Electricity Exports Research Articles

Biomass-Driven Polygeneration Coupled to Power-to-X: An Energy and Economic Comparison Between On-Site Electric Vehicle Charging and Hydrogen Production

The power-to-X strategy for passenger car applications offers a viable solution for using the surplus electrical power from renewable energy sources instead of exporting it to the grid. The innovative system proposed in this study allocates surplus electrical power from a building-integrated biomass-based Combined Cooling Heating and Power (CCHP) system to on-site applications and evaluates the energetic and economic benefits. The system comprises two key components: a 50 kW electric vehicle (EV) charging station for EVs and a 50 kW alkaline electrolyzer system for on-site hydrogen production, which is later dispensed to fuel cell electric vehicles (FCEVs). The primary goal is to decrease the surplus of electricity exports while simultaneously encouraging sustainable transportation. The system’s economic viability is assessed through two scenarios of fuel (e.g., biomass) supply costs (e.g., with and without fuel market costs) and compared to the conventional approach of exporting the excess power. The key findings of this work include a substantial reduction in surplus electricity exports, with only 3.7% allocated for EV charging and 31.5% for hydrogen production. The simple payback period (SPB) is notably reduced, enhancing economic viability. Sensitivity analysis identifies the optimal hydrogen system, featuring a 120 kW electrolyzer and a 37 kg daily hydrogen demand. The results underscore the importance of prioritizing self-consumed energy over exports to the national grid, thereby supporting integrated renewable energy solutions that enhance local energy utilization and promote sustainable transportation initiatives.

Spatial national multi-period long-term energy and carbon planning scenarios in Ecuador’s electric system

The Republic of Ecuador is developing a comprehensive plan to meet the increasing residential, industrial, and commercial energy demands. With a population of 17.08 million in 2018, the country is experiencing an annual average energy growth of approximately 7.13% until 2027. This research aims to model the incorporation of new and proposed power plants strategically planned to cater to the expanding demand needs. Ensuring that our existing energy infrastructure can adequately meet the current and growing needs of the residential, commercial, and industrial sectors should be made possible. In this paper, we present several hypotheses that need to be made to identify the potential demands for residential, industrial, and commercial requirements, making it more accessible to build new facilities that use renewable energy. Traditional and unconventional renewable energy sources, such as hydro-power, wind, and solar power, are being explored to generate electricity. The research employs quantitative methodology, beginning with gathering information and a detailed data analysis. Subsequently, a scenario-based model will examine the impact on energy demand and supply from 2020 to 2035. The results show that the Santiago hydroelectric project is becoming essential for the country’s energy development and that the current national power system will only be able to supply the electricity demand when the industrial city of Posorja is being developed. We suggest that to maintain Ecuador’s electricity trade balance as an electricity exporter, we continue with the energy investment plans currently issued by the Ministry of Energy and Mines. This study is relevant for establishing global financing arrangements involving the public and private sectors. In doing so, we can meet our hypothetical scenarios, ensuring that all energy needs are met by 2035. This will involve developing a robust national grid system with sufficient reserve capacity, meeting residential and projected commercial and industrial demand.

Finding opportunity in economic power dispatch: Saving fuels without impacting retail electricity prices in fuel-producing countries

In many oil- and natural gas-producing countries, fuels are allocated to the electricity sector at administratively set prices below international market prices for domestic policy reasons. This article shows that dispatching power units based on the opportunity costs of domestically used fuels can yield significant efficiencies, while end-user electricity prices can continue to reflect administratively set fuel prices. In addition, opportunity cost dispatch can bring environmental benefits when it results in switching the priority of oil and gas units in the merit order and facilitating investments in renewable energy. Therefore, this approach can support long-term net-zero emission targets. It can also resolve cross-border electricity trading issues faced by fuel-rich countries, which are reluctant to base their electricity exports on domestic fuel prices.

