At the beginning of 2025, Norway’s power supply had an installed production capacity of 40 334 MW, with an estimated normal annual production of around 157 TWh. The year 2024 set a new record with electricity production of 157.2 TWh, while 2023 had a total production of 154 TWh. In contrast, 2022 was marked by low precipitation and reduced inflow, resulting in a total electricity production of 146.1 TWh.

Installed production capacity refers to the maximum output a power plant or power system can produce, while normal annual production refers to the amount of electricity expected to be produced in a year with normal weather conditions.

Hydropower

Hydropower is the backbone of the Norwegian power system. Today, 1,791 hydropower plants account for approximately 88 percent of Norway’s total normal annual electricity production. As of the beginning of 2025, the total installed capacity for Norwegian hydropower was 33,947 MW.

Water inflow and installed production capacity form the basis for what Norwegian hydropower can produce. The amount of inflow varies significantly throughout the year and from year to year. The water inflow is highest during the spring, normally declines towards the end of summer but increases again during the autumn. Inflow is generally very low in the winter months.

The hydropower system had a normal annual production of 137.6 TWh at the start of 2025. This figure is calculated by NVE and is based on observed inflow data over a longer period. The reference period used is 1991–2020.

Norway currently has around 1 100 water reservoirs with a total storage capacity of over 87 TWh. Approximately half of this storage capacity is covered by the 30 largest reservoirs. Most of the reservoirs were built before 1990. Upgrades and expansions of the power plants have improved the ability to utilize these reservoirs.

By using storage reservoirs, flexible hydropower plants can produce electricity even in periods when there is little precipitation and inflow is low. The large available reservoir storage capacity makes it possible to even out production over years, seasons, weeks and days, within the constraints set by the licence and the watercourse itself.

Production of intermittent hydropower automatically varies with changes in water inflow. Production is high during spring and summer, when consumption is lowest.

The flexibility of power plants and reservoirs varies. Some hydropower plants with small reservoirs offer short-term flexibility, and can transfer production from base-load hours (at night) to peak-load hours (daytime). Hydropower plants with larger reservoirs can store water for longer periods so that they produce electricity in winter, when consumption and prices are highest. Norway’s largest reservoir, Blåsjø, has a capacity of 7.8 TWh and can hold three years’ normal inflow. However, when the hydropower plants are working at full capacity, the reservoir could be emptied in 7–8 months. Very large reservoirs like Blåsjø are intended to store water in years when precipitation is high for use in drier years. Much of Norway’s reservoir capacity is concentrated in the mountains in the southern half of the country (in the counties Telemark, Rogaland, Hordaland and Sogn og Fjordane), and further north in Nordland.

Reservoirs make it possible to manage water use to maximise income from the available water resources. For society as a whole, the aim is to spread production so as to make optimal use of water inflow over the year, or in some cases over several years. To ensure that this happens, there must be financial incentives for producers that reflect the underlying physical conditions. The market therefore plays an important part in ensuring efficient management of water stored in the reservoirs.

Wind power

As of the beginning of 2025, there were 65 wind farms in Norway with a total of 1 392 turbines. These wind farms had a combined installed capacity of 5 082 MW and a normal annual production of 15.9 TWh. This accounts for approximately 11 percent of Norway’s total electricity production capacity. Electricity generation from wind power varies with weather conditions. Wind conditions can fluctuate significantly from day to day, week to week, and month to month. Wind power development peaked in 2020, when 5.3 TWh of new capacity was commissioned across 18 wind farms.

Offshore wind

The government aims to contribute to the development of new industries on the Norwegian continental shelf and is following up on its ambitions for offshore wind. Through its focus on offshore wind, the authorities want to promote increased emissions-free power production in Norway. The initiative also aims to facilitate innovation and technology development and contribute to industrial growth.

In 2020, Southern North Sea II and Utsira Nord were opened as the first areas on the Norwegian continental shelf for renewable offshore energy production. Southern North Sea II is located at the very southern end of the North Sea, near the border with Denmark. The area is suitable for fixed-bottom offshore wind. Utsira Nord is located in deeper waters off the coast of Rogaland and is best suited for floating offshore wind.

In March 2024, Norway held its first offshore wind auction. The auction concerned a project area in Southern North Sea II. The company Ventyr SN II AS won the auction. Ventyr is a consortium owned by Parkwind and the Ingka Group. The company will be granted the project area and thus a time-limited exclusive right to carry out a project-specific environmental impact assessment and to apply for a concession under the Offshore Energy Act. The state will support the project with up to NOK 23 billion (2023 kroner). The support will be provided through a two-way contract for difference with a 15-year duration from the start of production.

In May 2025, the Ministry of Energy announced the opening of Utsira Nord, which will be Norway’s first large-scale floating offshore wind project. The application deadline was September 15, 2025, and the ministry received two applications. Actors awarded areas will have the opportunity to further develop their projects during a maturation phase before participating in a competition for state support. The state support will be provided as investment grants and cannot exceed a cost framework of NOK 35 billion (2025 kroner).

The further development of offshore wind depends on access to suitable areas. In June 2025, NVE submitted a strategic environmental impact assessment of areas suitable for offshore wind. The assessment was sent out for public consultation, and based on the report and feedback from the consultation, the government will prepare a plan for the future development of offshore wind.

Solar power

As of the beginning of 2025, the total installed capacity for solar power in Norway was 767 MW. In 2023, over 90 percent of the solar power capacity was connected to the Norwegian power grid. Around 5 percent of solar installations in Norway had an installed capacity of more than 50 kW in 2023. These accounted for approximately half of the total production capacity of solar installations in the country.  Most solar installations are rooftop systems installed on private homes and industrial buildings, primarily covering the owners' own electricity consumption. In recent years, there has been growing interest in ground-mounted solar power plants.

Thermal power plants

Norway’s thermal power plants accounted for about 1.5% of the total production capacity in 2025. Many of the power plants are located in large industrial installations that use the electricity generated themselves. Hence, production often depends on the electricity needs of the industry. These power plants use a variety of energy sources, including municipal waste, industrial waste, surplus heat, oil, natural gas and coal. There are 30 thermal power plants in Norway, with a total installed capacity of about 538 MW.

