Current concentrated solar power plants (CSP) use molten salt at 565°C as a heat transfer and energy storage fluid. Due to thermal energy storage (TES), these solar plants can deliver dispatachable electricity to the grid; however, the levelized cost of electricity (LCOE) for these plants is 12-15 c/kWh, about 2.5 times as high as fossil fuel electricity generation. Molten salt technology limits peak operating temperatures to 565°C and a heat engine efficiency of 40%. Liquid metal (LM), however, can reach >1350°C, and potentially utilize a more efficient (60%) heat engine and realize cost reductions. A 1350 °C LM-CSP plant would require ceramic containment, inert atmosphere containment, additional solar flux concentration, and redesigned internal receiver. It was initially unclear if these changes and additions for LM-CSP were technically feasible and could lower the LCOE compared to LS-CSP. To answer this question, a LM-CSP plant was designed with the same thermal input as a published LS-CSP plant. A graphite internal cavity receiver with secondary concentration heated liquid Sn to 1400°C and transferred heat to a 2-phase Al-Si fluid for 9 hours of thermal energy storage. Input heat to the combined power cycle was 1350°C and had 60% thermal efficiency for a gross output of 168 MW. The cost of this LM-CSP was estimated by applying material cost factors to the designed geometry and scaling construction costs from published LS-CSP estimates. Furthermore, graphite was experimentally tested for reactivity with liquid Sn, successful reaction bonds, and successful mechanical seals. The result is switching to molten metal can reduce CSP costs by 30% and graphite pipes, valves, and seals are possible at least at 400°C.

Concentrating solar power plants can integrate cost-effective thermal energy storage systems and thereby supply controllable power on demand, an advantage against other renewable technologies. Storage integration allows a solar thermal power plant to increase its load factor and to shift production to periods of peak demand. It also enables output firmness, providing stability to the power block and to the grid. Thus, despite the additional investment, storage can enhance the performance and economic viability of the plants. However, the levelized cost of electricity of these plants yet remains higher than for other technologies, so projects today are only viable through the provision of incentives or technology-specific competitive bid tenders. It is the variability of the solar resource, the myriad roles that storage can assume, and the complexity of enhancing the synergies between the solar field, the storage and the power block, what makes the development of adequate policy instruments, design and operation of these plants a challenging process. In this thesis a comprehensive methodology for the pre-design and analysis of concentrating solar power plants is presented. The methodology is based on a techno-economic modeling approach that allows identifying optimum trade-off curves between technical, environmental, and financial performance indicators. A number of contemporary plant layouts and novel storage and hybridization concepts are assessed to identify optimum plant configurations, in terms of component size and storage dispatch strategies. Conclusions highlight the relevance between the sizing of key plant components, the operation strategy and the boundaries set by the location. The interrelation between critical performance indicators, and their use as decisive parameters, is also discussed. Results are used as a basis to provide recommendations aimed to support the decision making process of key actors along the project development value chain of the plants. This research work and conclusions are primarily meant to set a stepping stone in the research of concentrating solar power plant design and optimization, but also to support the research towards understanding the value of storage in concentrating solar power plants and in the grid. / Koncentrerad solkraft erbjuder möjligheten att integrera kostnadseffektiv termisk energilagring och därmed behovsstyrd kraftkontroll. Detta är en viktig fördel jämfört med andra förnybara energiteknologier. Lagringsintegration tillåter solkraftsanläggningar att öka sin lastfaktor och skifta produktion till tider med största efterfrågan. Vidare möjliggör lagring fast elproduktion vilket leder till förbättrad nät- och kraftturbinstabilitet. Därför kan termisk lagring öka anläggningsprestanda och ekonomiskt värde trots ökande initiala kapitalkostnader. I termer av specifik elproduktionskostnad (LCOE) ligger koncentrerade solkraftsanläggningar med lagring fortfarande högre än andra kraftteknologier och anläggningsprojekt blir endast lönsamma genom subventionsmodeller eller teknologispecifika konkurrensutsatta anbudsförfaranden. Att hitta adekvata policylösningar och optimala design och operationsstrategier är en utmanande process eftersom det gäller att hitta rätt balans mellan variabel solinstrålning, lagring av energi och tid för produktion genom optimal design och operation av solmottagarfält, kraftblock och lagringskapacitet. I denna avhandling presenteras en omfattande metodik för pre-design och analys av koncentrerande solkraftverk. Metodiken baseras på en tekno-ekonomisk modelleringsansats som möjliggör identifiering av optimala avvägningssamband för tekniska, ekonomiska och miljöprestanda indikatorer. Metodiken tillämpas på ett antal moderna anläggningslayouter  och lagrings- och hybridiseringskoncept för att identifiera optimal kraftanläggningsdesign i termer av komponentprestanda och lagringsanvändningsstrategier. I slutsatsen poängteras relevansen av att hitta rätt storlek på nyckelkomponenter i relation till lagringsstrategi och randvillkoren som ges av konstruktionsläget för optimal ekonomisk och miljömässig prestanda. Resultaten används för att formulera rekommendationer till nyckelaktörer i beslutsprocessen genom hela kraftanläggningens värdekedja från politisk beslutsfattare till anläggningsingenjör. Forskningen och slutsatserna i detta arbete skall i första hand ta ett steg framåt för optimering och design av solkraftsanläggningar men även tillhandahålla en metodik för utvärdering av lagringslösningar och dess specifika värde för solkraftsanläggningar och elnätet. / <p>QC 20160829</p>

