator, 400 battery banks, and 200 kW converter. All the calculations were performed by Homer and the selection were based on the Net Present Cost (NPC) and Levelized cost of energy (COE). Because of the fossil fuels’ negative impacts on human health and environment, all the energy sources for this system are renewable energies which have less pollution.

The aim of this thesis is to evaluate different repowering alternatives from the viewpoint of increasing power production from existing offshore wind farms (OWF), as some of the first commissioned OWFs are approaching the end of their expected lifetime. The thesis presents a literature review of components and financial aspects that are of importance for repowering of OWFs. In the literature review, risks and uncertainties regarding repowering are also lifted and analysed. The thesis contains a case study on Horns Rev 1 OWF, where three different repowering scenarios are evaluated by technical and financial performance, aiming to compare the cost of repowering alternatives. The design of the case study is based around previous studies of offshore repowering having focused mainly on achieving the lowest possible levelized cost of energy (LCoE) and highest possible capacity factor, often resulting in suggested repowering utilizing smaller wind turbines than the existing ones. In order to evaluate the financial viability of repowering alternatives, the software RETScreen Expert was used to estimate the annual energy production (AEP) after losses and calculate the net present value (NPV) and LCoE for lifetime extension and full repowering utilizing different capacity wind turbines. Input values from the literature as well as real wind resource measurements from the site was utilized to achieve as accurate results as possible. The result of the case study shows that repowering of OWFs have the possibility of providing a very strong business case with all scenarios resulting in a positive NPV as well as lower LCoE than the benchmarked electricity production price. Although the initial investment cost of the different repowering alternatives presented in this thesis still are uncertain to some extent, due to the lack of reliable costs for repowering alternatives, this thesis provides a base for further research regarding the repowering of OWFs.

Brazil\'s discoveries of large gas reservoirs in the offshore ultra-deep waters of the presalt fields show a promising scenario, along with strategic investment and adequate policy, for the development of natural gas infrastructure and a sustainable transition in the Brazilian electricity mix. Such transition should occur through the use of transnational natural gas pipelines connected to large industrial facilities and power stations, as part of strategic planning to expand industrial usage, and avoid the shortage of electricity supply, with economic and environmental advantages. Since the most important debates of the new millennium are focused on globalization and sustainable development for nations, transnational energy integration in Latin America has been receiving increasingly attention from researchers and policy makers. In this overall context, the purpose of the present research was to develop a model to study, in a comparative manner, the thermoelectric generation, as well as to analyze the effect of legal frameworks and governmental policies on the development of infrastructure and natural gas market in Brazil, with a detailed study of the most relevant market and regulatory mechanisms. A comparison was performed in terms of the most relevant regulatory legislation in Brazil and other relevant Member States of the South American economic block. The study also evaluates the sanctions imposed by ANEEL Resolution n. 583 of 2013 on suppliers, due to the lack of NG supply for thermoelectric utilities, proposing an alternative formula, thought to mitigate the influence of averages and other electricity market parameters, therefore decreasing the sanction value for the NG supplier, without compromising the contract neutrality. Different factors were analyzed in order to determine which technology would be the most efficient in terms of levelized costs. Results indicated that natural gas-fired generators are very competitive and efficient, when compared to other thermoelectric sources in both economic and environmental aspects, even when externalities were included. Also, that further strategic investment and adequate regulatory policy changes are required from the market agents, in order to foster the development of pipeline infrastructure and the expansion of natural gas use in Brazil. The study also demonstrates that the environmental impact of the CH4 leakage equals that of CO2 release from combustion at about 4.2% leakage on a mass basis, when methane leakage rises to a level in which natural gas becomes as greenhouse gas intensive as biomass.<br>As descobertas de substanciais reservatórios de gás natural no Brasil, localizados em águas ultra profundas após a camada Pré-Sal, demonstram um cenário promissor, aliado a investimentos estratégicos e a políticas públicas adequadas, para o desenvolvimento da infraestrutura de gás natural e uma transição sustentável na matriz elétrica brasileira. Tal transição deveria ocorrer por intermédio do uso de tubulação transnacional de gás natural, conectada a grandes instalações industriais e a usinas termelétricas, como parte de um planejamento estratégico voltado à expansão do uso de gás natural na indústria e a evitar a escassez no suprimento de energia elétrica, com vantagens econômicas e ambientais. Considerando que os debates mais relevantes do novo milênio estão focados na globalização e no desenvolvimento sustentável das nações, a integração transnacional na América Latina tem recebido crescente atenção por parte de pesquisadores e de elaboradores das políticas públicas. Nesse contexto geral, a proposta da presente pesquisa foi a de desenvolver um modelo para estudar, de uma forma comparativa, a geração termelétrica, bem como analisar o impacto do arcabouço jurídico-regulatório e das políticas governamentais no desenvolvimento da infraestrutura e do mercado do gás natural no Brasil, com um estudo detalhado dos mais relevantes mecanismos regulatórios e de mercado. Foi realizado, ainda, um comparativo da legislação regulatória do gás natural no Brasil com outros Estados-Membros relevantes do Mercosul. O estudo também avalia as sanções impostas pela Resolução ANEEL n. 583 de 2013 nos fornecedores, devido a corte no suprimento de gás natural para empreendimentos de geração termelétrica, propondo um cálculo alternativo visando a mitigar a influência das médias e outros parâmetros intrínsecos ao mercado de energia, dessa maneira reduzindo as sanções contratuais para o fornecedor de gás natural, sem prejudicar a neutralidade contratual. Diferentes fatores foram analisados de forma a determinar qual tecnologia seria a mais eficiente em termos de custos nivelados de eletricidade. Os resultados indicaram que as termelétricas a gás natural são muito competitivas e eficientes, quando comparadas com outros tipos de combustível, tanto pelo aspecto ambiental quanto pelo econômico, mesmo quando externalidades são incluídas. Ainda, que são necessárias mudanças nas políticas regulatórias e no investimento estratégico por parte dos agentes do mercado, de forma a incentivar o desenvolvimento de infraestrutura e a expansão do uso do gás natural no Brasil. O estudo também evidencia que o impacto ambiental do vazamento de CH4 se iguala àquele do CO2 liberado pela combustão em cerca de 4.2% em base mássica, quando o vazamento de metano atinge um nível em que seu impacto como gás do efeito estufa fica equivalente à biomassa.

