Reliable, affordable access to electrical power is a requirement for almost all aspects of developed societies. Challenges associated with reducing carbon emissions has led to growing interest in nuclear-renewable hybrid energy systems (N-RHES). Much work has already been done in suggesting and analyzing various N-RHES using a variety of optimization techniques and assumptions. This work builds upon previous techniques for simultaneous combined design and dispatch optimization (CDDO) for hybrid energy systems (HES). The first contribution of this work is the development and application of sensitivity analysis tailored to the combined design and dispatch optimization problem. This sensitivity analysis cover uncertainty in design parameters, time series and dispatch horizon lengths. The result is a deeper insight into which sources of uncertainty are most important to account for and how the uncertainty around these sources can be quantified. The second contribution of this work is a novel multi-scale optimization algorithm for the combined HES design and dispatch optimization. This algorithm supports optimization of nonlinear models over very long-time horizons. This method is based on a multi-dimensional distribution of the optimal capacities for a system as determined by a large number of combined design and dispatch optimization problems each covering a subset of the complete time horizon. This method shows good agreement with the direct solution to multiple example systems and is then used to solve a problem with a dispatch horizon length 112.5 times longer than is solvable directly. The third contribution of this work is the application of the novel multi-scale method to three HES. Each of the application systems is used to demonstrate the strengths, validation and applicability of the developed algorithm to a wide range of possible HES/NHES designs.

Adaptive software becomes more and more important as computing is increasingly context-dependent. Runtime adaptability can be achieved by dynamically selecting and applying context-specific code. Role-oriented programming has been proposed as a paradigm to enable runtime adaptive software by design. Roles change the objects’ behavior at runtime and thus allow adapting the software to a given context. However, this increased variability and expressiveness has a direct impact on performance and memory consumption. We found a high overhead in the steady-state performance of executing compositions of adaptations. This paper presents a new approach to use run-time information to construct a dispatch plan that can be executed efficiently by the JVM. The concept of late binding is extended to dynamic function compositions. We evaluated the implementation with a benchmark for role-oriented programming languages leveraging context-dependent role semantics achieving a mean speedup of 2.79× over the regular implementation.

This project proposes a hybrid system for hydrogen production, which includes a connection to the grid, a source of renewable energies, namely photovoltaic (PV), a Battery Energy Storage System (BESS), and a PEM (Proton Exchange Membrane) electrolyzer modelled from commercial technologies available. A dispatch optimization algorithm will evaluate the price of the energy inputs and the power available from the solar PV system and will decide the operation on an hourly basis to maximize net profit in a year timeframe. This algorithm will have a daily hydrogen production constraint. When the price of electricity is low, the energy is used for two purposes. First, to electrolyze water in the electrolyzer system and second, to store it in the BESS. The stored energy will be used to produce hydrogen when electricity prices are high or inject back to the grid when it is economically sound to do. The PV input will be used to alleviate the need for energy from the grid, therefore, it can be used to feed the electrolyzer or to store in the batteries or to inject back to the grid. In this study, a multi-energy system is modelled and its operation strategy for green hydrogen production is analyzed. Four topological scenarios were chosen, which include Scenario 1 (Grid + PEM), Scenario 2 (Scenario 1 + BESS), Scenario 3 (Scenario 2 + Grid injection), and Scenario 4 (Scenario 3 + Solar PV). These scenarios facilitate a comprehensive assessment of the system's economic and environmental performance contingent on the installed assets. In addition to the scenario analysis, the study broadens its scope by exploring two diverse geographical regions, Sweden and Spain, as case studies. This comparative approach offers invaluable insights into the role of factors like lower electricity prices and reduced solar energy availability, as observed in the Swedish case, versus the dynamics of higher electricity prices and abundant solar energy in the Spanish context. Lastly, the research undertakes a thorough sensitivity analysis, considering two pivotal factors with great influence over the system's behavior: hydrogen pricing and BESS capacity. This exploration enriches our understanding