Most of the world’s electricity is being generated through conventional sources of energy like coal and nuclear. People are realizing the dire effect of using these fuels, and the amount of CO2 being released into the environment. Therefore, in recent year there has been a shift in emphasis towards cleaner ways of generating electricity. One such recent trend is solar photovoltaics (PV), which has seen rapid growth over the years. This ever-increasing trend of adopting PV system allows consumers to be producers or “Prosumers”. Due to the irregular production capability of solar PV, the need for an energy storage system like a battery bank is on the rise as well. This report evaluates how solar PV can be used in combination with a battery bank to supply the annual electricity demand for a household with little to no support from the grid. The building is assumed to be located in Bangalore, India. The energy demand for the household is estimated based on the requirements of a basic Indian house standard. The size and configuration of each component have been done with regards to the total load demand. Furthermore, the cost of the whole system is estimated in order to evaluate the feasibility of the grid-tied system from an economic perspective. The results show that a PV system consisting of four 270W solar panels, a battery bank of eight150Ah lead-acid batteries and a 48V 4kW inverter is required to meet the annual energy demand of the house. The results show that from a technical standpoint, the above-mentioned technology is feasible. The results from the economic evaluation show that the localized cost of energy(LCOE) for the system is ₹6.01/kWh or € 0.078/kWh or 0.84SEK/kWh and the payback time for the given system is 16.19 years. On the bright side, there are new technological advancements in the PV field every day, which could mean that an energy system of this type can be an achievable and practical alternative. Most of the world’s electricity is being generated through conventional sources of energy like coal and nuclear. People are realizing the dire effect of using these fuels, and the amount of CO2 being released into the environment. Therefore, in recent year there has been a shift in emphasis towards cleaner ways of generating electricity. One such recent trend is solar photovoltaics (PV), which has seen rapid growth over the years. This ever-increasing trend of adopting PV system allows consumers to be producers or “Prosumers”. Due to the irregular production capability of solar PV, the need for an energy storage system like a battery bank is on the rise as well. This report evaluates how solar PV can be used in combination with a battery bank to supply the annual electricity demand for a household with little to no support from the grid. The building is assumed to be located in Bangalore, India. The energy demand for the household is estimated based on the requirements of a basic Indian house standard. The size and configuration of each component have been done with regards to the total load demand. Furthermore, the cost of the whole system is estimated in order to evaluate the feasibility of the grid-tied system from an economic perspective. The results show that a PV system consisting of four 270W solar panels, a battery bank of eight 150Ah lead-acid batteries and a 48V 4kW inverter is required to meet the annual energy demand of the house. The results show that from a technical standpoint, the above-mentioned technology is feasible. The results from the economic evaluation show that the localized cost of energy (LCOE) for the system is ₹6.01/kWh or € 0.078/kWh or 0.84SEK/kWh and the payback time for the given system is 16.19 years. On the bright side, there are new technological advancements in the PV field every day, which could mean that an energy system of this type can be an achievable and practical alternative.