Per poter valutare, dal punto di vista economico, in quali condizioni la tecnologia da fusione può essere un elemento chiave di un sistema di generazione elettrica futuro, è indispensabile disporre di strumenti di calcolo adeguati, in grado di simulare in modo semplice un reattore a fusione calcolando il costo di generazione, un sistema energetico, composto da differenti centrali elettriche, e di valutare per il sistema il costo medio di generazione. Il lavoro di tesi inizia con la presentazione del codice di calcolo FRESCO (Fusion REactor Simplified COst): un codice sviluppato in linguaggio C++ che mira a modellare in modo semplificato un reattore a fusione basato sulla configurazione tokamak. FRESCO permette di calcolare i parametri geometrici, fisici ed ingegneristici di una centrale a fusione e di effettuare un’analisi economica valutando il costo di generazione. Come lavoro sono presentati prima i miglioramenti introdotti in FRESCO, come il modello del sistema di pompaggio per la camera da vuoto del reattore e l’integrazione tra il codice FRESCO ed un programma di ottimizzazione basato sugli algoritmi genetici. Sarà poi descritto lo studio condotto per capire come gli intervalli operativi di un reattore a fusione possono influire sul costo di generazione, accompagnato dall’ottimizzazione di questi intervalli per ottenere il minimo costo di generazione. Nella seconda parte della tesi è presentato nel dettaglio il codice di calcolo COMESE C++ (COsto MEdio del Sistema Elettrico): un codice realizzato durante il lavoro di tesi allo scopo di avere uno strumento per lo sviluppo di nuovi scenari energetici. In particolare scenari che possano evidenziare come la tecnologia della fusione nucleare possa fare parte del parco di generazione elettrica. Il codice di calcolo COMESE C++ utilizza i dati della domanda elettrica e della generazione di un Paese, assieme ai dati delle tecnologie e dei sistemi di accumulo, per poter simulare uno scenario energetico. Esso permette di valutare se la generazione ipotizzata riesce a soddisfare la domanda, e in quel caso calcola il costo medio di generazione dello scenario, avendo la possibilità di eseguire un’analisi stocastica basata sul metodo Monte Carlo, per tenere conto dell’incertezza sui parametri economici delle tecnologie di generazione. Il codice COMESE C++ è stato utilizzato per definire due scenari energetici europei 100% rinnovabili: uno per il Nord Europa basato sulla tecnologa di generazione eolica e uno per il Sud Europa basato sulle tecnologie di generazione fotovoltaiche. Partendo da questi scenari di riferimento sono poi stati sviluppati nuovi scenari con la tecnologia da fusione, ed è stata fatta un analisi per determinare il costo di investimento di centrali elettriche a fusione tale da rendere competitiva la tecnologia e ridurre il costo medio di generazione di uno scenario energetico.<br>In order to be able to evaluate, from an economic point of view, under which conditions fusion technology can be a key element of a future electricity generation system, adequate calculation tools are needed to simulate a fusion reactor in a simple way and calculate the cost of electricity generated. Other tools are required to simulate an energy system, composed of different power plants, and to evaluate the system cost of electricity. The thesis work begins with the presentation of the FRESCO code (Fusion REactor Simplified COst): a code developed in C ++ language with the aim to model in a simplified way a D-T fusion power plant based on the tokamak configuration. In FRESCO the power plant is studied from a technical and an economical point of view. It allows the users to calculate reactor parameters i.e. geometrical and physical dimension of the power plant, electromagnetic parameters of the machine, net electricity production, auxiliary energy needed, the operative cycle phases (especially for the pulsed configuration), and not last, the related capital cost and the cost of electricity. As part of the thesis work, the improvements introduced in FRESCO are presented first, such as the model of the reactor chamber vacuum pumping system, and the integration between the FRESCO code and an optimization program based on genetic algorithms. Then, the analysis of the effects of the duration of the operative phases in a pulsed power plant on the cost of electricity is presented. In the second part of the thesis, the COMESE code (COsto MEdio del Sistema Elettrico, Average Cost of the Electric System) is described. The code developed as a part of the doctoral research activities, is used to develop and test energy scenarios. In particular, scenarios that can show how nuclear fusion technology can be part of the electricity generation park. The COMESE C ++ calculation code uses the electricity demand and generation data of a country, together with the data of the technologies and storage systems, in order to simulate an energy scenario. It allows to evaluate if the hypothesized generation succeeds in satisfying the demand. In that case, it calculates the levelized cost of timely electricity (LCOTE) for the scenario. It also offers the possibility to perform a stochastic analysis, based on the Monte Carlo method, in order to take into account the uncertainty on the economic parameters of generation technologies. An application of the COMESE C ++ code is presented. Two fully renewable European energy scenarios, one for Northern Europe based on the wind generation technology and one for Southern Europe based on photovoltaic generation technologies, are studied and compared. Alternative scenarios including fusion technology were developed, in order to estimate which economic conditions (overnight cost) fusion power plants can be competitive and bring a benefit to the levelized cost of timely electricity of an energy scenario.

A comparison between a traditional fixed high voltage direct current energy transmission system and a mobile transmission system utilizing vanadium redox flow batteries has been conducted in this degree work.  The purpose of this comparison was to evaluate if a mobile energy transmission system could be competitive in terms of energy efficiency and cost-effectiveness for use in offshore wind power applications. A literary study was made to fully grasp the various technologies and to create empirical ground of which cost estimation methods and energy calculations could be derived. A specific scenario was designed to compare the two transmission systems with the same conditions. To perform the comparison, a model was designed and simulated in MATLAB. The results from the model showed that the flow battery system fell behind in energy efficiency with a total energy loss of 33.3 % compared to the 11.7 % of the traditional system, future efficiency estimations landed it at a more competitive 17.5 %. The techno-economic results proved that a mobile flow battery system would be up to nine times more expensive in comparison to a traditional transmission system, with the best-case scenario resulting in it being roughly two times more expensive. The main cause of this was found out to be the expensive energy subsystem, specifically the electrolyte, used in the flow battery system. Several environmental risks arise when using a flow battery system with this electrolyte as well which could harm marine life severely. In conclusion; with further development and cost reductions, a case could be made for the advantages of a truly mobile energy transmission system. Specifically, in terms of the pure flexibility and mobility of the system, allowing it to circumvent certain complications. The mobility of the system gives the possibility of selling energy where the spot prices are at their highest, providing a higher revenue potential compared to a traditional fixed system. As for now though, it is simply too expensive to be a viable solution.