of how variations in these factors can impact the system's operational and economic viability. / Detta arbete presenterar ett hybridsystem för produktion av vätgas som integrerar elnätsanslutning, förnybar energiförsörjning genom solceller (PV), ett batterilager (BESS) och en PEM-elektrolysör. För detta energisystem har en optimeringsalgoritm för systemdrift skapats. Denna algoritm utvärderar energipriser och tillgänglig kapacitet från PV-systemet, och driftar systemet på timbasis för att optimera nettovinsten över ett år, med dagliga produktionsgränser för vätgas. När elpriset är lågt används energin för två ändamål: Att elektrolysera vatten i elektrolyssystemet, och att lagra det i batterilagret (BESS). Den lagrade energin från BESS kommer att användas för att producera vätgas när elpriserna är höga eller för att injicera tillbaka i elnätet när det är ekonomiskt försvarbart. Energin från PV-systemet används för att lindra behovet av energi från elnätet och kan användas för att driva elektrolysören, eller för att lagra i batterierna, eller för att injicera tillbaka i elnätet. I denna studie modelleras en elektrolysör, baserat på kommersiellt tillgängliga teknologier, och en driftsstrategi utvecklas för produktionen av grön vätgas. Fyra unika scenarier valdes ut: Scenario 1 (Nät + PEM), Scenario 2 (Scenario 1 + BESS), Scenario 3 (Scenario 2 + Injektion till Elnät) och Scenario 4 (Scenario 3 + Solenergi från PV). Dessa scenarier underlättar en omfattande bedömning av systemets ekonomiska och miljömässiga prestanda beroende på installeradetillgångar. Utöver scenarioanalysen vidgar studien sin omfattning genom att utforska två olika geografiska regioner, Sverige och Spanien, som fallstudier. Denna jämförelse ger värdefulla insikter i systemfaktorernas roll, där det Svenska fallet (med lägre elpriser och minskad tillgänglighet av solenergi) ställs emot the Spanska fallet (med högre elpriser och rikligt med solenergi). Slutligen genomför forskningen en noggrann känslighetsanalys och beaktar två avgörande faktorer med stor påverkan över systemets beteende: Priset på såld vätgas och BESS-kapaciteten. Denna utforskning berikar vår förståelse för hur variationer i dessa faktorer kan påverka systemets operativa och ekonomiska livskraft.

Emerging integration of renewable energy has prompted a wide range of research on the use of energy storage to compensate for the added uncertainty that accompanies these resources. In the Electric Reliability Council of Texas (ERCOT), compressed air energy storage (CAES) has drawn particular attention because Texas has suitable geology and also lacks appropriate resources and locations for pumped hydroelectric storage (PHS). While there have been studies on incorporation of renewable energy, utilization of energy storage, and dispatch optimization, this is the first body of work to integrate all these subjects along with the proven ability to recreate historical dispatch and price conditions. To quantify the operational behavior, economic feasibility, and environmental impacts of CAES, this work utilized sophisticated unit commitment and dispatch (UC&D) models that determine the least-cost dispatch for meeting a set of grid and generator constraints. This work first addressed the ability of these models to recreate historical dispatch and price conditions through a calibration analysis that incorporated major model improvements such as capacity availability and sophisticated treatment of combined heat and power (CHP) plants. These additions appreciably improved the consistency of the model results when compared to historical ERCOT conditions. An initial UC&D model was used to investigate the impacts on the dispatch of a future high wind generation scenario with the potential to utilize numerous CAES facilities. For all future natural gas prices considered, the addition of CAES led to reduced use of high marginal cost generator types, increased use of base-load generator types, and average reductions in the total operating costs of 3.7 million dollars per week. Additional analyses demonstrated the importance of allowing CAES to participate in all available energy and ancillary services (AS) markets and that a reduction in future thermal capacity would increase the use of CAES. A second UC&D model, which incorporated advanced features like variable marginal heat rates, was used to analyze the influence of future wind generation variability on the dispatch and resulting environmental impacts. This analysis revealed that higher amounts of wind variability led to an increase in the daily net load ramping requirements which resulted in less use of coal and nuclear generators in favor of faster ramping units along with reductions in emissions and water use. The changes to the net load also resulted in increased volatility of the energy and AS prices between daily minimum and maximum levels. These impacts were also found to increase with compounding intensity as higher levels of wind variability were reached. Lastly, the advanced UC&D model was also used to evaluate the operational behavior and potential economic feasibility of a first entrant conventional or adiabatic CAES system. Both storage systems were found to operate in a single mode that enabled very high utilization of their capacity indicating both systems have highly desirable characteristics. The results suggest that there is a positive case for the investment in a first entrant CAES facility in the ERCOT market. / text