Globally, approximately 663 million people lack access to safe drinking water sources and nearly half of these people live in Sub-Saharan Africa (SSA), where only 68% of the population has access to improved drinking water sources. Globally, it is estimated that 79% of the people using unimproved sources and 93% of people using surface water live in rural areas. In terms of water for agriculture, most of the countries in Sub-Saharan Africa rely on rain-fed agriculture, which is threatened by the effects of climate change thereby worsening food insecurity. Adequate provision of drinking and irrigation water is believed to enhance development in areas such as health, education, food security and women empowerment. This interdisciplinary study used a mixed methods approach to develop a financing and decision support model for planning and analysing of sustainable rural water provision using solar photovoltaics (PV) in SSA, with Malawi as a case study country. The research methods included household surveys, stakeholder interviews, field visits and techno-economic analysis. Findings from the household surveys show that the current water sources are inadequate; the majority of the households used boreholes as their main source of water and they faced challenges, which included queuing, low yield, non-functionality, disparity in number of water points, theft and vandalism. For irrigation, households still rely on traditional methods of irrigation namely; watering cans with very few having treadle pumps, which are all labour intensive. From the stakeholders point of view, challenges included lack of finances, failure of current community management system, lack of coordination and lack of enabling policies. In the techno-economic analysis, a solar PV system was designed to supply approximately 200 households with drinking water. The design cost was calculated to be US$18,600 and the levelized cost of water was US$0.34/m3. The levelized cost was found to be almost six times what the households are currently paying and three times what they are willing to pay. To address this issue, the study developed a cross-subsidy model for the cost of water with that of basic energy services, particularly rechargeable lantern lighting and mobile phone charging. Using this model, the levelized cost of water was reduced by over half but is still two and a half times what they are currently paying for water. Further innovations were found to reduce the breakeven cost to only US$0.06 more of what they are currently paying. The novelty of the research is that no work in SSA, particularly in Malawi has developed such an all-inclusive integrated needs-driven approach that helps identify solar PV powered water provision solutions. These results provide baseline data for researchers, policymakers, planners, entrepreneurs and other stakeholders with interest in providing water and energy to the rural areas. This thesis recommends that with proper finance and management policies, enforcement of product and installation standards and training of households, solar PV can be used to improve access for drinking and irrigation water and at the same time provide basic energy services to the people living in the rural areas of SSA.

abstract: To date, the production of algal biofuels is not economically sustainable due to the cost of production and the low cost of conventional fuels. As a result, interest has been shifting to high value products in the algae community to make up for the low economic potential of algal biofuels. The economic potential of high-value products does not however, eliminate the need to consider the environmental impacts. The majority of the environmental impacts associated with algal biofuels overlap with algal bioproducts in general (high-energy dewatering) due to the similarities in their production pathways. Selecting appropriate product sets is a critical step in the commercialization of algal biorefineries. This thesis evaluates the potential of algae multiproduct biorefineries for the production of fuel and high-value products to be economically self-sufficient and still contribute to climate change mandates laid out by the government via the Energy Independence and Security Act (EISA) of 2007. This research demonstrates: 1) The environmental impacts of algal omega-3 fatty acid production can be lower than conventional omega-3 fatty acid production, depending on the dewatering strategy. 2) The production of high-value products can support biofuels with both products being sold at prices comparable to 2016 prices. 3) There is a tradeoff between revenue and fuel production 4) There is a tradeoff between the net energy ratio of the algal biorefinery and the economic viability due to the lower fuel production in a multi-product model that produces high-value products and diesel vs. the lower economic potential from a multi-product model that just produces diesel. This work represents the first efforts to use life cycle assessment and techno-economic analysis to assess the economic and environmental sustainability of an existing pilot-scale biorefinery tasked with the production of high-value products and biofuels. This thesis also identifies improvements for multiproduct algal biorefineries that will achieve environmentally sustainable biofuel and products while maintaining economic viability. / Dissertation/Thesis / Doctoral Dissertation Civil and Environmental Engineering 2016

