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To successfully transition towards fully renewable energy systems, energy sectors that today are primarily autonomous should be closely integrated to increase system flexibility and maximise synergy from effective sector coupling. Heat pumps are one of the sector coupling technologies which enable a mutual integration of power and heat sectors. Heat pumps are viewed as a low-cost source of sustainable heat for both space heating and industrial processes. However, representation of heat pumps in energy system models is typically oversimplified by using a uniform coefficient of performance, which limits perception of the hourly temperature changes on heat pump efficiency, or by using generic heat pumps for all individual residential, district, or industrial heat supplies. The LUT Energy System Transition Model was expanded to examine the impact of utilisation of hourly coefficient of performance profiles and specific heat pumps for different applications. The results indicate that, in cold climate countries, the use of hourly coefficient of performance profiles has little impact on the heat supply structure and overall primary energy demand, but has a noticeable impact on the electricity supply and energy storage system. Though the cost of the optimised system stays on the same level, application of hourly COP profiles leads to a more accurate simulation of electricity consumption and energy storage operation. The separation of district and industrial heat pumps leads to a higher share of heat pumps in industrial heat supply and allows for a reduction in overall energy system primary energy demand by 1.8%. • Use of generic HP in energy system modelling leads to underestimation of HPs capacity. • Applying uniform COP values from literature may lead to energy demand undervaluation. • Considering hourly COP does not substantially change system cost or efficiency. • Use of hourly COP leads to changes in electricity supply and storage systems. [ABSTRACT FROM AUTHOR]

• A cost-optimized transition towards 100 % renewable energy is modelled for Finland to 2050. • Power, heat and transport sectors are modelled in high temporal and geographic resolutions. • Prosumers can self-generate up to 26 % of final electricity consumption by 2050. • Levelized cost of energy decreases with adoption of low-cost renewable energy and storage. • Combined heat and power plant capacity would reduce outside of industrial applications. A cost-optimised transition pathway towards 100 % renewable energy was simulated for Finland. This transition was consistent with EU and international targets to achieve sstainability, while maintaining national competitiveness. Finland was divided into 7 regions that account for resource distribution and demand differences at high spatial and hourly time resolutions. Results indicate that levelised cost of electricity can decrease from 61 €/MWh in 2015 to 53 €/MWh in 2050 and that levelised cost of heat can decrease from 29 €/MWh to 20 €/MWh based on the assumptions used in this study. Transport sector costs decrease for most vehicle classes through electrification but increase marginally for classes that use bioenergy-based or sustainable synthetic fuels. Costs decrease through the adoption of flexible generation by several renewable energy technologies, intra-regional interconnections, and the use of low-cost energy storage solutions. Results show less need for combined heat and power plants as the electrification increases through sector integration. Individuals and groups can become prosumers of energy, motivated by a desire to contribute to climate action and making choices for lower cost, sustainable energy. Collectively, society can increase a sense of agency through lower exposure to risks. A 100 % renewable energy system can be a resilient, low cost and low risk option for the future. [ABSTRACT FROM AUTHOR]

Ammonia is a key chemical for the agriculture and chemical industries, and a potential future marine fuel. Potential growth in ammonia demand further highlights the importance of ammonia production defossilisation to comply with climate goals. Widely available renewable resources and declining costs of solar photovoltaics and wind power enable the production of green e-ammonia at many locations and potential exports to countries with less optimal resources and other restrictions. This paper aims to compare the cost of imported e-ammonia to Germany, Finland, and Spain from regions with excellent renewable resources, Morocco and Chile, to the cost of local production, and to quantify potential economic savings due to trading. Transportation costs are calculated in this study with techno-economic parameters reported in detail to assess their impact on final import costs, and to allow comparison of shipping costs to pipeline transmission costs over various distances. Pipeline imports from Morocco were found to be significantly higher in cost compared to imports by sea from Chile and Morocco or local production. Imports from Chile were found to be economically feasible for Germany and Finland, with import costs 10–33% lower than domestic e-ammonia production in 2030–2050. Imports to Spain may be attractive in 2030s, but, after 2040, local solar resources enable local e-ammonia production costs at the same or lower cost as imported e-ammonia. Ammonia trading in the future may depend on access to the sea. Other factors such as creation of jobs, additional revenues, and energy security concerns may also impact e-ammonia trade. • Imports of green e-ammonia are feasible for Germany and Finland, but not for Spain. • Imported e-ammonia is 10–33% lower in cost in Germany and Finland in 2030 • In 2050, imports are 12–33% lower in cost in Germany and Finland than local supply. • Shipping e-ammonia is more economical for medium and long distances. [ABSTRACT FROM AUTHOR]

• Imported green e-H 2 is more expensive than e-H 2 produced in Germany and Finland. • Local supply of e-H 2 found to be more economical across all scenarios and years. • Transportation costs constitute 29–63% of the total imported e-H 2 cost. • Pipeline transmission may be cheaper than shipping for distances of 2000–2500 km. Widely available and low-cost solar photovoltaics and wind power can enable production of renewable electricity-based hydrogen at many locations throughout the world. Hydrogen is expected to emerge as an important energy carrier constituting some of the final energy demand; however, its most important role will be as feedstock for further processing to e-fuels, e-chemicals, and e-steel. Apart from meeting their own hydrogen demand, countries may have opportunities to export hydrogen to countries with area limitations or higher production costs. This paper assesses the feasibility of e-hydrogen imports to Germany and Finland from two case regions with a high availability of low-cost renewable electricity, Chile and Morocco, in comparison to domestic supply. Special attention is paid to the transport infrastructure, which has a crucial impact on the economic viability of imports via two routes, shipping and pipelines. This study has found that despite lower e-hydrogen production costs in Morocco and Chile compared to Germany and Finland, additional transportation costs make imports of e-hydrogen economically unattractive. In early 2020s, imported fuel costs are 39–79% and 34–100% higher than e-hydrogen produced in Germany and Finland, respectively. In 2050, imported e-hydrogen is projected to be 39–70% more expensive than locally produced e-hydrogen in Germany and 43–54% in the case of Finland. e-Hydrogen may become a fuel that is mostly produced domestically and may be feasible for imports only in specific locations. Local e-hydrogen production may also lower dependence on imports, enhance energy security, and add jobs. [ABSTRACT FROM AUTHOR]