Developing hydrogen energy hubs: The role of H2 prices, wind power and infrastructure investments in Northern Norway

Hydrogen is seen as a key energy carrier to reduce CO2 emissions. Two main production options for hydrogen with low CO2 intensity are water electrolysis and natural gas reforming with Carbon Capture and Storage, known as green and blue hydrogen. Northern Norway has a surplus of renewable energy and natural gas availability from the Barents Sea, which can be used to produce hydrogen. However, exports are challenging due to the large distances to markets and lack of energy infrastructure. This study explores the profitability of hydrogen exports from this Arctic region. It considers necessary investments in hydrogen technology and capacity expansions of wind farms and the power grid. Various scenarios are investigated with different assumptions for investment decisions. The critical question is how exogenous factors shape future regional hydrogen production and export. The results show that production for global export may be profitable above 90 €/MWh, excluding costs for storage and transport, with blue hydrogen being cheaper than green. Depending on the assumptions, a combination of liquid hydrogen and ammonia export might be optimal for seaborne transport. Exports to Sweden can be profitable at prices above 60 €/MWh, transported by pipelines. Expanding power generation capacity can be crucial, and electricity and hydrogen exports are unlikely to co-exist.

Day-ahead optimal scheduling considering thermal and electrical energy management in smart homes with photovoltaic–thermal systems

The environmental impact on the energy sector has become a significant concern, necessitating the implementation of Home Energy Management Systems (HEMS) to enhance the energy efficiency of buildings, reduce costs and greenhouse gas emissions, and ensure user comfort. This paper presents a novel approach to provide optimal day-ahead energy management plans in smart homes with Photovoltaic/Thermal (PVT) systems, aiming to achieve a balance between energy cost and user comfort. This multi-objective problem employs the Non-dominated Sorting Genetic Algorithm III as the optimization algorithm and the Nonlinear Auto-regressive with External Input to forecast the day-ahead meteorological variables, which serve as inputs to predict the PVT electrical and heat production in the thermal resistance model. The HEMS benefits from the time-of-use tariff due to the flexibility provided by the energy storage from a battery bank and a boiler. Furthermore, it performs a load scheduling for 10 controllable loads based on three feature parameters to characterize occupant behavior. A study case analysis revealed a cost reduction of approximately 66% in the solution close to the knee of the Pareto curve (S3 solution). The environmental impact on the energy sector has become a The PVT heat production was sufficient to meet the thermal demand of the showers. The proposed hybrid battery management model effectively eliminated the export of electricity to the grid, reducing consumption during peak periods and the maximum peak demand.

An integrated system dynamics model of electricity production, consumption, and export policy in Iran considering carbon emissions

The electricity industry is a cornerstone of modern economies, requiring accurate forecasting to facilitate informed decision-making aligned with sustainable development goals. This study employs a novel, comprehensive system dynamics model comprising four subsystems: consumption, production, carbon emissions, and electricity trading. Our analysis reveals significant trends in Iran's electricity industry. The household sector is projected to become the largest energy consumer, with anticipated reductions in consumer sector subsidies over time. By 2040, total electricity production is forecasted to reach 862,835 million kWh, with renewable sources contributing only 3.3 percent. This trajectory is accompanied by a substantial increase in carbon emissions, reaching 448,383 tons, an alarming 2.6-fold surge compared to 2020. The private sector is anticipated to account for 70 percent of these emissions. Given the findings, prioritizing renewable electricity sources becomes imperative to align with sustainable development goals. Utilizing this integrated model, stakeholders can formulate informed strategies and interventions to navigate the evolving landscape of Iran's electricity sector.

The REPowerEU policy’s impact on the Nordic power system

Energy system models provide us with scenarios for the future energy system, supporting our understanding of the impact of societal changes and adopted policies. To front-load the EU’Fit for 55’ package for 2030 and targets of replacing imported natural gas with renewable electricity, the Nordic countries could contribute by exporting additional electricity to mainland Europe. This paper describes a comparative study including five energy system models – GENeSYS-MOD, ON-TIMES, IFE-TIMES-Norway, highRES, and IntERACT, exploring two decarbonisation scenarios leading up to 2050. The scenarios involved simulating an additional 30 TWh electricity export requirement from 2030. Key findings include Denmark and Norway emerging as major net exporters, with Denmark covering over 60% of the additional export. The models predict that 76%–82% of the new electricity production will come from wind power, split between onshore and offshore installations, highlighting significant investment requirements. These results underscore the Nordic countries’ capacity to support the EU’s renewable energy targets, with wind power being pivotal. This research offers a broad overview over different modelling tools and their behaviour and provides critical insights for policymakers, stressing the need for coordinated Nordic efforts to maximise the benefits of increased electricity exports while ensuring energy system stability and cost-efficiency.