Cuba’s government has set a goal to generate 24 percent of the country’s electricity from renewable sources by 2030. The country’s many sugar mills have been identified as key contributors to reach this goal as their cogeneration units have the potential to significantly increase Cuba’s electricity production from biomass by upgrading them to bioelectric plants. This study evaluates the feasibility of upgrading the cogeneration unit of George Washington sugar mill in the province of Villa Clara, Cuba. An energy balance of the proposed upgraded scheme is done to deduce its feasibility from an energy perspective. To deduce the project’s feasibility from a financial standpoint its net present value (NPV), internal rate of return (IRR), discounted payback period (DPP) and levelized cost of energy (LCOE) are calculated. The spared CO2 emissions by integrating more biopower in the Cuban electricity system are calculated from the avoided burning of diesel for electricity production. The impact on Cuba’s energy independence is quantified by calculating the avoided diesel imports. The NPV of the proposed scheme is 64.9 MUSD, the IRR is 25.6 percent which is significantly higher than the set discount rate of 6.5 percent, the DPP is 5.3 years and the LCOE is 0.0533 USD/kWh which is lower than the maximum LCOE set by AZCUBA to 0.14 USD/kWh. The avoided CO2 emissions and imported diesel are estimated to be 110,173 tonnes CO2 and 36,724 tonnes diesel each year, respectively. These indicators suggest that the upgrade of George Washington’s cogeneration unit is feasible.​<br>Kubas regering har satt som mål att generera 24 procent av landets elektricitet från förnyelsebara källor till år 2030. Landets många sockerbruk har identifierats som nyckelaktörer för att nå detta mål då sockerbrukens kraftvärmeenhet har potential att öka Kubas elproduktion från biomassa genom att uppgradera dem till bioelektriska kraftverk. Denna studie utvärderar möjligheten att uppgradera kraftvärmeenheten på sockerbruket George Washington i provinsen Villa Clara, Kuba. Först görs en energibalans på det föreslagna uppgraderade systemet för att utläsa dess genomförbarhet ur ett energiperspektiv. För att utvärdera projektets genomförbarhet ur ett finansiellt perspektiv beräknas investeringens nettonuvärde (NPV), interna avkastningsgrad (IRR), diskonterade återbetalningstid (DPP) och energiproduktionskostnad (LCOE). De undvikta CO2 utsläppen genom integrering av mer biokraft i det kubanska elsystemet beräknas från den uteblivna förbränningen av diesel för elproduktion i landet. Effekterna på Kubas energioberoende kvantifieras genom att man beräknar den minskade dieselimporten. NPV i det föreslagna uppgraderade systemet är 64,9 MUSD, IRR är 25,6 procent vilket är betydligt högre än den fastställda diskonteringsräntan på 6,5 procent, DPP är 5,3 år och LCOE är 0,0533 USD/kWh vilket är lägre än det maximala LCOE som fastställts av AZCUBA till 0,14 USD/kWh. De uteblivna CO2-utsläppen och minskningen av importerad diesel beräknas uppgå till 110 173 ton CO2 respektive 36 724 ton diesel varje år. Dessa indikatorer tyder på att uppgraderingen av George Washingtons kraftvärmeenhet är genomförbar.​

Generering av el med hjälp av solen står idag för en väldigt liten andel av Sveriges totala genereringav el. För att komma upp till en högre nivå krävs inte enorma solcellsparker över hela Sverige, utan tvärtom skulle det kunna gå att använda redan befintliga tak. Det förhållandet är bara ett av flera som påvisar behovet av större kunskapsspridning om dagens energisystem och solcellsteknik. Det finns också ett behov av ökad kunskap om karaktäristiska svenska hus- och taktyper och om vad som är möjligt att göra med varierande slag av solcellsteknik, för att konvertera de olika hustypernas tak till en liten energikälla. Ren solenergi kan inte ensam konkurrera ut fossila bränslen, men det finns god potential för en mycket högre andel av den än vad som är installerat idag. Wallenstam AB är ett energimedvetet fastighetsbolag som bland annat är verksamma i Göteborg. Deras intresse av förnybar energi och av att ersätta fossilt bränsle med mer miljövänlig teknik gav upphov till ett samarbete mellan författaren och Wallenstam AB. Arbetets första del syftar till att inbringa mer och fördjupad kunskap inom ämnet solceller och solcellsanläggningar. Syftet med arbetets andra del är att undersöka vilka möjligheter och hinder det finns med solcellsinstallationer på några olika typiska svenska fastighetstyper. En projektering genomförs på tre olika fastighetstyper i Göteborgsområdet; en industri/kontorslokal, ett modernt flerbostadshus och en fastighet i centrala Göteborg med både bostäder och kommersiell verksamhet. Målet är att utifrån varje fastighets förutsättningar finna den eller de mest lämpade solcellspanelerna för respektive fastighet med avseende på ekonomisk fördelaktighet, estetik samt i vad som är tekniskt möjligt utifrån exempelvis tidigare installerade energisystem. Rapporten och dess resultat är skapat utifrån litteraturstudier, platsbesök på fastigheter, mätningar på ritningar och satellitkartor, beräkningar för hand, samt modellering i PVsyst. Fortlöpande diskussion med personer inom solenergibranschen har också hållits. För att beräkna respektive anläggnings elproduktionskostnad samt för känslighetsanalyser används en webbaserad beräkningsapplikation, tillhörande rapporten El från nya och framtida anläggningar 2014. Huvudresultat är att endast två av de tekniskt möjliga anläggningarna har en elproduktionskostnad som är i närheten av det jämförande elpriset på 0,75 kr/kWh. Det är de polykristallina solcellsanläggningarna på Kvillebäcken 3:1 och Mölnlycke 1:1. Beräkningarna visar på att anläggningarna med polykristallina solcellspaneler på Kvillebäcken 3:1 och Mölnlycke Fabriker 1:1 är riktigt konkurrenskraftiga om kalkylräntan sänks från 4 % till 2 %, eller om investeringskostnaderna minskar med 15 %. På fastigheten Inom Vallgraven 26:8 ligger samtliga elproduktionskostnader över en krona per kilowattimme, men installation av solcellsteknik på en sådan central byggnad skulle kunna ha ett marknadsföringsvärde.<br>Generation of electricity by use of solar irradiation is today a very small part of the total electricity generation in Sweden. It is not necessary to build a great amount of solar parks all over Sweden to reach a higher level, it could instead be possible by using already existing rooftops. That is one of the situations that indicates the need of a greater knowledge dissemination, about today’s energysystem and the technology of photovoltaics. It also exists a demand of knowledge about characteristic Swedish houses and rooftops. To convert the different kinds of rooftops to small powersources, there is also a demand of knowledge about installations that is possible to do with different kinds of photovoltaics. Although, solar power alone cannot compete with fossil fuels, but it should have a good possibility to reach a much higher level than what exists today. Wallenstam AB is anenergy-conscious company within the real estate business in Gothenburg. Their interests in renewable energy and their ambition to replace fossil fuel with more environment-friendly technology facilitated this cooperation.The first part of the report aims to get more and deeper knowledge about the subject photovoltaics and solar plants. The second part of the report aims to investigate what possibilities and impediments there is with photovoltaic installations at different kinds of typical Swedish houses. A planning work is made at three different types of buildings in the area of Gothenburg. One at an industry/office space, one at a modern apartment block and one at a central building in Gothenburg that has both apartments and commercialized activity. The goal is to find the most suitable photovoltaic installation to each of the three buildings, based on economic advantageousness, appearance and esthetic, and the possibilities with the technology of earlier installed energy systems.The report and the result are formed on the basis of literature studies, site visits at the buildings, measurements at drawings and satellite maps, calculations by hand and modelling in the software PVsyst. Many discussions with people in the solar energy industry were also held. To calculate the Levelized Cost Of Energy (LCOE) and to perform the sensitivity analysis, a web-based calculator was used. The web-based calculator belongs to the report El från nya och framtida anläggningar 2014. The main result shows that only two of the possible photovoltaic installations gets a LCOE that is competitive relative the comparative electricity price at 0,75 SEK/kWh. Installations with polycrystalline solar panels at Kvillebäcken 3:1 and Mölnlycke 1:1. The result also shows that the two installations with polycrystalline solar panels at Kvillebäcken 3:1 and Mölnlycke Fabriker is really competitive if the capital interest rate is reduced from 4 % to 2 %, or if the investment cost isreduced by 15 %. At the property Inom Vallgraven 26:8, the LCOE for all possible installations are over one Swedish krona per kilowatt hour, but an installation with solar panels at a central building like that could have a marketing value. It would also show Wallenstams standpoint for renewable energy, new technology and a sustainable energy system.