Biofuels have been identified as one of several GHG emission strategies to reduce the use of fossil fuels in the transport sector. Fast pyrolysis of biomass is one approach to producing second generation biofuels. The bio-oil product of fast pyrolysis can be upgraded into essential gasoline and diesel range products with conventional refinery technologies. Thus, it is important to assess their techno- economic and environmental performance at an early stage prior to commercialisation. This research was conducted with the goal of evaluating and comparing the techno-economic and environmental viability of the production of biofuels from fast pyrolysis of biomass and upgrading of bio-oil via two refinery technologies, viz. hydroprocessing and zeolite cracking. In order to achieve this aim, process models of fast pyrolysis of biomass and bio-oil upgrading via hydroprocessing and zeolite cracking were developed. The fast pyrolysis model was based on multi-step kinetic models. In addition, lumped kinetic models of the hydrodeoxygenation reactions of bio-oil were implemented. The models were verified against experimental measurements with good prediction and formed the foundation for the development of a 72 t/day fast pyrolysis plant model in Aspen Plus®. Several strategies were proposed for the two pathways to enhance energy efficiency and profitability. All in all, the results revealed that the hydroprocessing route is 16% more efficient than the zeolite cracking pathway. Moreover, the hydroprocessing route resulted in a minimum fuel selling price of 15% lower than that from the zeolite cracking pathway. Sensitivity analysis revealed that the techno-economic and environmental performance of the both pathways depends on several process, economic and environmental parameters. In particular, biofuel yield, operating cost and income tax were identified as the most sensitive techno-economic parameters, while changes in nitrogen feed gas to the pyrolysis reactor and fuel yield had the most environmental impact. It was concluded that hydroprocessing is a more suitable upgrading pathway than zeolite cracking in terms of economic viability, energy efficiency, and GHG emissions per energy content of fuel produced.

No description available.

Photovoltaic thermal (PVT) collectors are widely used to harness a large fraction of the solar spectrum to generate electricity and heat from a single collector. The circulation of the working medium will pass through the collector which cools down the PV cell temperature and also increases the water temperature, which will increase the electrical and thermal performance at the same time. PVT is an emerging technology and is demonstrated for domestic and industrial applications. There has also been a major gap for the techno-economic analysis of PVT system in different climatic conditions and further developing reliable financial models that can be applied in different regions. This thesis paper presents a techno-economic evaluation of a liquid-based PVT collector system developed by Abora Solar, Spain across a wide range of climatic conditions and contexts. The various performance indicators are visualized by digital mapping approach for 86 different locations all over the world. The databank obtained from the analysis is further used to establish a general correlation between collector performance and meteorological parameters such as Global horizontal irradiation and ambient temperature. The collector energetic performance is simulated using a validated and proprietary simulation tool developed by Abora Solar company. The complete energy system consists of a PVT collector, a water storage tank, and the associated DHW demand simulator. The collector energetic performance has reflected following the analysed Global horizontal irradiation and ambient temperature trend. The highest and lowest energy utilization ratio of the collector has been recorded in Reykjavik, Iceland (63%) and Medina, Saudi Arabia (54%) respectively. The highest and lowest exergetic efficiency of the collector has been recorded in Reykjavik, Iceland (23%) and Medina, Saudi Arabia (17%) respectively. The exergetic efficiency collector has shown better performance with the less ambient temperature and less quality of work in high ambient temperatures. Furthermore, the energy utilization ratio and exergetic efficiencies of collector production are analysed. The economic analysis is carried out in realistic approach using two different financial scenarios: mode (1) The total system cost is capital investment in the first year; mode (2) Only 25 % of total system cost is a capital investment and remaining 75 % investment is considered with financing period with certain interest rate. The economic performance of the collector has been decided mainly based on the Net Present Value per unit collector area, whereas it expressed high dependency on thermal energy savings. The average NPV per unit collector area of 86 geographical cities for first financial model 1 and financial model 2 are 1886€ and 2221€ respectively. Besides, the Payback Period has also been estimated for the first financing model in all selected locations. The first financial model (1) has shown better results in locations with a high interest rate and highly recommended for the locations with interest rate. The significant work of understanding of PVT components behaviour at the system level, the collector energetic and economic performance at different climatic conditions across the world have been highlighted which reflects the concrete developments to this research subject area and helps market decision-makers for market penetration.