The power balance

The power balance expresses the relationship between production and consumption and indicates whether the Norwegian power system is a net exporter or importer in a particular year. There are wide variations from year to year. Generally, consumption fluctuates with temperature and production with water inflow and wind conditions. The underlying situation in the Norwegian power supply system can be illustrated by comparing Norwegian production capacity in a normal year with electricity consumption corrected for temperature, as in the figure below.

At the beginning of the 1990s, there was a considerable surplus in the Norwegian power supply system, which became apparent when the market was deregulated. This was followed by a period of falling investments in new electricity production and relatively high growth in consumption, resulting in a reduction in the power surplus by the early 2000s. After the 2008–2009 financial crisis, the power surplus has increased again as a result of weaker growth in consumption and higher electricity production. In 2024 Norway had a power surplus of 18 TWh, which is a historically large surplus of power. At the same time, there is uncertainty about how this surplus will develop in the coming years. This depends on consumption trends and the extent to which new power production will be realized in Norway.

Supply and demand

Norway has a cold climate, and a large part of its energy consumption is used for heating. Unlike most other countries, the dominant source for heating is electricity. The high proportion of electric heating can put pressure on the power supply during cold periods.

Households account for about half of the total energy consumption used for heating and cooling in Norway. The industry accounts for about 25 percent, while the service sector accounts for just under 25 percent.

District heating

In 2024, 6.8 TWh of district heating was delivered to end users. District heating can be produced using many different types of fuels. Waste incineration accounted for approximately 38.2 percent of district heating production in 2024, while facilities using solid biofuels covered 28.9 percent. The use of fossil fuels for district heating production has decreased in recent years.

District heating primarily supplies larger buildings. About 53.7 percent of district heating consumption in 2024 took place in buildings within the service sector, such as hospitals, cultural, educational, and office buildings. District heating is also used in households and industry.

District heating interacts well with the power supply. If district heating can replace electricity consumption in winter, this can reduce the need for investments in the power system. Some district heating plants can also use electricity when power prices are low and switch to other energy carriers when prices are high.

District cooling

District cooling involves supplying cold water through pipes for cooling purposes. The water supplied is typically pumped from the sea, lakes, or rivers. Although district cooling has been growing in Norway for some time, its usage remains relatively low. In 2024, district cooling consumption was 185 GWh. The service sector accounts for most of the district cooling consumption, while the rest is used in industry.

There are approximately 20 district heating companies in Norway that provide district cooling. The majority of district cooling production comes from cooling plants based on heat pumps.

Heat pumps

Over one million heat pumps have been installed in Norway. Most of these are air-to-air heat pumps in households, while a significant number of larger heat pumps are installed in commercial buildings and in the industry. According to the Norwegian Water Resources and Energy Directorate (NVE), 21,9 TWh of heat was produced by heat pumps in 2024, with an electricity consumption of 9,5 TWh.

Bioenergy

Bioenergy is an important energy source for the production of heat in Norway. It contributes  to energy flexibility and reduction of greenhouse gas emissions. Annual use of bioenergy in Norway has increased from about 9,1 TWh in 1990 to 17,6 TWh in 2024 Wood burning in households accounts for a large share, with just over 6,5 TWh in 2022.

Surplus heat

Industry, data centers, and cooling facilities often generate heat as a byproduct. This is commonly referred to as waste heat or surplus heat. Surplus heat is thermal energy in the form of air, water, steam, or exhaust gases at a higher temperature than the surroundings, which is not utilized for the facility’s primary purpose and can therefore be used for other purposes.

The extent to which surplus heat can be utilized depends on the quality of the heat source, such as temperature level, availability, and quantity. Additionally, the available technology and customer base are decisive factors. The customer base is largely linked to the geographic location of the heat resources. From April 1, 2025, facilities with surplus heat (industry, data centers, etc.) are required to conduct cost-benefit analyses of the possibilities for utilizing this heat. To facilitate sustainable industrial development for data centers and energy-intensive industries, the Norwegian Water Resources and Energy Directorate (NVE) has established a heat map.

Petroleum products

From January 1, 2020, use of mineral oil (oil from fossil sources) for heating buildings has been prohibited. The purpose is to reduce emissions of greenhouse gases. The ban also includes the use of mineral oil for temporary heating of buildings under construction or renovation (construction heat).

Gas heating is very rare in Norway, with a limited domestic gas infrastructure. Since 2017, installing heating solutions based on any fossil fuel, including natural gas, in new buildings has been prohibited. Use of gas is mainly related to industrial activities.

The electricity grid is key infrastructure

The three fundamental functions of the power supply system are:

• Production
• Transmission
• Trade

A reliable supply of electricity is crucial in modern society. In business and industry, the public service sector and households, reliable access to electricity is a matter of course. Almost all important public services and functions depend on a well-functioning power system with a reliable supply of electricity.

Electricity production resources are often located far from where consumption takes place. A well-developed electricity grid makes it possible to transmit power from the hydropower plants in the southwest and north to consumers in other parts of Norway and abroad.

The grid must be able to cope with both short- and long-term variability in production and consumption in order to ensure that electricity supplies are maintained. The grid system is designed  to handle peaks in electricity consumption, which generally occur on the coldest days in cold years, and to allow for import of sufficient quantities of electricity for extended periods, for example in dry years. In addition, the grid must have sufficient capacity to transport electricity out of a region when consumption is low and production is high. The wide variations in domestic production and consumption make it necessary to have sufficient transmission capacity both between different regions of Norway and between Norway and other countries.

Administrative organisation of the electricity grid

Statnett owns the transmission grid in Norway, and is the transmission system operator (TSO). Statnett is a state-owned enterprise, and the Ministry of Energy is responsible for the state’s ownership. Municipalities and county authorities own most of the regional and distribution grids, but there is also some amount of private ownership.