The integration of distributed energy sources and systems is of high relevance for the transition towards a more sustainable energy system. Taking into consideration the  amount of emissions produced by the heating sector, which account for at least half of the energy demand in buildings, district heating systems have the potential to play a key role in the transition, by enabling the integration of various energy sources and provide flexible energy services to the grid. The objective of this research is to evaluate the potential for flexible sector coupling between the electrical and heating sectors, utilizing thermal energy storage alongside various heat generation units, including heat pumps and a combined heat and power (CHP) unit. To examine this concept, we used a district heating facility located in Oskarshamn, Sweden, as our case study. At present, the production mix at this facility comprises various production units- that utilize mainly biomass as their fuel source, including wood pellets, wood chips, and occasionally, bio-oil. Extensive research was conducted to review the existing literature and gain a comprehensive understanding of the technologies and concepts associated with FSC. This thorough examination allowed for a comprehensive overview of the current state-of-the-art in FSC. As the main contributions of this work, two numerical models respectively for production and dispatch optimization were developed and simulated complementary, concerning the thermal and electrical system of the studied plant. A dispatch model was developed with the aim of analyzing the operating behaviour of the system, identifying the available energy sources and optimizing their hourly dispatch. Subsequently, utilizing the open-access tool for capacity and investment optimization (OSeMOSYS), various scenarios were examined to evaluate the potential of thermal energy storage (TES), where a water tank was found to be the most cost-effective solution, and heat pump integration in enhancing the plant performance and providing flexibility. The study was divided into two distinct time periods. The first period focused solely on hourly dispatch optimization until 2035. In the second period, the analysis extended to include investment optimization, followed by the subsequent dispatch optimization until 2050, hence, using both tools. To effectively compare and assess the different scenarios, several key performance indicators (KPIs) were chosen, including the levelized cost of energy (LCOE), capital expenditure (CAPEX), generation costs, and emissions. These scenarios were designed to account for variations in crucial variables such as electricity prices, the plant’s self-consumption potential, and the capital cost of storage. By considering the aforementioned factors, a comprehensive analysis was conducted to determine the optimal approach for maximizing performance and cost-effectiveness. It is important to mention that the electrical self-consumption within the plant was considered as one of the potential improvements. While the potential for electrical self-consumption was mainly studied on a shorter-term, the variability in the capital cost of the TES system was better considered on the long-term investment analysis. From the different simulations, the cases where self-consumption is included result in smaller operating costs, as producing electricity via the CHP unit of the plant is cheaper on average than the prices offered by the local distribution company. The obtained capacities for TES and the heat pump vary among the studied scenarios. Higher electricity prices favor investments in alternative fuel boilers like wood chips or wood pellets, while lower electricity prices result in increased TES capacities and higher heat pump production. The capital cost of storage also determines the capacity chosen for the storage water tank, sometimes investing a bit more to gain efficiency and reduce operational costs. Throughout the project, various sustainability aspects have been addressed. These encompass environmental responsibilities, with a focus on reducing CO2 emissions, enhancing social equity by implementing a more efficient heating system within the municipality, and assessing the economic viability of these initiatives. In conclusion, the study provides evidence and showcases the viability of implementing FSC in Oskarshamn’s power plant, as results from the different scenarios commonly show that FSC could bring down the total costs, as well as the amount of CO2 emissions on a long-term basis. Based on the findings, additional recommendations are proposed to optimize the plant’s performance and leverage the potential of this innovative