System flexibility in the context of transition towards a net-zero sector-coupled renewable energy system—case study of Germany

To integrate variable renewable energy sources into the energy system and achieve net-zero emissions, the flexible operation of the power system is essential. Options that provide flexibility include electrolysis, demand side management, import and export of electricity, and flexible power plants. However, the interplay of these flexibility options in a renewable energy system with highly interacting energy and end-use sectors (known as sector coupling) is not yet fully understood. The aim of this paper is to improve the understanding of energy flexibility from a system perspective by explaining which flexibility options can provide how much flexibility and when are they operated. The analysis of the hourly results of the sector-coupled, long-term energy system model REMod shows that in times with high renewable electricity production, sector coupling technologies, specifically electrolysis and power-to-heat, dominate the annual flexibility shares. On the other hand, in times with low renewable production and high non-flexible demand, combined and open cycle gas turbines and electricity imports dominate in winter, while discharging electricity storage technologies dominate in summer. The operation of short-term electricity storage aligns in particular with photovoltaic production, while the operation of electrolysis is especially aligned to wind production. Non-flexible demand variations are driving the operation of combined and open cycle gas turbines and electricity imports. The results emphasize the pivotal role of flexibility, highlighting the need for efficient surplus electricity utilization and sector coupling. The results further suggest that it is crucial to establish market conditions that facilitate the flexible operation of various technologies in order to achieve economic efficiency.

Benchmarking and contribution analysis of carbon emission reduction for renewable power systems considering multi-factor coupling

The renewable power system serves as a vital path towards achieving carbon peaking and neutrality goals. Accurately quantifying the carbon reduction emissions of renewable power systems and evaluating the contribution of various influencing factors to carbon reduction is quite important, which is related to the formulation of energy policies and regional power planning by the power grid or relevant departments. However, in the current research, there are few studies related to the quantification of carbon emission reduction, and in terms of optimal scheduling, the existing studies often only consider a single factor, ignoring the coupling effect between multiple factors, which makes the contribution of each optimization strategy to carbon emission reduction unclear. Therefore, based on the current power system scheduling mechanism and dual-carbon background, this paper optimizes the carbon emission reduction benchmark factor and its corresponding weight, proposes a new carbon emission reduction benchmark of renewable power system, and verifies the accuracy of this benchmark based on the classical scheduling model. On this basis, the mathematical models of thermal power deep peak shaving (DPS), electricity export (ELE) and green certificate trading (GCT) are established. Each factor is introduced into the classical scheduling model to simulate and verify the promoting effect of each influencing factor on carbon emission reduction. Finally, the above different influencing factors were constructed in different coupling scenarios to calculate the carbon emission reduction under each scenario, and the contribution degree of each influencing factor to carbon emission reduction was analyzed sharply according to the value of cooperation game instead of the traditional calculation method. The results show that the proposed benchmark can reduce the error by 2.6%–15.5 %. In the carbon emission reduction contribution simulation, the three factors have coupling effects, and deep peak shaving and electricity export are more sensitive to carbon emission reduction contribution. This study provides valuable insights for the development of carbon reduction strategies for renewable power systems.

A hybrid method of system dynamics and design of experiments for investigating the economic and environmental indicators of electricity industry

Electricity plays a pivotal role in the socio-economic development of nations. However, heavy reliance on fossil fuels for electricity generation, as observed in Iran, poses significant environmental challenges. This study proposes a novel hybrid methodology that combines system dynamics modeling and Design of Experiments (DOE) to examine economic and environmental indicators within Iran's electricity sector. The system dynamics model delineates four key subsystems: consumption, production, CO2 emissions, and power trade. By integrating DOE into this framework, various economic and environmental metrics are assessed for the year 2040. Through a comprehensive analysis of variable impacts on these indicators, optimal levels are identified to achieve favorable outcomes. Notably, variables such as the allocation coefficient of export income to capacity development and electricity export price emerge as critical determinants. Due to economic, environmental, and economic-environmental indicators, the most appropriate level of allocation of export income towards capacity development is estimated at 30, 10, and 20 percent, respectively. The study recommends allocating 80 % of the capacity development budget to renewable energy sources and 20 % to thermal power plants to optimize future conditions. In business as usual, the Export CO2 emission damage to export income index will be 0.19. In implementing the proposed scenario, according to the economic-environmental index, this value will decrease and reach 1.73E-06, which indicates the improvement of electricity export from the economic-environmental dimension. This research underscores the importance of balancing economic prosperity with environmental sustainability in electricity industry planning and policy formulation.