The industrial sector is one of the largest emitters of CO2 and a great potential for retrofitting with carbon capture systems. In this work the performance of a palladium-based membrane reactor at 400°C and operating pressures between 100-400 kPa have been studied in terms of methane conversion, hydrogen recovery, hydrogen purity, and CO2 emission. It is found that the MR has the potential to produce high purity hydrogen while the methane conversion values could be as high as 40% at very moderate operating conditions and without using any sweep gases. The H2 permeation and separation properties of two Pd-based composite membranes were evaluated and compared at 400 °C and at a pressure range of 150 kPa to 600 kPa. One membrane was characterized by an approximately 8 μm-thick palladium (Pd)-gold (Au) layer deposited on an asymmetric microporous Al2O3 substrate; the other membrane consisted of an approximately 11 μm-thick pure palladium layer deposited on a yttria-stabilized zirconia (YSZ) support. At 400 °C and with a trans-membrane pressure of 50 kPa, the membranes showed a H2 permeance of 8.42 × 10−4 mol/m2·s·Pa0.5 and 2.54 × 10−5 mol/m2·s·Pa0.7 for Pd-Au and Pd membranes, respectively. Pd-Au membrane showed infinite ideal selectivity to H2 with respect to He and Ar at 400 °C and a trans-membrane pressure of 50 kPa, while the ideal selectivities for the Pd membrane under the same operating conditions were much lower. Furthermore, the permeation tests for ternary and quaternary mixtures of H2, CO, CO2, CH4, and H2O were conducted on the Pd/YSZ membrane. The H2 permeating flux decreased at the conclusion of the permeation tests for all mixtures. This decline however, was not permanent, i.e., H2 permeation was restored to its initial value after treating the membrane with H2 for a maximum of 7 h. The effects of gas hourly space velocity (GHSV) and the steam-to-carbon (S/C) ratio on H2 permeation were also investigated using simulated steam methane reforming mixtures. It was found that H2 permeation is highest at the greatest GHSV, due to a decline in the concentration polarization effect. Variations in S/C ratio however, showed no significant effect on the H2 permeation. The permeation characteristics for the Pd/YSZ membrane were also investigated at temperatures ranging from 350 to 400 °C. The pre-exponential factor and apparent activation energy were found to be 5.66 × 10−4 mol/m2·s·Pa0.7 and 12.8 kJ/mol, respectively. Scanning Electron Microscope (SEM) and X-ray diffraction (XRD) analyses were performed on both pristine and used membranes, and no strong evidence of the formation of Pd-O or any other undesirable phases was observed. The permeation tests with pure hydrogen and inert gases indicate that the MR is highly selective toward hydrogen and the produced hydrogen is an ultrahigh purity grade. The carbon capture experiments in the work consists of dehydrating the retentate stream and redirecting it to a 13X packed bed before analyzing the stream via mass spectrometry. The carbon capture studies reveal that approximately 5.96 mmole CO2 (or 262.25 mg of CO2)can be captured per g of 13X. In this study, SEM-EDS, and XRD technics have been used to characterize the crystallography and morphology of the membrane surface. These material characterization techniques reveal that the surface of the membrane has gone through significant oxidation during the steam methane reforming reaction, although this oxidation is only limited to the few nanometers of depth through the surface of the palladium membrane.

The development of high capacity factor solar power plants is an interesting topic, especially when considering the climate and economic conditions of a location such as the Chilean Atacama Desert. The hybridisation of solar photovoltaic (PV) and concentrating solar power (CSP) technologies for such an application is a promising collaboration. The low cost of PV and dispatchability of CSP, integrated with thermal energy storage (TES), has the promise of delivering baseload electricity at a lower cost than what could be achieved with CSP alone. Therefore, the objective of this work was to evaluate whether or not a hybrid PV-CSP plant is more economically viable, than CSP alone or hybrid PV-diesel, for baseload generation. To analyse this hypothesis, a techno-economic optimisation study of a PV-CSP hybrid plant with battery storage and fossil fuel backup was performed. In doing so, a methodology for the identification of optimum solar hybrid plant configurations, given current technology and costs, to best satisfy specific location weather and economic conditions was developed. Building on existing models, for the PV and CSP components, and developing models for further hybridisation, a complete PV-CSP model was created that could satisfy a baseload demand. Multi-objective optimisations were performed to identify optimal trade-offs between conflicting technical, economic and environmental performance indicators. For the given economic and technical assumptions, CSP hybridised with fossil fuel backup was shown to provide electricity at the lowest cost and have the lowest project capital expenditure. This configuration showed a 42% and 52% reduction in the levelised cost of electricity in comparison to CSP alone and hybrid PV-diesel, respectively. It also provides a 45% reduction in CAPEX in comparison to CSP alone. PV-CSP integration increases capital costs and the cost of electricity, but reduced the use of fossil fuel backup and thereby reduced emissions, when compared to CSP with fossil fuel backup. However PV-CSP showed a 97% reduction in CO2 emissions when compared to hybrid PV-diesel. Furthermore, it showed a 35% and 46% reduction in LCOE in comparison to CSP alone and hybrid PV-diesel.