Historically, many grid companies have been part of vertically integrated companies, i.e. companies that are involved in both electricity generation, transmission and/or trading. Today, regulatory provisions require that all grid companies undertake legal undbundling and grid companies with more than 100 000 customers undertake functional unbundling. This makes the distinction between market-based and monopoly activities clearer.

You can read more about regulation of grid operations here.

Statnett SF

Statnett is the only certified Transmission System Operator (TSO) for electricity in Norway and holds a monopoly on owning and operating the Norwegian transmission grid. Statnett is responsible for the economically efficient operation and development of the transmission system. In addition, Statnett owns and operates the interconnectors between Norway and other countries.

Statnett is a member of the European Network of Transmission System Operators for Electricity (ENTSO-E), which, among other things, plays a role in the development of European regulations for the internal energy market in the EU.

Electricity cannot easily be stored, so the amount produced must at all times equal consumption. Statnett has been granted a specific license delegating the authority to carry out system responsibility in the Norwegian power system, which entails ensuring that there is always an instantaneous balance between the production and consumption of electricity in Norway. The power market is an essential tool to ensure balance between electricity supply and demand. Statnett uses the results of daily price determination in the day-ahead market as the basis for planning and maintaining the instantaneous balance in the following 24-hour period. The continual process of balancing the electricity system is vital for the operational reliability of the power supply system. If an imbalance arises, the transmission system operator takes steps to restore the balance, for example by adjusting production or consumption.

As the system operator, Statnett is also responsible for submitting the amount of transmission capacity that will be made available to the market the day before the operational day. Previously, the capacity between price areas was calculated statically. Starting in autumn 2024, this will be done through so-called flow-based market coupling, where capacity is calculated dynamically based on actual flow patterns in the grid.

This means that more trading opportunities become available to the market, and the physical grid capacity can be utilized in a more flexible and economically efficient manner.

Power exchange

Norway's exchange capacity to other countries is approximately 9000 MW. This is distributed with 4000 MW to Sweden, 1400 MW to Germany, 1400 MW to the United Kingdom, 1600 MW to Denmark, and 700 MW to the Netherlands as of 2024. 9000 MW corresponds to a theoretical potential for power transmission of 80 TWh per year, but the historical utilization has been lower.

More information about interconnectors and cross-border electricity trading can be found here.

A market-based power system

The power market ensures that resources are used efficiently, that security of supply is maintained, and helps keep electricity from becoming more expensive than necessary.

An important principle in the regulation of the power system is the distinction between monopoly activities and activities suited for competition. The Energy Act forms the basis for the free buying and selling of electricity and a strictly regulated grid operation.

Electricity differs from other goods in that it is less suited for storage. There must always be an exact balance between production and consumption.

In the wholesale market, large volumes of electricity are bought and sold, and this is where the price is determined for each individual 15-minute interval in the following day. Pricing is based on the supply and demand from many market participants, given the available grid capacity.
Short-term market adjustments ensure that the cheapest production resources are used first. Furthermore, electricity prices send signals about power scarcity in the form of investment signals.

Transmission and distribution of electricity are natural monopolies, and competition is therefore not allowed in grid operations.

An integrated market

Norway is part of a joint Nordic power market with Sweden, Denmark, and Finland, which in turn is integrated into the European power market through interconnections to the Netherlands, Germany, the United Kingdom, the Baltic states, Poland, and Russia.

In Europe, efforts are underway to improve the internal energy market and to better connect the European markets. European market coupling has previously been based on voluntary cooperation and regional initiatives.

Market coupling takes place through an implicit auction, which means that prices and electricity flows between areas are calculated simultaneously in the day-ahead market. Market participants on different sides of national borders submit their bids to sell and buy for each 15-minute interval of the following day, without needing to reserve grid capacity in advance.

Organisation of the power market

Power supplied to the grid follows the laws of physics and flows down the path of least resistance. It is not possible to separate different power deliveries from each other. A consumer who switches on the power has no way of knowing who produced the electricity or how far it has been transported through the grid. The grid companies keep account of how much power each producer delivers and how much each end user consumes, and this forms the basis for settlement. Producers are paid for the volume of power they deliver, and end users pay for their consumption.

The power market can be divided into wholesale and end-user markets. Large volumes are bought and sold in the wholesale market by power producers, brokers, power suppliers, energy companies and large industrial customers. Power suppliers trade on behalf of small and medium-sized end users and small-scale businesses and industry.

The wholesale market consists of several markets where bids are submitted and where prices are determined:

• the day-ahead market
• the continuous intraday market
• the balancing markets

Day-ahead and intraday trading take place on organized marketplaces (power exchanges).

The balancing markets are operated by Statnett, which has been granted a license to exercise system responsibility. To ensure the instantaneous balance in the power system, Statnett uses the balancing markets to regulate consumption and production up or down, depending on the imbalance. Market participants can also enter into bilateral contracts for the purchase and sale of electricity at agreed prices, volumes, and delivery periods.

In the end-user market, individual consumers enter into agreements to purchase electricity from a supplier of their choice. In Norway, the end-user market consists of roughly one-third household customers, one-third industry, and one-third medium-sized end users, such as hotels and retail chains.

The wholesale market

The day-ahead and intraday markets

The day-ahead market is the main market for electricity trading in the Nordic region, where most volumes are traded. In the day-ahead market, contracts are traded for the delivery of physical electricity for each 15-minute interval of the following day. Previously, this was based on hourly intervals, but starting in 2025, the market has transitioned to 15-minute resolution, in line with European requirements and the need for more precise balance between production and consumption. This transition provides more detailed price and volume signals and is intended to facilitate better integration of weather-dependent power production and flexible resources.

Market participants submit their bids to sell and buy into the power exchange’s trading system between 8:00 AM and 12:00 PM. Before 10:00 AM, the system operator (Statnett) allocates transmission capacity to the market for each bidding area. The auction closes at 12:00 PM. Based on the incoming buy and sell bids and the available transmission capacity, prices are calculated for each 15-minute interval of the next day.

The Nordic day-ahead market is linked with day-ahead markets across much of Europe through what is known as an implicit auction. This means that participants bid on energy and transmission capacity simultaneously. The Nordic power market is also price-coupled with large parts of Europe (PCR). Price coupling means that Nord Pool calculates electricity prices in the various areas using a common European price algorithm, at the same time every day.