Wind Power Integration and Challenges in Low Wind Zones. A Study Case: Albania

High wind performance systems are influenced by many factors such as site wind resources and configuration, technical wind turbine features and many financial conditions. Scenario planning and modelling activities often focus on restricted parameters and numbers to justify wind power plant performance. To better understand possible pathways to scaling up the distributed wind market in Albania, a deep and multidimensional calculations based on Monte Carlo analysis, using RETScreen and wind JEDI model, to assess socio-economic impact as a function of turbine output power, operating and maintenance cost and many other financial inputs by testing different WT (i.e., VESTAS, GAMESA, W2E and NORDEX) with rated power from 3.45 MW up to 4.5MW applied on LCOE, NPV, SPP, equity payback, B-C, after-tax IRR on equity and effects of GHG credits extended at a sensitivity range of ±35% is scientifically performed. From the simulation results LCOE reaches a minimal value of €43.48/MWh, if the debt rate is 99 % and a debt interest rate of 5.0%, a TotCapEx of €828/MW (-35 % less expenditures) indexed as the best scenario. For the base case scenario LCOE results €62.79/MWh, when applying a debt rate of 80% and a TotCapEx of (€1274/MW), while in the worst-case scenario LCOE impart a maximal value of €87.63/MWh if a TotCapEx of €1720/MW (+35 % more expenditures) and a share of 52 % debt rate is applied. Local annual economic impact (m€) during construction period and operating period evaluated in the wind JEDI model result around m€ 89.92 and m€ 23.54, respectively. As a conclusion, wind power plants (WPP), installed in low wind zones (Albania and many other EU countries) would be of interest if an electricity export rate of 110€/MWh, and a GHG credit rate of €50/tCO2 were accepted.

Time-frequency connectedness between electricity prices in Romania and its determinants in the competitive markets

PurposeIn this paper, we aim to provide an extensive analysis to understand how various factors influence electricity prices in competitive markets, focusing on the day-ahead electricity market in Romania.Design/methodology/approachOur study period began in January 2019, before the COVID-19 pandemic, and continued for several months after the onset of the war in Ukraine. During this time, we also consider other challenges like reduced market competitiveness, droughts and water scarcity. Our initial dataset comprises diverse variables: prices of essential energy sources (like gas and oil), Danube River water levels (indicating hydrological conditions), economic indicators (such as inflation and interest rates), total energy consumption and production in Romania and a breakdown of energy generation by source (coal, gas, hydro, oil, nuclear and renewable energy sources) from various data sources. Additionally, we included carbon certificate prices and data on electricity import, export and other related variables. This dataset was collected via application programming interface (API) and web scraping, and then synchronized by date and hour.FindingsWe discover that the competitiveness significantly affected electricity prices in Romania. Furthermore, our study of electricity price trends and their determinants revealed indicators of economic health in 2019 and 2020. However, from 2021 onwards, signs of a potential economic crisis began to emerge, characterized by changes in the normal relationships between prices and quantities, among other factors. Thus, our analysis suggests that electricity prices could serve as a predictive index for economic crises. Overall, the Granger causality findings from 2019 to 2022 offer valuable insights into the factors driving energy market dynamics in Romania, highlighting the importance of economic policies, fuel costs and environmental regulations in shaping these dynamics.Originality/valueWe combine principal component analysis (PCA) to reduce the dataset’s dimensionality. Following this, we use continuous wavelet transform (CWT) to explore frequency-domain relationships between electricity price and quantity in the day-ahead market (DAM) and the components derived from PCA. Our research also delves into the competitiveness level in the DAM from January 2019 to August 2022, analyzing the Herfindahl-Hirschman index (HHI).

COMPRENSIÓN DEL MERCADO ENERGÉTICO ESPAÑOL 2022 CON UN ANÁLISIS DE LOS DATOS OFICIALES

The energy situation that occurred in the Spanish electricity and natural gas markets in 2022 implies the concept of a global crisis. This entails a significant increase in the prices of electricity and natural gas. Historically, the relationship between these two concepts has always been substantial, as demonstrated in the conducted study. This article aims to analyze whether this relationship between both markets has continued to be strong in the past year, 2022, and to assess the factors that may have distorted the results. To achieve this, publicly available data recorded by various operators in the electricity and natural gas markets have been meticulously analyzed and reviewed from a statistical-mathematical perspective. The study investigates the implications of the rising prices of electricity and natural gas, as well as the measures taken by the Spanish Government in June 2022. Furthermore, it is essential to consider that in 2022, several anomalous factors occurred, such as the Russia-Ukraine war and the Spanish market intervention resulting from the price increases, suggesting a different market behavior. The primary conclusion drawn from the analysis of the published data is that the high prices in 2022 can be attributed not solely to the high prices of natural gas, as indicated in the media. This will be elaborated upon throughout this study. Key Words: Gas Cap Adjustment Mechanism, Massive Consumption of natural gas and exports of electricity in 2022. Correlation between OMIE and MIBGAS.