approach. The proposed recommendations include increasing the time resolution in the model simulations to improve result accuracy and exploring different scenarios, which may involve considering various electricity or fuel price predictions, among other factors. / Integreringen av distribuerade energikällor och energisystem är av stor betydelse för övergången till ett mer hållbart energisystem. Med hänsyn till det utsläpp från värmesektorn, som står för minst hälften av energibehovet i byggnader, har fjärrvärmesystem potential att spela en nyckelroll i omställningen genom att möjliggöra integrering av olika energikällor och tillhandahålla flexibla energitjänster till nätet. Syftet med denna forskning är att utvärdera Potentialen för flexibel sektorkoppling (FSC) mellan el- och värmesektorerna, med hjälp av termisk energilagring tillsammans med olika värmeproduktionsenheter, inklusive värmepumpar och en kombinerad kraftvärmeproduktion (CHP). För att undersöka detta koncept, använde vi en fjärrvärmeanläggning i Oskarshamn, Sverige, som vår fallstudie. För tillfället består produktionsmixen vid denna anläggning av olika produktionsenheter som huvudsakligen använder biomassa som bränslekälla, inklusive träpellets, träflis och ibland bioolja. Omfattande forskning genomfördes för att granska den befintliga litteratur och få en heltäckande förståelse för de tekniker och koncept som är förknippade med FSC. Denna grundliga undersökning möjliggjorde en omfattande översikt av det aktuella kunskapsläget inom FSC. Som de viktigaste bidragen i detta arbete utvecklades och simulerades två numeriska modeller för produktions- respektive leveransoptimering, som berör det termiska och elektriska systemet i den studerade anläggningen. En fördelningsmodell utvecklades i syfte att analysera systemets driftsbeteende, identifiera tillgängliga energikällor och optimera deras fördelning per timme. Med hjälp av det verktyget med öppna tillgång (open-aceess) för kapacitets- och investeringsoptimering (OSeMOSYS) undersöktes därefter olika scenarier för att utvärdera potentialen för termisk energilagring (TES), där en vattentank visade sig vara den mest kostnadseffektiva lösningen, och integration av värmepumpar för att förbättra anläggningens prestanda och ge flexibilitet. Studien var uppdelad i två olika tidsperioder. Den första perioden fokuserade enbart på optimering av timfördelning fram till 2035. Under den andra perioden utvidgades analysen till att omfatta investeringsoptimering, följt av efterföljande optimering av driften fram till 2050, vilket innebär att båda verktygen användes. För att effektivt kunna jämföra och bedöma de olika scenarierna valdes flera viktiga nyckelprestandaindikatorer (KPI:er), inklusive den nivellerade energikostnaden (LCOE), kapitalinvesteringar (CAPEX), produktionskostnader och CO2 utsläpp. Dessa scenarier utformades för att ta hänsyn till variationer i viktiga variabler som elpriser, anläggningens självkonsumtionspotential och kapitalkostnaden för lagring. Med hänsyn till de ovan nämnda faktorerna genomfördes en omfattande analys för att fastställa den optimala metoden för att maximera prestanda och kostnadseffektivitet. Det är viktigt att nämna att den elektriska självförbrukningen inom anläggningen betraktades som en av de potentiella förbättringarna. Medan potentialen för elektrisk självförbrukning främst studerades på kortare sikt, beaktades variationen i kapitalkostnaden för TES-systemet bättre i den långsiktiga investeringsanalysen. De olika simuleringarna visar att de fall där självförbrukning ingår resulterar i lägre driftskostnader, eftersom elproduktionen via kraftvärmeverket i genomsnitt är billigare än de priser som erbjuds av det lokala distributionsbolaget. De erhållna kapaciteterna för TES och värmepumpen varierar mellan de studerade scenarierna. Högre elpriser gynnar investeringar i alternativa bränslepannor som flis eller träpellets, medan lägre elpriser resulterar i ökad TES-kapacitet och högre värmepumpsproduktion. Kapitalkostnaden för lagring avgör också vilken kapacitet som väljs för vattentanken (some en TES), ibland investerar man lite mer för att öka effektiviteten och minska driftskostnaderna. Under hela projektet har olika hållbarhetsaspekter beaktats. Dessa omfattar miljöansvar, med fokus på att minska CO2-utsläppen, öka den sociala rättvisan genom att införa ett mer effektivt värmesystem inom kommunen, och bedöma den ekonomiska bärkraften i dessa initiativ. Sammanfattningsvis visar studien att det är möjligt att implementera FSC i Oskarshamns kraftverk, eftersom resultaten från de olika scenarierna visar att FSC kan sänka de totala kostnaderna samt mängden CO2-utsläpp på lång sikt. Baserat på resultaten föreslås ytterligare rekommendationer för att optimera anläggningens prestanda och utnyttja potentialen i denna innovativa metod. De föreslagna rekommendationerna inkluderar att öka tidsupplösningen i modellsimuleringarna för att förbättra resultatens noggrannhet och utforska olika scenarier, vilket bland annat kan innebära att man överväger olika el- eller bränsleprisprognoser.