The balance between supply and demand is largely ensured in the day-ahead market. However, events can occur after the day-ahead auction, such as changed weather forecasts, that cause participants’ actual production or consumption to differ from their positions in the day-ahead market.

In the intraday market, trading takes place continuously from the clearing of the day-ahead market until one hour before the operating hour. This allows participants to trade themselves into balance if they see that actual production or consumption differs from their declared position in the day-ahead market. The transition to 15-minute resolution also applies in the intraday market and gives participants better opportunities to balance their positions if actual production or consumption deviates from the plan.

Balancing markets

Although the day-ahead and intraday markets create a balance between production and consumption leading up to the operating hour, there will still be unforeseen events that disturb the balance during the operating hour. As the system operator, Statnett is responsible for ensuring that the power system is balanced at all times. To secure this instantaneous balance, Statnett uses the balancing markets to purchase flexibility so that consumption and production can be regulated up or down depending on the imbalance.

In the Nordics, the balancing markets are divided into fast frequency reserves (FFR), primary reserves (FCR), secondary reserves (aFRR), and tertiary reserves (mFRR). The power system is balanced at a frequency of 50 Hz. Fast frequency reserves, primary reserves, and secondary reserves are activated automatically in response to frequency changes. Previously, tertiary reserves were activated manually by the Nordic system operators, but from 2025 these will also be activated automatically.

Imbalances are first regulated using fast frequency reserves. These reserves are activated within approximately one second after a frequency change. A commercial market for acquiring FFR was established by Statnett in 2022. After that, primary regulation is used to stabilize the frequency change. Primary reserves are traded in a separate daily and weekly market for primary reserves. If imbalances persist for several minutes, secondary regulation takes over, freeing primary regulation resources to handle new imbalances. Previously, the Nordic system operators purchased secondary reserves in separate national weekly markets. In 2022, a joint Nordic capacity market for aFRR was launched.

If further needs arise, tertiary reserves are activated, known as mFRR (manual Frequency Restoration Reserve). mFRR frees up aFRR and is also used to avoid congestion in the grid. mFRR is the slowest and most energy-rich reserve, with a minimum bid size of 5 MW and an activation time of up to 12.5 minutes. Activation occurs every 15 minutes, in line with the transition to 15-minute resolution in balance settlement.

From 2025, the previous regulating power market is replaced by a new activation market for mFRR, called mFRR EAM (Energy Activation Market). This is a common Nordic market where bids are sorted in a shared list, and activation happens automatically based on forecasted imbalances in each price area. Statnett calculates the need for regulation every 15 minutes and sends the activation requirement to a common Nordic activation function, which selects bids and activates resources. Operators still have the possibility to intervene manually if needed, but this is exceptional.

mFRR EAM is based on the same algorithm as the European reserve trading platforms, MARI (mFRR) and PICASSO (aFRR). The Nordic TSOs will eventually connect to the European trading platforms.

To ensure sufficient balancing capacity, the capacity market for mFRR (mFRR CM) is used, which replaced the previous regulating power options market (RKOM) in 2024. In this market, providers are paid to make up- and down-regulation resources available, regardless of whether they are activated. Capacity from both production and consumption can be offered, and electricity-intensive industry contributes flexibility through rapid changes in consumption.

Price formation

System price

Every day, the power exchange Nord Pool calculates the system price for electricity for the upcoming day. The system price is a theoretical price, calculated based on the assumption that there are no transmission constraints (bottlenecks) in the Nordic transmission grid. The system price is the same for the entire Nordic market and serves as a reference price for price setting in the financial power market in the Nordic region.

Power price

Producers submit how much they wish to produce at a given price level. The bids reflect the value the producers assign to their production, which is largely related to the running production costs of the power plant. Buyers submit the amount of electricity they want to purchase at different price levels. The price is determined by the balance between supply and demand in the day-ahead market.

In market equilibrium, it is the cost of producing electricity in the "last" power unit, the marginal cost, that sets the price. This ensures that the cheapest energy resources are used, so that electricity demand is met at the lowest possible cost to society. The high exchange capacity with foreign countries means that the price level in Norway is largely influenced by the costs of producing electricity in thermal power plants, especially the price of coal, gas, and emission allowances. The amount of renewable production and consumption in the countries Norway is connected to also plays a role.

A large share of hydropower in the Norwegian and Swedish production mix means that variations in inflow to reservoirs have a significant effect on price fluctuations in the Nordic region. In periods of high inflow, there is a large supply of electricity, and prices are pushed down. In years with low rainfall and less inflow, prices increase. With a growing share of wind and solar power in the Nordic market, the same applies for periods with a lot or little wind and sun. Market prices are also influenced by temperature fluctuations, as these affect heating demand in households, among other things.

Bidding areas

In addition to the system price, the power exchanges calculate area prices that take into account bottlenecks in the transmission grid. The area prices are the prices that balance the purchase and sale bids from market participants within the different bidding areas in the Nordic region. In recent years, Norway has been divided into five bidding areas, Sweden into four areas, Denmark into two areas, while Finland consists of one area.

The reason bottlenecks and different electricity prices between areas can occur is that we have varying regional power situations, which can change from hour to hour and between seasons and years. Some regions may have a power surplus in one situation, while others have a deficit. In deficit areas, there is therefore a need to import electricity, while in surplus areas there is a need to export electricity. If there is insufficient transmission capacity to import and export this electricity, bottlenecks arise between the areas. In certain cases, this can lead to hours with negative electricity prices. This may occur, for example, due to significant rainfall combined with transmission capacity limitations out of the price areas.

When dividing into bidding areas, a market area is defined on each side of the bottleneck. This allows deficit areas to have an area price higher than the price in surplus areas. Electricity flows from areas with low prices to areas with high prices, which helps increase electricity supply where it is most needed. Furthermore, area prices provide signals to market participants about where it is most valuable to increase or reduce production and consumption. In areas with tight electricity supply, production increases while consumption decreases, improving electricity availability and supply security.

