Desalination is one of the proposed methods to meet the ever increasing water demands. It can be subdivided into two broad categories, thermal based desalination and electricity based desalination. Multi-effect Distillation (MED), Multi-Stage Flashing (MSF), Membrane Distillation (MD) fall under former and Reverse Osmosis (RO), Electro-Dialysis (ED) fall under later. MD offers an attractive solution for seawater as well as brackish water distillation. It shows highly pure yields, theoretically 100% pure. The overall construction of a MD unit is way simpler than any other desalination systems. MD is a thermally driven diffusion process where desalination takes places in the form of water vapor transport across the membrane. It has low second law efficiency due to parasitic heat losses. The objective of the first part of the investigation is to thoroughly analyze a Direct Contact Membrane Distillation (DCMD) system from the view point of yield and exergy. The insights from exergy analysis are used in a design study, which is used for performance optimization. The first part concludes with a design procedure and design windows for large scale DCMD construction. In the second part of the investigation, focus is moved to waveguide solar energy collector. The idea behind an ideal waveguide is to reduce the complexity of modeling solar energy collection. The mathematical model provided in this analysis can be extended to a family of non-imaging optics in solar energy and serves as a benchmarking analysis tool. A waveguide is suitable for low temperature operations due to limitations on maximum continuous temperature of operation. Thus, it becomes an ideal solution for DCMD applications. A levelized cost analysis is presented for a waveguide powered DCMD plant of a 30,000 capacity. A combination of waveguide and DCMD shows levelized cost of water at $1.80/m³, which is found to be lower than previously reported solar desalination water costs. / Master of Science

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.

Coordenação de Aperfeiçoamento de Pessoal de Nível Superior / 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. / 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.

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

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.