Det finns en ökande efterfrågan på förnybar elproduktion och effektiva lösningar att kombinera med denna. Ett flertal tidigare arbeten har undersökt energilagringssystem (ESS) och dess lönsamhet i olika tillämpningar. Det råder en osäkerhet kring lönsamheten hos ESS för ökad självkonsumtion i Sverige. Detta arbete undersöker lönsamheten hos batterilagringssystem (BESS) som används i syftet att öka självkonsumtionen för aktörer med solceller i den svenska bostadssektorn. En modell konstruerades baserat på Levelized Cost of Storage (LCOS), och indata till modellen varierades för olika scenarier. Resultaten visade att BESS kostnader i dagsläget är för höga, med LCOS mellan 1,68 kr/kWh och 3,56 kr/kWh beroende på aktör och indata. För lönsamhet krävs reduktion av LCOS mellan 55% och 85%. Vidare undersöker arbetet vilka variabler som har störst påverkan på BESS lönsamhet. En känslighetsanalys genomfördes, där CAPEX, antalet battericykler per år, WACC och skattereduktioner vid elhandel identifierades som viktiga variabler. Arbetet visade att det antagligen krävs en kombination av högre elpriser och reducerade investeringskostnader för att motivera en investering i BESS. Utöver ökad självkonsumtion behövs ytterligare värden för att motivera en investering i BESS inom en snar framtid.<br>There is a growing demand for renewable power generation and efficient solutions to combine with renewables. Previous works have explored energy storage systems (ESS) and their profitability in various applications. There is an uncertainty about the profitability of ESS for increased self-consumption in Sweden. This thesis explores the profitability of battery energy storage systems (BESS) used for increased self-consumption for stakeholders with solar photovoltaics in the Swedish residential sector. A model based on levelized cost of storage (LCOS) was constructed, and varying input values were used for different scenarios. The results showed that the current cost of BESS is too high, with LCOS ranging between 1,68 SEK/kWh and 3,56 SEK/kWh depending on the stakeholder as well as input data. For profitability, a reduction of LCOS between 55% and 85% is needed. Furthermore, this thesis explores which variables have the greatest effect on a BESS’s profitability. A sensitivity analysis was conducted, where CAPEX, the number of battery cycles per year, WACC and tax reductions linked to electricity trading were identified as important variables. This thesis concluded that higher electricity prices in combination with reduced investment costs is needed to justify an investment in BESS. Besides increased self-consumption, other values are needed to justify an investment in a BESS in the near future.

L'accesso ininterrotto all'energia elettrica è diventato il bisogno fondamentale del mondo di oggi. Le parti rurali di molti paesi ancora oggi non hanno accesso all'energia elettrica o hanno accesso a reti di distribuzione deboli con infrastrutture del sistema di trasmissione e distribuzione inadeguate. Tuttavia, nei paesi dove c'è un'abbondanza di risorse rinnovabili come la radiazione solare, la risorsa eolica e corsi d’acqua, l'accesso all'elettricità può essere gestito dalla generazione di energia distribuita. Considerando il fatto che le fonti di energia rinnovabile sono intermittenti in natura si possono integrare ad esse sistemi di stoccaggio a batteria e altri serbatoi, per esempio le fonti di energia da biomassa, per garantire l'accesso continuo all'elettricità e la sicurezza energetica. In questo elaborato sono stati descritti i principali impianti basati su fonte di energia rinnovabile, i metodi di ottimizzazione, i criteri di valutazione ed infine è stato preso in considerazione come caso di studio l’implementazione di un nuovo sistema stand-alone per sei differenti zone rurali dell’India impossibilitate a connettersi alla rete centralizzata. Infine i risultati ottenuti dai processi di simulazione e ottimizzazione del software HOMER sono stati confrontati con quelli del sistema attualmente in uso nelle sei zone climatiche. Dai risultati ottenuti si evince che l’implementazione del nuovo sistema ha portato alla riduzione degli indici LCOE (Levelized cost of energy) ed NPC (Net present cost), ma ha anche diminuito le emissioni di gas nocivi, migliorato la frazione rinnovabile RF ed ha creato nuova occupazione.