The role of Niger’s uranium supply to France’s electricity export potential in Europe

This article examines the role of stability of Niger uranium supply to France for the volume of electricity export to Europe, as well as the possible role of Russia in resolving the uranium deficit for nuclear power plants in France. France is considered one of the world’s largest producers and exporters of nuclear energy. For more than 50 years, one of the main suppliers of uranium to France has been its former colony, represented by Niger. Due to the events of 27 July 2023 in the Niger, there is a high risk of a complete cut in the supply of Niger uranium to France, which threatens the energy security not only of France, but of all its neighbors: Germany, the United Kingdom, Spain, Italy, Switzerland and others. Also in this work, the statistical data on uranium shipments from other countries to France are analyzed, the possible risks associated with the changing political situation in the African region are predicted and various measures are presented, which could be taken to mitigate the impact of the disruption of uranium supplies from the Niger to France’s nuclear sector.

Assessment of the feasibility of Aku small hydropower project using RETscreen Energy Model Software

The RETScreen 4 software was used in this study to conduct the analysis to determine the viability of the river Aku hydropower plant in Uturu, Abia State. The study was carried out using data from Ivo river dam authority, previous studies and literatures. The result of the study showed that the Aku river could generate an annual energy of 6,434,000kWh and will be able to payback its project cost at 6.3 years. The estimated annual GHG reduction of the project stood at 4,310.7tCo2 an equivalent of 1,852,317 litres of gasoline not used. The sensitivity/risk analysis indicated that electricity export rate (electricity sales price), initial cost and debt interest rate impacted the project profitability the most in that order. The project NPV is sensitive to both the debt interest rate and the initial cost of the project as variation in cost above 30% will throw the project into a negative NPV. In the light of the available information, the project is feasible if implemented.

Flexing with lines or pipes: Techno-economic comparison of renewable electricity import options for European research facilities.

Where local resources for renewable electricity are scarce or insufficient, long-distance electricity imports will be required in the future. Even across long distances, the variable availability of renewable energy sources needs to be managed for which dedicated storage options are usually considered. Other alternatives could be demand-side flexibility and concentrated solar power with integrated thermal energy storage. Here their influence on the cost of imported electricity is explored. Using a techno-economic linear capacity optimization, exports of renewable electricity from Morocco and Tunisia to CERN in Geneva, Switzerland in the context of large research facilities are modeled. Two different energy supply chains are considered, direct imports of electricity by HVDC transmission lines, and indirect imports using H2 pipelines subsequent electricity generation. The results show that direct electricity exports ranging from 58 EUR/MWh to 106 EUR/MWh are the more economical option compared to indirect H2-based exports ranging from 157 EUR/MWh to 201 EUR/MWh. Both demand-side flexibility and CSP with TES offer significant opportunities to reduce the costs of imports, with demand-side flexibility able to reduce costs for imported electricity by up to 45%. Research institutions in Central Europe could initiate and strengthen electricity export-import partnerships with North Africa to take on a leading role in Europe's energy transition and to secure for themselves a long-term, sustainable electricity supply at plannable costs.

Economic policy uncertainty, intra-industry trade, and China's mechanical and electrical product exports.

Economic policy uncertainty has had an important impact on trade and sustainable economic development. Especially in some specific industries, uncertainty has increased dramatically. The extant related literature mainly analyzes the nexus between uncertainty and trade across different industries and focuses less on a specific industry. Using Chinese customs data on HS 8-digit products over the period of 2000-2013, this paper first investigates the impact of both foreign economic policy uncertainty (EPU) and domestic intra-industry trade on China's mechanical and electrical product exports to 23 trading partners and applies pooled OLS regressions to conduct an empirical study. This paper finds that EPU has a significant inhibition effect on mechanical and electrical product exports; conversely, intra-industry trade can both significantly promote exports and alleviate the inhibition effect of EPU. In addition, the export impact of EPU varied with different trade patterns. It can significantly inhibit processing exports, while it has no effect on ordinary exports. The results of this paper indicate that in the context of increasing uncertainty, our findings could have far-reaching policy implications for China to build a new development pattern of domestic and international dual circulation.