In addition to being an important tool for balancing the system in the short term, area prices help highlight the need for more long-term measures in the power system. Area prices signal to producers and consumers where it is most advantageous to locate new production or large new consumption.

Dividing into bidding areas does not automatically mean different area prices will occur. When there are no capacity constraints in the Nordic transmission grid, area prices are the same throughout the Nordic region and correspond to the system price.

The end-user market and electricity prices

Consumers who purchase power for their own consumption, are called end users. End users in Norway are free to choose their power supplier. Small end users normally purchase electricity from a power supplier, while larger end users, such as large industrial companies, often choose to purchase directly in the wholesale market or enter into a bilateral agreement with an electricity producer.

Power contracts

Electricity is a homogeneous product, meaning it is not possible to distinguish between different electricity deliveries. What differentiates electricity suppliers from each other are the electricity contracts they offer. Generally, end-users can choose between three main types of electricity contracts: fixed-price contracts, contracts with standard variable price, and contracts based on market price with a markup (spot price agreement).

A fixed-price contract is an agreement on a fixed price for electricity over a period, for example, one year. The supplier is then obligated to deliver electricity at the agreed price, regardless of what happens to the electricity price in the market. A fixed-price contract is therefore a type of financial contract where the customer is price-secured for the duration of the contract. Electricity suppliers set the fixed price based on expectations of the electricity price, in addition to a markup to cover costs. The difference between the fixed price and the expected market price during the period represents the risk premium for the price guarantee.

The price of the standard variable electricity price varies with developments in the electricity market. The standard variable price is also a form of financial contract but with a relatively short price guarantee period. The supplier is required to inform about price changes 30 days before they take effect.

Contracts based on market price with a markup are agreements where the price follows the market price set on Nord Pool. In addition to the market price, the customer must pay a markup. Such contracts are the closest households and smaller businesses get to the day-ahead market.

The Norwegian Consumer Council maintains a website, www.strompris.no, where it is possible to compare all the different contracts offered by electricity suppliers. This makes it easy for a consumer to find the most suitable contract.

Smart Electricity Meters (AMS)

All grid companies are required to ensure that smart electricity meters (AMS) are installed at every individual metering point. AMS provides consumers with better information about their own electricity consumption and more accurate billing so that customers are charged for their actual consumption. Electricity customers also gain better insight into their electricity usage and the ability to use electricity in a more flexible and efficient way. The vast majority of Norwegian electricity customers have now adopted a smart electricity meter. As of the third quarter of 2022, AMS meters with communication modules were installed at 98.8 percent of the metering points in the distribution network. The implementation of AMS is therefore considered complete in Norway. The remaining 1.2 % of metering points are either AMS meters without communication modules, older meters, or unmetered consumption points in the low-voltage network.

Financial power trading

Financial power trading includes trading with financial instruments used for risk management and speculation. All contracts are settled financially without any physical power deliveries. Financial products are often called long-term contracts because they apply to periods further ahead in time than those for physical products.

Financial power trading can take place either bilaterally or on a power exchange. In the Nordic countries, financial trading takes place mainly on the Nasdaq OMX Commodities AS (Nasdaq OMX) exchange. Nasdaq OMX has a license from the Financial Supervisory Authority of Norway, which is also the supervisory authority for the marketplace. At Nasdaq OMX, players can hedge prices for purchase and sale of power for up to six years ahead, split by days, weeks, months, quarters and years.

Financial products include future and forward contracts, electricity price area differentials (EPAD) and options.

Nasdaq OMX Clearing AB (Nasdaq Clearing) is the clearing house for the financial contracts on Nasdaq OMX. Nasdaq Clearing has a license from the Swedish Financial Supervisory Authority. Clearing activities make an important contribution to operational efficiency in the Nordic power market. Nasdaq Clearing acts as the counterparty in all financial trading on Nasdaq OMX. Bilateral financial agreements can also be cleared. This eliminates the counterparty risk for the participants.

Norwegian power trading

Norway has had transmission connections to foreign countries since 1960, when the first connection to Sweden was built. Since then, connections have been established to Denmark, Finland, Russia, the Netherlands, Germany, and the United Kingdom. Norway has been a net exporter in 19 of the last 25 years. The period from the mid-1990s to the mid-2000s was characterized by several years of net power imports more than before. Over the last ten years, the power balance has improved, and Norway has had an average net export of approximately 14 TWh per year.

In 2024, total power exports amounted to 33.1 TWh, with power imports of 14.7 TWh. This results in a net electricity export of 18.4 TWh. The net export was high due to good inflow to the reservoirs and capacity upgrades in the grid, in addition to relatively high prices in Europe. Except for 2019, there has been net export every year since 2010.

Norway’s exchange capacity with foreign countries is approximately 9,000 MW. This is distributed as about 4,000 MW to Sweden, 1,400 MW to Germany, 1,400 MW to the United Kingdom, 1,600 MW to Denmark, and 700 MW to the Netherlands. 9,000 MW corresponds to a theoretical potential for power transmission of 80 TWh per year, but actual utilization is much lower.

Security of electricity supply is vital for a modern society, and requires a smoothly functioning power market. The market plays a key role in maintaining a constant balance between production and consumption. Both production-side and demand-side flexibility have a positive effect on security of supply, as do hydropower storage reservoirs and foreign trade in power. In addition, there must be a power grid with adequate transmission capacity.

Energy security in the power system

Hydropower accounts for most of the Norwegian power supplies, and the resource base for production depends on the precipitation in a given year. This is a significant difference for the rest of Europe where security of supply is mainly secured through thermal power plants, with fuels available in the energy markets.

By using storage reservoirs, flexible hydropower plants can produce electricity even in periods when there is little precipitation and inflow is low. The large storage capacity makes it possible to even out production over years, seasons, weeks and days, within the constraints set by the licence and the watercourse itself.

Norway has a sound power balance and high power trading capacity, and therefore enjoys high energy security in the power system. Nevertheless, low water inflow and events outside Norway can make the situation difficult at times.