With environmental concerns and energy needs increasing, many regions in the world are promoting renewable energy technologies making use of various policy instruments. Although today the PV systems price is decreasing, which gives it a competitive edge; we see the technology still being dependent on policy instruments for its dissemination.   The aim of this study is to research on whether or not a solar PV system is economically viable under certain circumstances. The study analyzes this by performing a cost beneficial analysis for the lifetime of the solar PV system making use of a discounted savings model. The systems being considered in this study are from California and Germany as these regions are leading in solar PV dissemination in their respective regions. The policies that are aiding the deployment of solar PV technologies are varied and thus this study compares benefits from different policy instrument for a residential customer investing in a solar PV system.   The research objectives in this study are pursued making use of major concepts such as Grid Parity, Levelized Cost of Electricity and financial methods such as discounting.  Further, to understand how the different independent variables such as retail electricity prices, PV system pricing, WACC, self-consumption rate and storage availability are having an impact and how the results change with variation in these variables, a sensitivity analysis is conducted.   The results obtained in this study show that a solar PV system installed in California and Germany both make net benefits over their lifetime. When compared, the Californian solar PV system under the Net Energy Metering policy is making more net economic benefits in the range of $ 40,351 in Eureka and $53,510 in San Francisco; when compared to the German solar PV systems under the Feed in Tariff ranging $4,465 in Berlin and $11,769 in Munich. Furthermore the Californian solar PV systems still prove to be more beneficial even when compared to the German solar PV systems under the self-consumption law of the Feed in Tariff ranging $ 6,443 in Berlin and $ 13,141 in Munich.  But when the self-consumption rate is increased in the German case, it is noted that the associated benefits increase.   The study at hand thus results in the California Net Energy Meter policy instrument proving to be more beneficial to a residential customer than the German Feed in tariff with and without self-consumption. Another important finding made in this study is that despite the German solar PV system making lesser benefits than the Californian ones, they attain Grid Parity before the ones in California.

Electricity availability and stability have a great contributory share of industrialization growth rate, poverty statistics, unemployment, foreign investors' participation, medium and small scale encouragement, crime and mortality rates recorded in any country. Nigeria as a country has been challenged with unstable and unreliable power supply. There are many problems associated with electricity production in Nigeria. Such problems are recorded in the generation, transmission and distribution facets of electricity production. With a multi-faceted problem, this document has been developed to deal with the economic aspect of power generation in Nigeria. Out of numerous technologies that are used in power generation, Nigerian predominantly sources its electricity supply from gas power plants and hydropower systems located within the country. Unfortunately, the Nigeria hydropower has been challenged with hydrological shortfalls. The gas power plant which is now conventional is being challenged with the developing gas technology around the globe. This development has adversely affected the cost of gas and subsequently the cost of power production using gas power plants. As a result of hydrological limitations on Nigerian hydropower dams, effect of gas price on cost of energy produced and diversifying gas technology, harnessing electric energy from Inga falls of River Congo was considered as an economic choice of power production in Nigeria. The choice of power production adopted in this document was made from an economic viability studies carried out between Nigerian gas power plants and hydropower production from the River Congo. The choice of technology employed for harnessing electric energy is largely dependent on the economic factors that go with the development. While some of these technologies go with large initial capital investment some are challenged with geometric increase of running cost. As applied in this work, the Net Present Value, Internal Rate of Return, Levelized Cost of Energy and Cash Flow Trend Analysis are suitable tools to determine choice of power plant. These tools were integrated and developed as an NILC model. In the analysis presented in this dissertation, the economic viability of the two power plants selected was determined with the use of the Net Present Value, Internal Rate of Return, Levelized Cost of Energy and Cash Flow Trend Analysis (NILC) model. The model was used to measure the economic viability quantities of the two power plants selected for economic comparison. After the completion of economic comparative analysis, hydropower production from the River Congo was concluded to be a better choice of power production compared to the conventional gas power plant option in Nigeria.<br>Thesis (M.Ing. (Development and Management Engineering))--North-West University, Potchefstroom Campus, 2009.

The research activities described in the present work aims to develop a pendulum converter (PeWEC: Pendulum Wave Energy Converter) for the Mediterranean Sea, where waves are shorter, thus with a higher frequency. In particular, the Pantelleria Island site wave climate is assumed as reference. The research activities started from the preliminary investigation of the working principle validity in the case of the Mediterranean Sea wave characteristics, taking into account a 1:45 scale prototype. The numerical model reliability and the success of experimental tests motivated the design and development of a 1:12 scaled device, useful for a deeper investigation of the technology capabilities and performances. Globally, the technology readiness level (TRL) was increased from 1 to 4. Important effort were focused in the development of a reliable model-based design and optimization methodology for the investigation of a full scale configuration. The latter was widely used to identify a preliminary full scale configuration and to assess the economic viability of the PeWEC technology in the Mediterranean Sea context. Results were benchmarked against the ISWEC pilot plant, deployed in 2015, in Pantelleria Island. One of the major outcomes of this analysis is a detailed overview of the advantages and drawbacks of an active (ISWEC) and a passive (PeWEC) technology, together with some guidelines for the improvement of this technology.

The performance of parabolic trough based solar power plants over the last 25 years has proven that this technology is an excellent alternative for the commercial power industry. Compared to conventional power plants, parabolic trough solar power plants produce significantly lower levels of carbon dioxide, although additional research is required to bring the cost of concentrator solar plants to a competitive level. The cost reduction is focused on three areas: thermodynamic efficiency improvements by research and development, scaling up of the unit size, and mass production of the equipment. The optimum design, performance simulation and cost analysis of the parabolic trough solar plants are essential for the successful implementation of this technology. A detailed solar power plant simulation and analysis of its components is needed for the design of parabolic trough solar systems which is the subject of this research. Preliminary analysis was carried out by complex models of the solar field components. These components were then integrated into the system whose performance is simulated to emulate real operating conditions. Sensitivity analysis was conducted to get the optimum conditions and minimum levelized cost of electricity (LCOE). A simplified methodology was then developed based on correlations obtained from the detailed component simulations. A comprehensive numerical simulation of a parabolic trough solar power plant was developed, focusing primarily on obtaining a preliminary optimum design through the simplified methodology developed in this research. The proposed methodology is used to obtain optimum parameters and conditions such as: solar field size, operating conditions, parasitic losses, initial investment and LCOE. The methodology is also used to evaluate different scenarios and conditions of operation. The new methodology was implemented for a 50 MWe parabolic trough solar power plant for two cities: Tampa and Daggett. The results obtained for the proposed methodology were compared to another physical model (System Advisor Model, SAM) and a good agreement was achieved, thus showing that this methodology is suitable for any location.