growing concern on achieving environmental sustainability and at the same time making economical savings has become a necessity in our society. The prices of different battery energy storage technologies together with PV cells are declining all around the globe which has led to the fact that there is an increased interest in investing and using these technologies to be able to reach environmental sustainability. The combined system however, must be accurately calculated both when it comes to the sizing and the different costs related to the combined system to be able to make an economical saving. This thesis addresses both of those aspects in Sweden where a residential building with roof-top installed PV system is assessed with a battery energy storage system. An investigation is necessary to be able to assess the different battery storage technologies available in the market today with their specific technical and economical specifications. The electricity market in Sweden, the role of the Distribution System Operator on the electricity pricing with different time tariffs and fuse size subscription, PV generation and battery specifications are investigated and modeled in this study. Sizing of the different battery technologies for the given system is accomplished through a methodology that is developed in this project for the Swedish system. The calculated size of the battery is then used in the Life Cycle Cost analysis, using Monte Carlo simulations for a chosen period of 25 years.Calculations shows that the most appropriate size for the battery system with the given parameters is 6 kWh for all the battery types investigated in this study. The size of the batteries is also shown to be mainly dependent on the charging/discharging time together with the set fuse size margin. Profitability of the Battery Energy Storage system is proven to be mainly dependent on the fuse size downgrade. Sulphur-Sodium battery result in the greatest savings while Vanadium Redox batteries in the least when sizing the batteries. Lithium-Ion battery technology however is most likely to result in the lowest Levelized Cost of Electricity, total- and cycle costs while the highest Net Present Value with 90 % probability in the Monte Carlo simulations. Lithium-Ion battery technology is also found to have the highest probability of having a positive NPV compared to the lowest probability for Sulphur-Sodium battery technology. Lead-Acid battery technology is however shown to have the least uncertainties compared to other Battery Energy Storage technologies due to its maturity. It is additionally shown that government subsidy plays a crucial role when investing in the battery storage system. However, even with the case of removed government subsidy, Lithium-Ion battery technology still results in the largest probability of having a positive NPV while Sulphur-Sodium battery technology results in the lowest probability of having a positive NPV. / Den växande oron för att uppnå miljömässig hållbarhet och samtidigt göra ekonomiska besparingar har blivit en nödvändighet i vårt samhälle. Priserna på olika energilagrings teknologier så som batterier tillsammans med PV-celler minskar runt om i världen vilket har lett till att det finns ett ökat intresse när det gäller att investera och använda dessa teknologier för att kunna nå miljömässig hållbarhet. Det kombinerade systemet måste dock noggrant beräknas både när det gäller storleken och de olika kostnaderna för det kombinerade systemet för att kunna göra en ekonomisk besparing. Denna avhandling behandlar båda dessa aspekter i Sverige där en bostadsbyggnad med takmonterat PV system utvärderas med ett batteri system. En undersökning är nödvändig för att kunna bedöma de olika batteri teknologier som finns tillgängliga på marknaden idag med sina specifika tekniska och ekonomiska specifikationer. Elmarknaden i Sverige, Distribution System Operatörs roll för elprissättning med olika tidstariffer och säkringsabonnemang, PV-generation och batterispecifikationer undersöks och modelleras i denna studie. Dimensionering av olika batteri teknologier för det givna systemet uppnås genom en metod som utvecklats i detta projekt för det svenska systemet. Den beräknade storleken på batteriet används sedan i livscykelkostnadsanalysen, med Monte Carlo-simuleringar under en vald period på 25 år. Beräkningar visar att den optimala storleken för batterisystemet med de angivna parametrarna är 6 kWh för alla batterityper som undersöktes i denna studie. Batteriets storlek visar sig också vara huvudsakligen beroende av laddning / urladdningstiden tillsammans med den inställda säkrings storleken. Lönsamheten hos batterilagringssystemet visar sig vara huvudsakligen beroende av säkringens nedgradering. Svavel-Natriumbatteriet resulterar i de största besparingarna medan Vanadium Redox batteriet i de minsta när dimensionering av batteriet äger rum. Litium-Ion batteriet är emellertid sannolikt att leda till den lägsta nivån av elkostnader, total- och cykelkostnader, medan det högsta nettoförsäljningsvärdet med 90% sannolikhet i Monte Carlo-simuleringarna. Litium-Ion batteriet befanns också ha den högsta sannolikheten att ha en positiv NPV jämfört med Svavel-Natriumbatteriet som resulterar i den lägsta sannolikheten. Lead-Acid batteriet visar sig ha den minsta osäkerheten i jämförelse med andra batterilagrings teknologier på grund av dess mognad. Det framgår dessutom att statlig subvention spelar en avgörande roll när man investerar i ett batteri lagrings system. Dock även med borttagna statliga subventioner, resulterar Litium-Ion batteriet fortfarande största sannolikheten för att ha en positiv NPV, medan Svavel-Natriumbatteriet resulterar den lägsta sannolikheten för att ha en positiv NPV.

There is a well-established market for hydrogen, mainly for refining purposes, producing chemicals, and producing fertilizers. Today, almost all hydrogen is sourced from fossil fuels, with less than 1% of hydrogen sourced from renewable sources. Alternative solutions for fossil-free hydrogen are necessary to ensure that the demand for hydrogen can be met in a sustainable fashion. The objective of this study is to analyse the feasibility and cost-effectiveness of combining hydrogen production through electrolysis with electricity production from an array of wave energy converters to supply the hydrogen market with fossil-free hydrogen. A techno-economic analysis is performed for 16 cases of offshore hydrogen production and storage in eastern Japan, using three storage mediums; Compressed hydrogen, liquid hydrogen and ammonia. Technical and economical specifications of all components required for the production systems are modelled for each case to find the most beneficial system through the Levelized Cost Of Hydrogen (LCOH), which is compared to other available renewable and fossil hydrogen sources today. The production systems evaluated in this study reach an LCOH of $5.5-7.1 /kgH2 depending on the hydrogen storage medium, where compressed hydrogen is the cheapest. This can be considered competitive with other renewable hydrogen sources, but not with fossil counterparts. / Det finns en väletablerad marknad för vätgas, främst för raffinering och framställning av kemikalier samt gödningsmedel. Idag produceras nästan all vätgas av fossila bränslen, med mindre än 1% från förnybara källor. Alternativa lösningar för förnybar vätgas är nödvändiga för att möta efterfrågan på ett hållbart sätt. Syftet med denna studie är att analysera om det är ekonomiskt försvarbart att producera vätgas offshore genom elektrolys av el från vågkraftverk för att förse vätgasmarknaden med fossilfri vätgas. Detta utförs genom en tekno-ekonomisk analys av 16 fall av havsbaserad vätgasproduktion och lagring i östra Japan. Fallen behandlar tre lagringsmedium; komprimerad vätgas, flytande vätgas och ammoniak. Tekniska och ekonomiska specifikationer för alla komponenter som krävs för produktionssystemet modelleras för varje fall. Det mest fördelaktiga systemet beräknas genom Levelized Cost of Hydrogen (LCOH), som jämförs med andra tillgängliga förnybara och fossila produktionssystem för att avgöra systemets konkurrenskraft på marknaden. Produktionssystemen som utvärderas i denna studie har en LCOH från $5.5-7.1 /kgH2 beroende på lagringsmedium, där komprimerad vätgas är det billigaste. Detta resultat kan betraktas som konkurrenskraftigt med andra förnybara vätgaskällor, men inte med fossila motsvarigheter.

