In conjunction with Sweden's goal of reducing emissions and dependence on fossil fuels in the transport sector, hydrogen technology has received considerable attention. Today, several studies are being carried out into hydrogen technology that focus on developing the production, application, storage and distribution of hydrogen. Energimyndigheten is investigating various strategies for hydrogen development to increase hydrogen production, develop green transports and opportunities for energy storage in Sweden. This study is about estimating the potential for hydrogen in heavy-duty vehicles in Västerås and investigating various possibilities for local hydrogen production. Gasification plants with capacities of 1, 5 and 10 MW are studied to analyze the gasification plant's design, operating conditions, costs and investment profitability. In addition, it is investigating the possibility of building a hydrogen filling station with hydrogen produced by an electrolysis plant in Rocklunda. For the electrolysis plant in Rocklunda, alkaline electrolysis from Nel Hydrogen (A150 and A300) with a power of 660 and 1320 kW and a daily production of 320 and 640 kg of hydrogen respectively are investigated. The electrolysis is connected to the electricity grid and the PV system in Rocklunda, while waste heat from the electrolysis is used to balance the district heating network.   The results of this study show that the potential for hydrogen can vary depending on the number of heavy hydrogen-powered vehicles, the mileage and the depreciation period. Different scenarios are discussed to get an estimation of what the development of hydrogen demand may look like. For a long-term scenario with high hydrogen demand, hydrogen production with a gasification plant is considered suitable. The total investment costs are estimated at 2.3, 4.7 and 7.7 million euros for 1, 5 and 10 MW plants. The production cost for each plant is estimated at 3.45, 2.28 and 2.12 euros per kg of hydrogen. The results also show that efficiency and costs for operation and maintenance are factors that have the greatest impact on production costs. For the net present value, efficiency and sales price are two factors that constitute the greatest impact.  For the A150 and a hydrogen filling station with a storage capacity of 400 kg per day, the total investment cost is estimated at 2.5 million euros. For the A300 and a hydrogen filling station with a capacity of 800 kg per day, the total investment cost amounts to 4.7 million euros. MATLAB is used to optimize hydrogen production that meets the estimated hydrogen demand and minimize costs in Rocklunda. The production cost per kg of hydrogen is estimated at 8 and 7 euros for the A150 and A300. For the electrolysis plant, the results show that the price of electricity has the greatest impact on the production cost, while the net present value is most affected by the electricity price and sales price for hydrogen. Furthermore, the results show that approximately 70% of the annual hydrogen production takes place with the electricity grid between 21 and 05 when the electricity price is low, which means that the hydrogen is not classified as green hydrogen.   The conclusion that has been drawn in this study is that hydrogen enables the electrification of heavy-duty vehicles with long driving distances. In 2024, it is expected that there will be the possibility of selling produced green hydrogen to build hydrogen filling stations in Sweden. Hydrogen production with an electrolysis plant in Rocklunda is a suitable method that can meet the hydrogen demand in the short term. However, this means higher costs for one kg of produced hydrogen.   To produce green hydrogen, green electricity from local electricity grid must be used in the electrolysis. Increased capacity on the PV system in Rocklunda is an alternative for increasing the proportion of green hydrogen. Hydrogen production with a gasification plant entails high investment costs but is suitable for large-scale production, which means that a high demand in the market is required to ensure investment profitability.

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.