Africa still has the lowest electrification rates in the world with over 600 million people estimated to be living without access to electricity. What makes the challenge even greater for Africa is that the continent is so sparsely populated that building grid infrastructure is not viable in many cases. However, “pay-as-you-go” solar home systems have provided the continent with the opportunity to correct its electrification deficit. These innovations are not new and many of the costs of operating these systems have reached grid parity when one considers the Levelized Cost of Energy Model. However, these projects still fail to meet institutional investors' bankability criteria. The aim of this study is to try and understand whether solar home systems provide the investor with an opportunity to make a larger risk-adjusted return versus existing grid-based power station projects being considered on the continent. This study uses Ghana's recently built Kpone power station as a case study to complete this analysis. The study also seeks to assess what viability criteria is employed by a broad base of investors if they were to consider funding off-grid power. The study makes use of the Net Present Value model to compare the returns for Kpone and Zola Electric's Infinity solar home system. The study also conducts inductive qualitative analysis to try and ascertain what criteria is assessed for project viability and then builds a conceptual framework for assessing future projects. The study found that Kpone provided a better risk-adjusted return to that of Zola Electric's solar home system, largely because of Kpone's project finance structure reducing the risk of the investment. Our findings also show that investment ticket size, company track record and management track record are among the most highly considered criteria for investments into off-grid companies.

Submitted by Leonardo Madeira (leoribmad@hotmail.com) on 2017-05-24T20:49:04Z No. of bitstreams: 1 Dissertação_Leonardo_Madeira v4 - revEdson VF IMPRESSA.pdf: 497221 bytes, checksum: edd8c6618d1bbcf4135abc1f146a6980 (MD5)<br>Approved for entry into archive by GILSON ROCHA MIRANDA (gilson.miranda@fgv.br) on 2017-05-29T14:55:52Z (GMT) No. of bitstreams: 1 Dissertação_Leonardo_Madeira v4 - revEdson VF IMPRESSA.pdf: 497221 bytes, checksum: edd8c6618d1bbcf4135abc1f146a6980 (MD5)<br>Made available in DSpace on 2017-05-30T12:49:39Z (GMT). No. of bitstreams: 1 Dissertação_Leonardo_Madeira v4 - revEdson VF IMPRESSA.pdf: 497221 bytes, checksum: edd8c6618d1bbcf4135abc1f146a6980 (MD5) Previous issue date: 2017-05-05<br>This study seeks to evaluate the financial differences of power generation between a huge array of technologies, splitting them in Dispatchable and Intermittent. Tacitly accepted all over the world as a financial tool to compare any kind of technology, the Levelized Cost of Energy, LCOE, might originate inappropriate conclusions assumptions once it considers the life cycle of some power generation source with a homogeneous generation profile. Containing a huge framework of data source and a simple metric, the study puts the Joskow (2011) study into Brazil electric sector context.<br>Este trabalho busca avaliar as diferenças financeiras de geração de energia entre uma grande gama de tecnologias, separando-as em Despacháveis e Intermitentes. Aceito na grande maioria dos países como instrumento de comparação financeira entre fontes de geração, o Custo Nivelado de Energia (LCOE) também é amplamente utilizado no Brasil. Com base em Joskow (2011) e em dados para empreendimentos brasileiros, mostra-se que esta métrica, o LCOE, pode gerar conclusões equivocadas devido ao fato de considerar, em um ciclo de vida dos projetos, um perfil de geração homogêneo, o que não é compatível com as características de despachabilidade das diversas fontes.

Coordenação de Aperfeiçoamento de Pessoal de Nível Superior<br>In photovoltaic systems, the lowest energy cost is not always achieved by an inverter with minimized cost or maximized efficiency. It is important to adopt methodologies that optimize the balance between system losses and costs. The Levelized Cost of Electricity minimization methodology, presented in literature, obtains an optimized inverter design, but needs variables like discount rate and maintenance costs. This study proposes a methodology for design and comparison of photovoltaic inverters that is simpler and is based on the adoption of a cost per Watt reference. It minimizes the energy cost considering the photovoltaic initial system cost and design specifications. This methodology is presented in detail, including an inverter design example that analyses losses and cost of all components, and also the irradiance of the photovoltaic installation place. Experimental results are presented to validate the proposed methodology.<br>Em sistemas fotovoltaicos, o menor custo da energia gerada nem sempre é obtido com inversores de custo minimizado ou eficiência maximizada. Para o custo da energia seja minimizado, é importante empregar metodologias de projeto que otimizem o compromisso entre perdas e custos. A metodologia de minimização do custo nivelado da eletricidade, a mais difundida na literatura, permite obter um projeto otimizado do inversor, mas necessita de variáveis como taxa de desconto e custos de manutenção do sistema fotovoltaico. Este trabalho propõe uma metodologia para projeto e comparação de inversores fotovoltaicos mais simples, baseada na adoção de um custo por Watt de referência. Essa metodologia objetiva reduzir o custo da energia produzida considerando apenas o custo inicial do sistema fotovoltaico e as restrições associadas às especificações de projeto. A metodologia proposta é apresentada em detalhes, incluindo um exemplo de projeto de inversor que analisa as perdas e custos dos componentes, além do perfil de irradiação do local de instalação do sistema fotovoltaico. Resultados experimentais são apresentados para validação da metodologia proposta.

<div>The manufacturing cost of solar cells along with their efficiency and reliability define the levelized cost of electricity (LCOE). One needs to reduce LCOE to make solar cells cost competitive compared to other sources of electricity. After a sustained decrease since 2001 the manufacturing cost of the dominant photovoltaic technology based on c-Si solar cells has recently reached a plateau. Further reduction in LCOE is only possible by increasing the efficiency and/or reliability of c-Si cells. Among alternate technologies, organic photovoltaics (OPV) has reduced manufacturing cost, but they do not offer any LCOE gain because their lifetime and efficiency are significantly lower than c-Si. Recently, perovskite solar cells have showed promising results in terms of both cost and efficiency, but their reliability/stability is still a concern and the physical origin of the efficiency gain is not fully understood.</div><div><br></div>In this work, we have collaborated with scientists industry and academia to explain the origin of the increased cell efficiency of bulk solution-processed perovskite cells. We also explored the possibility of enhancing the efficiency of the c-Si and perovskite cells by using them in a tandem configuration. To improve the intrinsic reliability, we have investigated 2D-perovskite cells with slightly lower efficiency but longer lifetime. We interpreted the behavior of the 2D-perovskite cells using randomly stacked quantum wells in the absorber region. We studied the reliability issues of c-Si modules and correlated series resistance of the modules directly to the solder bond failure. We also found out that finger thinning of the contacts at cell level manifests as a fake shunt resistance but is distinguishable from real shunt resistance by exploring the reverse bias or efficiency vs. irradiance. Then we proposed a physics-based model to predict the energy yield and lifetime of a module that suffers from solder bond failure using real field data by considering the statistical nature of the failure at module level. This model is part of a more comprehensive model that can predict the lifetime of a module that suffers from more degradation mechanisms such as yellowing, potential induced degradation, corrosion, soiling, delamination, etc. simultaneously. This method is called forward modeling since we start from environmental data and initial information of the module, and then predict the lifetime and time-dependent energy yield of a solar cell technology. As the future work, we will use our experience in forward modeling to deconvolve the reliability issues of a module that is fielded since each mechanism has a different electrical signature. Then by calibrating the forward model, we can predict the remaining lifetime of the fielded module. This work opens new pathways to achieve 2030 Sunshot goals of LCOE below 3c/kWh by predicting the lifetime that the product can be guaranteed, helping financial institutions regarding the risk of their investment, or national laboratories to redefine the qualification and reliability protocols.<br>