This study will examine a strategy for evaluating energy storage projects by integrating valuation metrics from finance and the energy sector. Uncertainty is one of the key barriers to investment in the energy sector (Shimbar & Ebrahimi, 2017, p. 349) and therefore financial modeling that allows comprehensive valuation of energy investment is necessary (Berrada, 2022, p. 407). The purpose of the study is to propose a strategy for evaluating energy storage projects that applies to investors and decision makers.  LCOS is a necessary component of energy storage project valuation, as it considers both the financial and technical performance of energy storage systems (ESS). Existing research in the field has contradictory opinions regarding the usefulness of LCOS and traditional financial valuation models for investment decisions in the energy storage sector. Few studies have combined modeling from the financial and energy sector. The authors have identified a need to introduce an investor perspective to business research in the energy storage sector. The authors conduct an explorative mixed-method study with an underlying non-positivist philosophical position. The case study design includes creation of five hypothetical energy storage projects to simulate an investment scenario. The authors utilize a point-base system to integrate valuation models from the energy and financial sectors, which include NPV, IRR, payback period, LCOS and technological maturity. Experts in the field provide input for which metrics are emphasized by practitioners. The projects are ranked based on stand-alone metrics, an integrated model and expert opinion. The results indicate that integrating numerous valuation metrics is necessary for analyzing and comparing energy storage investments. The financial viability of projects change based on individual metrics and integrated financial models. Furthermore, the results indicate that LCOS should be reinforced by financial indicators when making investment decisions. The expert input shows that investors emphasize valuation metrics differently, which indicates that the economic attractiveness of energy storage projects varies among investors. IRR is used by practitioners as a primary indicator for profitability. Future research should investigate a method for including sustainability indicators in the valuation process. Furthermore, as data accessibility is an issue in the field of study, future studies should collaborate with practitioners to generate more secondary data sources. Lastly, the impact of discount rates, risk premiums and investor preferences should be researched to better understand investment in the sector.