Statnett is responsible for developing measures to deal with highly strained power situations energy situations. These are known as ‘SAKS’ measures, and their purpose is to reduce the likelihood of rationing.

The Energy Act includes rules on electricity rationing, including enforced reductions of supply and requisitioning. Rationing can be introduced if required by extraordinary circumstances. The Norwegian Water Resources and Energy Directorate is the rationing authority and is responsible for planning and administration of any measures needed in connection with electricity rationing. The Directorate has issued regulations relating to rationing.

Adequacy

Electricity consumption means the amount of electricity used over time; electricity consumption at a specific moment in time is called the load. The power balance shows the relationship between the electricity supply and consumption at a particular moment. Although the load fluctuates with temperature, it has also shown a rising trend in line with the general rise in electricity consumption. In 1990, the maximum load in the Norwegian system was 18.42 GW. On 12 February 2021, a new consumption record was registered, and the load reached 25 230 MW in the morning (09:00–10:00). Thus, the peak load has risen since 1990, and has risen more rapidly than electricity consumption. This trend is expected to continue.

Satisfactory security of supply requires a power grid with adequate transmission capacity. To ensure that electricity supplies can be maintained in all circumstances, the grid system must be able to cope with both short- and long-term variability in production and consumption. It must be designed both to handle peaks in electricity consumption, which generally occur on the coldest days in cold years, and to allow for import of sufficient quantities of electricity for extended periods, for example in dry years.

To ensure security of supply, investments in the transmission grid are normally planned on the basis that a failure of one component in the system should not result in the interruption of supplies to end users (this is known as the N-1 criterion). However, this criterion is not a replacement for the cost-benefit analyses that are carried out when specific power lines are being planned. More information on how investments in the grid are planned can be found here.

Operational security

Operational security is concerned with avoiding interruptions to continuous operation of the power system right down to a time horizon of minutes and seconds. Faults in power lines, substations and control systems can affect operational security and result in service interruptions. There are various reasons why components of the system may fail, but weather-related incidents are an important reason for interruptions. You can read more about this below.

Statnett is responsible for coordinating the operation of the power supply system, capacity calculation, dealing with congestion, and facilitating power trade with other countries. As TSO, it must also take steps to ensure that the power market is efficient and that the quality of supply is satisfactory. The continual process of balancing the electricity system is vital for operational reliability. If an imbalance arises, the TSO takes steps to restore the balance, for example by adjusting production or consumption.

Electricity cannot easily be stored, so production must equal consumption at all times. This is called the instantaneous balance in the electricity system. The power market is an essential tool for maintaining the balance between electricity supply and demand. Statnett uses the results of daily price determination in the day-ahead market as the basis for planning and maintaining the instantaneous balance in the following 24-hour period.

The system frequency is a measure of the instantaneous balance in the power system, and is the same throughout the Nordic synchronous area, which comprises Norway, Sweden, Finland and parts of Denmark. The nominal system frequency is 50 Hertz (Hz), with a normal range of 49.9–50.1 Hz. The common system frequency means that an imbalance anywhere the synchronous area will affect the whole area. In addition, one country’s choices as regards grid investments, market solutions and operational security measures will affect the entire synchronous system. This makes it essential for the Nordic countries to cooperate closely.

Frequency quality can be measured using frequency deviations expressed as the number of minutes outside the normal variation range of 49.9–50.1 Hz. Frequency deviations can be caused by faults, imbalances related to changes in flow along interconnectors, or sudden changes in electricity production. To ensure that the instantaneous balance is maintained and prevent sudden changes or faults from causing frequency deviations or even power cuts, the TSO need to have reserves available. Reserves are often provided by flexible hydropower plants, where production can be regulated up or down to stabilise the system. To maintain operational security, TSOs must be able to access sufficient reserves through the balancing markets.

Many problems that can arise in the power system as a whole can also affect distribution grids. As people use electricity for more and more purposes, vulnerability to power cuts and problems related to quality of supply are increasing. For example, appliances such as induction hobs that draw more power are becoming increasingly popular, and more electricity produced from intermittent sources is being fed into lower grid levels. These trends are making operation of the distribution grid more challenging.

Investments in the distribution grid and measures to prevent the interruptions are important for security of supply. New technological and market solutions can also make the power supply system more resilient in future. You can read more about technological developments in the power supply system here.

Continuity of supply and interruptions

The continuity of the electricity supply is depends on both the frequency and the duration of interruptions in the supply. In Norway, continuity of supply is stable and very good, and is close to 99.99 % in years without extreme weather events. It has never dropped below 99.96 % in any year since 1996, see the figure below.

Extreme weather events affect continuity of supply. In the figure, this is particularly obvious in 2011, when a winter storm caused a great deal of disruption because the high winds brought trees down on power lines.

In 2017, end users experienced an average of 1.6 brief and 1,7 longer power cuts. Longer power cuts are defined as those lasting more than three minutes. Important causes of power cuts are thunderstorms (lightning), wind causing trees or other vegetation to fall over power lines, and snow/ice on power lines. Various steps can be taken to reduce weather-related disruption of this kind. Maintaining a cleared corridor along power lines in forested areas reduces the risk of trees falling over the lines. Using underground cables is another possibility, and this is now the first choice for new power lines in the distribution grid in Norway.

It is not possible to provide 100 % continuity of the electricity supply. This would require an unreasonable level of investment in infrastructure, and for the same reason, no legal requirements have been introduced to provide 100 % continuity. Customers who are dependent on uninterrupted supplies must therefore ensure that they have emergency back-up power such as generators. Thus, society’s vulnerability to disruption of the power supply also depends on end user emergency preparedness.

Emergency preparedness in the power sector

Emergency preparedness in the power sector has become increasingly important as society grows more and more dependent on electricity. It is important both to take steps to prevent the disruption of supplies and to provide a rapid response if disruption does occur.

Requirements for the emergency preparedness system are set out in the Energy Act and the security and emergency planning regulations. There are rules on the resources that must be available for repairs, security measures, information security, protection of operational control systems and the Power Supply Preparedness Organisation.