Analysis of Power Generation and Transmission from Very Large-Scale Photovoltaic Systems in Algeria

In addition to the well-recognised two values of vast land and sunshine of Algeria, its Sahara desert has the third value, energy production and export. Subsequently, Algeria can then become a role model to other countries in the world that has huge solar and energy feedstock. In this article, a particular attention is being given to the Algerian Sahara in terms of solar potential capability in that it could capture enough solar energy to meet the total energy needs for sustainable development of Algeria, Sahara cultivation and Repopulation and electricity Export to Europe using Very Large Scale- Photovoltaic (VLS-PV) system. Moreover, the article is also concerned with studying the energy transmission losses from the generation site, in depth Sahara of the south of the country, to the north as well to European countries. A rough calculation of the Losses was made for a transmission overhead line of 400 kV three-phases, 1000 MVA using ALMELEC cable of 1600 mm2. The calculated losses results were found to be 15% per 1000 km. The optimal location to start the installation of VLS PV systems is proposed.

Analysing Opportunities and Obstacles in Ethio-Djibouti Relations: Post-Cold War Era Historical Analysis

This study explores the post-Cold War relationship between Ethiopia and Djibouti, with a focus on events after war era 1990. It investigates their historical connection, Djibouti’s separation from Ethiopia, and the impact of geopolitical dynamics and other factors on their relationship. Historical methods and qualitative research are used to gather and analyze data. The origins of their relationship date back to ancient times when Djibouti was part of Ethiopia before being occupied by the French. After French occupation and post-liberation period, several treaties were signed between the rulers of both countries, but changes in transportation and other challenges altered their relationship. After the Cold War, their relationship reached its peak due to Ethiopia’s dependence on Djibouti as a gateway to the sea, especially after the Ethio-Eritrean war. Military and security cooperation between the two countries was facilitated by global competition for military bases in Djibouti, border conflicts with Eritrea, and joint anti-terrorism initiatives. However, peace agreements between Ethiopia and Eritrea, as well as growing relations with Somaliland, could create additional port options for Ethiopia which could potentially affect Djibouti’s income in the future. Differences in opinion on Somalia’s reunification and irredentism among Somalis may pose challenges for both countries. Additionally, global warming and desertification in Africa could affect water and electricity exports from Ethiopia to Djibouti. Despite these challenges, both countries have benefited from their relationship. In conclusion, this study provides insight into the historical development of Ethiopia and Djibouti’s relationship since the Cold War, highlighting the various factors that have influenced their dynamics. It is a valuable resource for understanding the complexities and potential future developments in their relationship.

Public support and opposition toward floating offshore wind power development in Norway

For countries like Norway, with abundant offshore wind resources and deep seas, floating wind power technology can play an essential role in the green energy transition. However, this technology is still immature, and the first utility-scale floating offshore wind power projects need substantial support for technology development to be commercially feasible. This study employs an online survey targeting the general population in Norway (N = 1011) to investigate support and opposition toward floating offshore wind power development. The survey includes a discrete choice experiment focusing on policy-relevant factors such as the export of electricity, reducing domestic carbon emissions by electrifying offshore oil and gas platforms, impact on global technology cost trends, and involving domestic offshore industries as key players in the floating offshore wind sector. We find the highest support for developing projects that utilize technology from domestic offshore industries and projects connected to the domestic electricity grid. Projects aimed at reducing domestic carbon emissions by electrifying offshore oil and gas platforms are favored over those for exporting electricity to other countries. A significant impact on future technology costs does not lead to increased support for the project. Projects presented after a framing text focusing on meeting future electricity demand result in a higher willingness to pay for floating offshore wind projects than those presented after a framing text focusing on meeting climate objectives. Respondents opposing all the projects are likely climate skeptics and believe that project developers should bear all the project costs. Norway is expected to play a critical role in developing floating wind power. However, the Norwegians demand clear national benefits to be willing to shoulder the cost of spearheading the floating offshore wind power development. Understanding these preferences is vital for crafting energy policies aligning with public interests and rapidly integrating floating wind power into the green energy transition.