The cost of energy and national power utility Eskom, is currently under heated debate after the cost of electricity has more than doubled over the past three years, with another five annual increases of 8% approved by the National Energy Regulator of South Africa. The state owned utility has a monopoly on electricity production in South Africa having sole ownership over the transmission and distribution of electricity. Eskom produces 95% of South Africa’s electricity, predominantly from coal fired power stations, which is one of the leading causes why the country is one of the highest carbon dioxide emitters in the world. The question of independent power production and the use of our abundant renewable resources for electricity generation have been at the forefront with critics arguing against the heavy increases absorbed by industry and consumers. Although the renewable energy space is a well discussed topic, it is not well scientifically documented from an economic standpoint. The primary objective is to determine if renewable energy is price competitive with Eskom, or non-renewable electricity generation, by not only looking at the current scenario but also the future price projection and point where renewable energy is on parity with the grid price. For this purpose the Levelised Cost of Energy calculation method was used. Four different measuring instruments were produced for each technology namely, biogas, biomass, solar and wind and a financial model developed to determine the levelised cost, taking into consideration more complex financial structures, tax incentives, revenues and costs associated with by-products. From the literature it is clear that wind and solar, on a large scale, are competitive with the levelised cost of Eskom’s new build coal power plants and particularly wind, is lower than the grid price in 2017. The empirical study focused on a smaller scale of 1 to 5 megawatt and concluded that the levelised cost of wind energy is lower than Medupi coal fired power plant, currently under construction. The study also determined that biogas and biomass, under certain conditions relating to feedstock costs, are able to compete with Medupi and offer real and sustainable benefits in long-term energy supply.<br>MBA, North-West University, Potchefstroom Campus, 2015

Renewable energy sources have become very popular in the last years in electricity generation thanks to the technological developments, the increase in the price of fossil fuels and the environmental concerns. These factors have also prompted Turkey to utilize her very rich renewable energy sources to meet the demand increasing around 7% annually. In this study, solar and wind energy potential of Turkey is analyzed in terms of its economics to find out whether these sources are real alternatives to fossil fuels in electricity generation. Before this analysis, wind and solar energy technologies and costs and wind and solar energy potential of Turkey are discussed. Then, models are set up for five technologies which are onshore wind, offshore wind, solar PV, solar trough and solar tower technologies models to calculate cash flows which are used to calculate payback, NPV, IRR, LCE and shut-down price to conduct economic analysis. In addition to base case scenario, uncertainty analysis is done for the most promising technologies which are onshore wind and solar tower technologies by evaluating NPV and LCE under uncertain environment. The main finding of these analyses is that only onshore wind projects are attractive in Turkey; none of other technologies is attractive. However, with a minor increase in the regulated price for solar thermal electricity, tower plant projects will also be attractive.<br>text

abstract: An eco-industrial park (EIP) is an industrial ecosystem in which a group of co-located firms are involved in collective resource optimization with each other and with the local community through physical exchanges of energy, water, materials, byproducts and services - referenced in the industrial ecology literature as "industrial symbiosis". EIPs, when compared with standard industrial resource sharing networks, prove to be of greater public advantage as they offer improved environmental and economic benefits, and higher operational efficiencies both upstream and downstream in their supply chain. Although there have been many attempts to adapt EIP methodology to existing industrial sharing networks, most of them have failed for various factors: geographic restrictions by governmental organizations on use of technology, cost of technology, the inability of industries to effectively communicate their upstream and downstream resource usage, and to diminishing natural resources such as water, land and non-renewable energy (NRE) sources for energy production. This paper presents a feasibility study conducted to evaluate the comparative environmental, economic, and geographic impacts arising from the use of renewable energy (RE) and NRE to power EIPs. Life Cycle Assessment (LCA) methodology, which is used in a variety of sectors to evaluate the environmental merits and demerits of different kinds of products and processes, was employed for comparison between these two energy production methods based on factors such as greenhouse gas emission, acidification potential, eutrophication potential, human toxicity potential, fresh water usage and land usage. To complement the environmental LCA analysis, levelized cost of electricity was used to evaluate the economic impact. This model was analyzed for two different geographic locations; United States and Europe, for 12 different energy production technologies. The outcome of this study points out the environmental, economic and geographic superiority of one energy source over the other, including the total carbon dioxide equivalent emissions, which can then be related to the total number of carbon credits that can be earned or used to mitigate the overall carbon emission and move closer towards a net zero carbon footprint goal thus making the EIPs truly sustainable.<br>Dissertation/Thesis<br>LCOE calculation charts<br>Gabi Life-cycle analysis<br>Masters Thesis Mechanical Engineering 2014

Today’s carbon constrained world with its increasing demand for cheap energy and a fossil fuel intensive fleet of power producers is making carbon capture and storage (CCS) desirable. Several CCS technologies are under investigation by various research and development groups globally. One of the more promising technologies is oxy-fuel combustion, since it produces a CO2 rich flue gas which requires minor processing to meet storage condition requirements. In this study the economics of an advanced super critical oxy-coal power plant burning lignite, simulated in-house was assessed. A robust and user-friendly financial tool box has been developed with commonly acceptable default parameter settings. Capital, operation and maintenance costs were estimated along with corresponding levelized cost of electricity and CO2 avoidance costs calculated using the detailed financial model developed. A levelized cost of electricity of 131 $/MWhrnet along with a levelized CO2 avoidance cost of 64 $/tonne was estimated for an ASC oxy-coal power plant with CO2 capture. Also a levelized cost of electricity of 83 $/MWhrnet was estimated for an ASC air-fired coal power plant without CO2 capture capabilities as the base plant. The price of electricity was observed to increase from 83 $/MWhrnet to 131 $/MWhrnet translating into a 57% increase. The sensitivity of the overall economics of the process was assessed to several parameters. The overall economics was found sensitive to the choice chemical engineering plant cost index (CEPCI), capacity factor, size of power plant, debt ratio, fuel price, interest rate, and construction duration.