The Power Supply Preparedness Organisation is responsible for restoring power supplies in an emergency. It is headed by the Norwegian Water Resources and Energy Directorate and also includes representatives of Statnett, grid companies, major electricity producers and larger district heating companies, and regional representatives of the power supply sector.

Human life and health and critical infrastructure and services are the priorities when restoring power supplies. Power companies are required to have robust communication systems, for example independent systems that make it possible for them to communicate with each other even if there is no mobile phone signal. Each company has an independent responsibility for maintaining effective security and preparedness systems.

The Norwegian Water Resources and Energy Directorate the supervisory body and is responsible for raising awareness of the need for emergency preparedness in the sector and for offering advice and guidance, exercises/training and information.

The overall objectives of the legislation

Developing infrastructure for electricity production and transmission or for district heating plants and distribution networks can result in conflicts between user and environmental interests during planning, construction or operation. Conflicts may also arise in connection with water resources management. There may be impacts on biodiversity, landscapes and outdoor recreation, fishing, tourism, the cultural heritage, local communities, reindeer husbandry and so on. In the legislation, these are often referred to generically as “public interests”. Energy and river system projects may also affect private economic interests.

Norway’s legislation is intended to ensure that all the different interests are heard and considered, and that projects are subject to government control and conditions that safeguard different interests. Another important objective is to ensure effective management of our resources. Security of energy supply and a well-functioning power market are key considerations here.

Below you will find an overview of Norway’s legal framework for the energy sector and water resources management

Waterfall Rights Act

Before making use of water for electricity production, a developer must have ownership rights to the waterfall. A non-state developer must hold a licence under the Waterfall Rights Act in order to acquire such rights. The Act does not apply to small-scale power projects or run-of-river hydropower plants under the limit of 4000 natural horse powers. The overall purpose of the Waterfall Rights Act is to ensure that hydropower resources are managed in the country’s best interests through public ownership of hydropower resources at national, county and municipal levels.

Under the current rules, licences may only be issued to public bodies, i.e. state-owned enterprises, municipalities and county authorities, and to companies where such bodies hold at least two-thirds of the capital and the votes in the company. This means that private actors may own up to one-third of a company that holds a licence under the Waterfall Rights Act. Licences issued under the Act include conditions on licence fees and obligatory sales of power to the municipalities where waterfalls are situated.

Watercourse Regulation Act

To regulate flow in a river or transfer water between river systems for use in power generation above a certain threshold, a licence is required in accordance with the Watercourse Regulation Act. The Act also applies to run-of-river hydropower plants that generate more than 40 GWh per year. Licences set out the highest and lowest permitted water levels in reservoirs. Licences also include rules for reservoir drawdown, which may include provisions on the minimum permitted rate of flow and on the volumes of water that may be released at different times of year. In addition, licences may include conditions relating to licence fees and obligatory sales of power or conditions aiming to compensate or mitigate damage.

Water Resources Act

In addition to hydropower projects, many other types of developments may take place in river systems. The Water Resources Act applies to all of these, not just to hydropower developments. Examples include the abstraction of water for fish farms and the extraction of deposits (sand, gravel, etc.). Small-scale power projects smaller than 10 MW are also regulated by the Water Resources Act. Licences may include various conditions to ensure compensation for damage or to mitigate damage. Small-scale developments that are not expected to cause significant damage or nuisance to public interests do not require a licence under this Act.

Energy Act

The purpose of the 1990 Energy Act is to ensure that energy is generated, converted, transmitted, traded, distributed and used rationally and in the best interests of society. This includes taking into consideration any public and private interests that are affected. The Act provides a framework for competition in electricity generation and trading. The development and operation of the grid is a natural monopoly, and the Act provides the legal basis for regulating the grid companies. The Energy Act also regulates marketplaces for trade in electrical energy, cross-border interconnectors, district heating facilities, responsibility for system operation, electricity supply quality, energy planning and contingency planning for power supplies.

Developers must apply for licences under the Energy Act to construct wind and solar farms and high-voltage power lines. Distribution grid companies can obtain general local area licences. This means that they do not need to apply for a licence for each separate installation within an area.

Offshore Energy Act

The Offshore Energy Act provides the legal basis for offshore renewable energy production. The Norwegian state has the right to utilise offshore energy resources. The Act applies to Norway’s territorial sea outside the baselines and to the continental shelf, however individual provisions are also applicable to internal waters. A licence is required for electricity generation, conversion and transmission in areas covered by the Act. Licences can only be obtained after the central government authorities have decided to open specific areas for licence applications and held an auction for interested parties/bidders. An area can only be opened after the authorities have carried out a strategic environmental assessment. However, the authorities may exempt pilot projects and similar projects with a limited time frame from these requirements.

Electricity Certificate Act

The 2011 Electricity Certificate Act is intended to promote production of electricity from renewable energy sources up to 2020. It establishes a Norwegian market for electricity certificates, which was linked to the Swedish electricity certificate market from 1 January 2012. The electricity certificate market is a constructed market in the sense that the demand for certificates arises from a statutory obligation to purchase them. Sales of electricity certificates give power producers a supplementary income in addition to that derived from sales of electricity.

Other relevant legislation

In addition to legislation administered by the Ministry of Energy, a number of other acts and regulations are important for the management of energy and water resources. The EU Water Framework Directive (2000/60/EC) has been implemented in Norwegian law through the Water Management Regulations, which were adopted under the Pollution Control Act, the Planning and Building Act and the Water Resources Act. The regulations include provisions on river basin management plans, which are intended to maintain and improve the ecological status of rivers and lakes and coastal waters.

Energy production and transmission infrastructure can have impacts on biodiversity, and developments must be assessed according to the principles set out in the Nature Diversity Act. This Act applies to all sectors during the exercise of public authority when the decisions being made may have environmental impacts. The Act is intended to ensure that Norwegian nature is protected through conservation and sustainable use, and that the environment can continue to provide a basis for human activity. The Act includes provisions on priority species, selected habitat types and area-based protection, which must be considered when developing energy production and transmission infrastructure.