This report conducts an in-depth examination of the potential for Small Modular Reactor (SMR)-based hydrogen production in Sweden's emerging nuclear market. Aligned with Sweden's ambitious targets of achieving carbon dioxide neutrality by 2045 and transitioning its steel and industry sectors to fossil-free production by 2035, the report explores the unique value proposition that a focal company can offer. This strategic positioning centres on supplying large volumes of hydrogen to the steel and iron industry while ensuring reliability and stability in production. To safeguard its competitive edge, the focal company leverages lock-in effects, capitalizing on the geographical placement of its facility and the establishment of a long-term Hydrogen Purchase Agreement (HPA) with its customers. Key findings highlight the levelized cost of hydrogen (LCOH) of 3.46 €/kg to 8.27 €/kg in the SMR-based production process. It reveals that transitioning from natural gas-based hydrogen is cost-intensive, resulting in a green premium (GP) ranging from 257% to 1134%. However, when compared to renewable energy sources and other fossil-free competitors, the LCOH proves competitive in every case except for HYBRIT’s, which is relying on low grid electricity prices in Sweden. When stipulating a HPA with a customer and using a real discount rate (RDR) of 3 % and a profit margin (PM) of 50 % over a 20-year analysis period, the project can reach a net present value (NPV) of 920 MEUR and discounted payback time (DPB) of 12 years in the most profitable case. In a more realistic scenario with a RDR of 7% and a PM of 30% the NPV becomes 497 MEUR with a DPB of 13 years. The economic feasibility is in general given at other, less favourable terms as well. This proves that the focal company’s business strategy is feasible. In conclusion, this report offers a strategic pathway for SMR-based hydrogen production in Sweden's evolving nuclear landscape. While feasibility is theoretically established, the presence of uncertainties cannot be overlooked. The report provides valuable insights for influential stakeholders in their decision-making processes and recognizes the substantial challenges and promising opportunities that lie ahead. / Denna rapport genomför en djupgående undersökning av potentialen för vätgasproduktion baserad på små modulära reaktorer (SMR) på den framväxande kärnkraftsmarknaden i Sverige. I linje med Sveriges ambitiösa mål att uppnå koldioxidneutralitet år 2045 och övergå sina stål- och industrisektorer till fossilfri produktion år 2035 utforskar rapporten det unika värdeerbjudandet som ett fokalföretag kan erbjuda. Denna strategiska positionering fokuserar på att leverera stora volymer av vätgas till stål- och järnindustrin samtidigt som tillförlitlighet och stabilitet i produktionen säkerställs. För att skydda sin konkurrensfördel utnyttjar det fokala företaget inlåsningseffekter genom att dra nytta av den geografiska placeringen av sin anläggning och etableringen av ett långsiktigt avtal om vätgasköp (HPA) med sina kunder. De viktigaste resultaten lyfter fram den utjämnade kostnaden för vätgas (LCOH) från 3.46 €/kg till 8.27 €/kg i produktionsprocessen baserad på SMR. Det visar att övergången från naturgasbaserad vätgas är kostnadsintensiv och resulterar i en grön premie (GP) som varierar från 257% till 1134%. Men när den jämförs med förnybara energikällor och andra fossilfria konkurrenter visar LCOH sig vara konkurrenskraftig i varje fall förutom i HYBRIT’s fall, vilket är beroende av låga elnätspriser i Sverige. När ett HPA stipuleras med kunden och man använder en verklig diskonteringsränta (RDR) på 3 % och en vinstmarginal (PM) på 50 % över en 20-års analysperiod, kan projektet nå ett nettonuvärde (NPV) på 920 MEUR och en diskonterad återbetalningstid (DPB) på 12 år i det mest lönsamma fallet. I ett mer realistiskt scenario med en RDR på 7 % och en PM på 30 % blir NPV 497 MEUR med en DPB på 13 år. Den ekonomiska genomförbarheten ges i allmänhet även på andra mindre förmånliga villkor. Det bevisar att det fokala företagets affärsstrategi är genomförbar. Sammanfattningsvis erbjuder denna rapport en strategisk väg för vätgasproduktion baserad på SMR i det svenska utvecklande kärnkraftslandskapet. Även om genomförbarheten teoretiskt är fastställd kan närvaron av osäkerheter inte bortses från. Rapporten ger värdefulla insikter för inflytelserika intressenter i deras beslutsprocesser och erkänner de betydande utmaningar och lovande möjligheter som ligger framöver.

Reducing carbon emissions in our societies requires a massive shift towards renewables. In Sweden, biomass is the dominant source for the district heat production, but growing demand for biomass in other sectors may cause pressure on it. In this context, this thesis explores the possibility to supply heat with solar parabolic thermal collectors to a district heating system in Kosta, a locality in Lessebo municipality, Kronoberg county. The simulations and calculations are based on the locally available hourly data of weather conditions, supply and return temperatures of district heat and heat demand profiles. The energy production as well as the profitability of the installation is evaluated through the calculation of carbon abatement costs, considering that heat supplied from solar collectors spares biomass which can be made available for decarbonating the power sector. Results have shown that a solar installation that cover most of the heat demand during the months of summer, thus 10% of the annual heat demand, can be profitable. This study also investigates different scenarios with increased costs for the biomass resource to simulate the growing pressure around this resource and concludes that with growing costs of the biomass resource, solar application will become more attractive, allowing to make larger solar district heating plants profitable.