This thesis holistically examines the potential for tidal stream turbine (TST) integration to displace diesel generated electricity in remote coastal First Nations communities within the Marine Plan Partnership for the North Pacific Coast region of British Columbia. This thesis utilizes a combination of spatial analysis (GIS Multi-Criteria Decision Analysis) to identify sites; stakeholder engagement to assess TST suitability, bridge knowledge gaps, and understand desired characteristics of community energy systems; and Levelized Cost of Energy (LCOE) analyses for existing diesel and externality included scenarios along with potential TST costs in a candidate community. Results illustrate the need for information within these communities, from resource quantification to characteristics of renewable energy technologies and system feasibility; self-sufficiency as being the primary transition driver; and funding/human resource capacity as being substantial barriers. Within the study region ≈89.8 km2 of feasible resource was identified, with ≈22 km2 of potentially suitable tidal resource in proximity to nine communities. The COVID-19 pandemic resulted in difficulties contacting and arranging interviews with the most suitable communities. Driven by the holistic research mandate requiring community stakeholder engagement to occur in tandem with the economic analyses, Queen Charlotte Village and Skidegate Landing on Haida Gwaii were chosen as the candidate communities, despite not being the most suitable identified communities. The community interviews revealed TSTs as being an acceptable renewable energy technology. Furthermore, the identified site in Skidegate Inlet (SI) was found to have favourable Marine Spatial Planning (MSP) for TST development. Existing diesel generation carries a LCOE of $0.63/kWh, being $0.08-0.14 more per kWh than the literature cited LCOE range for TSTs. The LCOE for CO2 equivalent externalities at current carbon tax prices was found to be an additional $0.02/kWh. Despite having a technically viable peak spring current speed, the SI site was financially unviable for 284 kW of rated capacity across all diesel LCOE scenarios driven by capacity factor (1.62%), high cabling costs (approximately one third of capital costs), and outdated data/assumptions within the Natural Resources Canada Tidal Project Cost Estimation tool used in the tidal LCOE calculations. This work contributes to the progression of tidal energy development on BCs coast along with demonstrating the utility of holistic assessment frameworks for RETs across environmental, social, and economic considerations. The results of this thesis can inform existing MSP efforts in the Marine Plan Partnership for the North Pacific region and the framework developed can be built upon and altered for global use in pursuit of sustainable energy transitions.<br>Graduate

This study centered on a novel thermoelectric generator (TEG) integrated into the built environment. Designed by Watts Thermoelectric LLC, the TEG is essentially a novel assembly of thermoelectric modules whose required temperature differential is supplied by hot and cold streams of water flowing through the TEG. Per its recommended operating conditions, the TEG nominally generates 83 Watts of electrical power. In its default configuration in the built environment, solar-thermal energy serves as the TEG’s hot stream source and geothermal energy serves as its cold stream source. Two systems-level, thermodynamic analyses were performed, which were based on the TEG’s upcoming characterization testing, scheduled to occur later in 2011 in Detroit, Michigan. The first analysis considered the TEG coupled with a solar collector system. A numerical model of the coupled system was constructed in order to estimate the system’s annual energetic performance. It was determined numerically that over the course of a sample year, the solar collector system could deliver 39.73 megawatt-hours (MWh) of thermal energy to the TEG. The TEG converted that thermal energy into a net of 266.5 kilowatt-hours of electricity in that year. The second analysis focused on the TEG itself during operation with the purpose of providing a preliminary thermodynamic characterization of the TEG. Using experimental data, this analysis found the TEG’s operating efficiency to be 1.72%. Next, the annual emissions that would be avoided by implementing the zero-emission TEG were considered. The emission factor of Michigan’s electric grid, RFCM, was calculated to be 0.830 tons of carbon dioxide-equivalent (CO2e) per MWh, and with the TEG’s annual energy output, it was concluded that 0.221 tons CO2e would be avoided each year with the TEG. It is important to note that the TEG can be linearly scaled up by including additional modules. Thus, these benefits can be multiplied through the incorporation of more TEG units. Finally, the levelized cost of electricity (LCOE) of the TEG integrated into the built environment with the solar-thermal hot source and passive ground-based cold source was considered. The LCOE of the system was estimated to be approximately $8,404/MWh, which is substantially greater than current generation technologies. Note that this calculation was based on one particular configuration with a particular and narrow set of assumptions, and is not intended to be a general conclusion about TEG systems overall. It was concluded that while solar-thermal energy systems can sustain the TEG, they are capital-intensive and therefore not economically suitable for the TEG given the assumptions of this analysis. In the end, because of the large costs associated with the solar-thermal system, waste heat recovery is proposed as a potentially more cost-effective provider of the TEG’s hot stream source.<br>text

There has recently been an increased interest in hydrogen, both as a solution for seasonal energy storage but also for implementations in various industries and as fuel for vehicles. The transition to a society less dependent on fossil fuels highlights the need for new solutions where hydrogen is predicted to play a key role. This project aims to investigate technical and economic outcomes of different strategies for production and storage of hydrogen based on hydrogen demand and source of electricity. This is done by simulating the operation of different systems over a year, mapping the storage level, the source of electricity, and calculating the levelized cost of hydrogen (LCOH). The study examines two main cases. The first case is a system integrated with offshore wind power for production of hydrogen to fuel the operations in the industrial port Gävle Hamn. The second case examines a system for independent refueling stations where two locations with different electricity prices and traffic flows are analyzed. Factors such as demand, electricity prices, and component costs are investigated through simulating cases as well as a sensitivity analysis. Future potential sources of income are also analyzed and discussed. The results show that using an alkaline electrolyzer (AEL) achieves the lowest LCOH while PEM electrolyzer is more flexible in its operation which enables the system to utilize more electricity from the offshore wind power. When the cost of wind electricity exceeds the average electricity price on the grid, a higher share of wind electricity relative to electricity from the grid being utilized in the production results in a higher LCOH. The optimal design of the storage depends on the demand, where using vessels above ground is the most beneficial option for smaller systems and larger systems benefit financially from using a lined rock cavern (LRC). Hence, the optimal design of a system depends on the demand, electricity source, and ultimately on the purpose of the system. The results show great potential for future implementation of hydrogen systems integrated with wind power. Considering the increased share of wind electricity in the energy system and the expected growth of the hydrogen market, these are results worth acknowledging in future projects.