The Planning and Building Act applies to a large extent in parallel with the energy and water resources legislation, but there are some important exceptions. Many of the provisions of the Planning and Building Act do not apply to the transmission grid, but an environmental impact assessment (EIA) is required in the usual way. The EIA regulations include specific provisions on projects that require licences. The Technical Regulations for buildings, also adopted under the Planning and Building Act, set out energy requirements for buildings.

A power project developer that does not have the necessary rights to establish and operate installations in a river system may apply for the expropriation of these property rights in accordance with the Expropriation Act. Where appropriate, the provisions of the Cultural Heritage Act, the Pollution Control Act and the Reindeer Husbandry Act must also be taken into consideration during the licensing process for energy projects and other projects in river systems. The Reindeer Husbandry Act is intended to maintain reindeer husbandry as an important basis for Sami culture, in accordance with the Norwegian Constitution and the provisions of international law on indigenous peoples and minorities.

The Public Administration Act sets out general provisions for administrative procedures in the public sector, including how cases should be prepared and how to deal with appeals against individual decisions. These rules apply in addition to the specific rules set out in the legislation on energy and river systems.

The licensing authorities

The licensing authorities are responsible for processing licence applications and issuing licences. They include the Storting (Norwegian parliament), the Norwegian Government (formally the King in Council), the Ministry of Energy, the Norwegian Water Resources and Energy Directorate as well as municipalities. The text below describes licensing procedures for hydropower projects under the Watercourse Regulation Act and the Water Resources Act, and for electrical installations under the Energy Act.

Licensing procedures under the water resources legislation

There are some differences between the licensing procedures for large- and small-scale hydropower projects. Small-scale projects are defined as power plants that require a licence under the Water Resources Act and have an installed capacity of less than 10 MW, but do not involve regulation of the rate of flow in a river exceeding the limit that triggers licensing requirements under the Watercourse Regulation Act. Large-scale projects are power plants that require a licence under the Water Resources Act and have an installed capacity greater than 10 MW, and projects that regulate the rate of flow in a river and require a licence under the Watercourse Regulation Act.

The Norwegian Water Resources and Energy Directorate has prepared guidelines (in Norwegian only) for the administrative procedures for a number of different types of installations in river systems. These include aquaculture facilities, the construction of small power plants, upgrades and renovation of existing power plants, construction in or across river systems, gravel pits and flood protection measures.

Large-scale hydropower projects

The King in Council formally awards licences for projects dealt with under the Watercourse Regulation Act and for projects with an installed capacity exceeding 10 MW that require a licence under the Water Resources Act. The Norwegian Water Resources and Energy Directorate is responsible for procedures during the application phase.

In addition, under Norway’s regulations on environmental impact assessment (EIA), an EIA is mandatory for power plants with an annual production exceeding 40 GWh. For other installations, an EIA is required if the project may have significant effects on the environment and society. Norway has two sets of regulations that implement EU rules on environmental impact assessment. Hydropower projects come under the Regulations relating to environmental impact assessment of projects under sectoral legislation (referred to as the EIA Regulations here).

If a project comes under Appendix II of the EIA Regulations, an EIA is not mandatory and the developer is not required to notify the authorities of the project. As a general rule, the ordinary licensing procedures under the Watercourse Regulation Act and the Water Resources Act are followed in such cases. If an EIA is found to be necessary, it must satisfy the requirements of Appendix IV of the EIA Regulations. The developer may be required to submit supplementary studies if the application does not provide sufficient information. The impacts of a project must be thoroughly described in the application even if no EIA is required under the Regulations.

If a project comes under Appendix I of the EIA Regulations, so that an EIA is mandatory, the Directorate will determine the final impact assessment programme after submitting it to the Ministry of Climate and Environment. The notification is made available for public inspection and local authorities and organisations are consulted on its contents. They also receive a copy of the final assessment programme for information purposes. Once an EIA is completed, the report is submitted together with the licence application.

Authorities, organisations and landowners that will be affected by the project are consulted on the application, and the EIA if one has been carried out. The Directorate makes an overall assessment of the project and submits a recommendation to the Ministry of Energy. The Ministry prepares the case for the Government (King in Council) and presents its recommendation. This is based on the application, the Directorate’s recommendations, the views of affected ministries and local authorities and the Ministry’s own assessments. The King in Council then makes a formal decision on the project in the form of a Royal Decree. If a project is particularly large (more than 20 000 natural horsepower) or controversial, the Storting is consulted and given an opportunity to debate the matter before a licence is formally awarded by the King in Council. The figure below illustrates the procedures.

Decisions to grant licences for major development projects cannot be appealed, as the licensing authority rests with the King in Council. Decisions to refuse licences are made by the Ministry of Energy and can be appealed to the King in Council.

Small-scale hydropower projects

Licensing authority for small-scale hydropower projects has been delegated to the Directorate. Small-scale projects are defined as power plants that require a licence under the Water Resources Act and have an installed capacity of less than 10 MW, but do not involve regulation of the rate of flow in a river exceeding the limit that triggers licensing requirements under the Watercourse Regulation Act. The procedures are simpler than those for large-scale projects, which also means that they can be processed more quickly.

In June 2007, the Ministry published guidelines for small hydropower plants. They describe how to draw up regional plans for small hydropower plants and how to ensure comprehensive assessment of applications and make licensing procedures more efficient and predictable.

For power plants of between 1 and 10 MW, a study of biodiversity that may be affected by the development is required. Pursuant to the rules of the Planning and Building Act, public notice of the application is given in the local media, it is made available public inspection, and authorities, organisations and landowners that will be affected are consulted. After this, an on-site inspection of the area is held before a decision is made.

Decisions by the Directorate may be appealed. If the Directorate upholds its decision, the appeal is sent to the Ministry, which deals with it under the normal rules of the Public Administration Act. The Ministry’s decision is final and cannot be appealed. The figure illustrates the procedures.

The municipalities are the licensing authority for power plants below 1 MW (mini and micro power plants), with the exception of projects in protected river systems. All applications for such power plants are therefore first sent to the Directorate to decide how the specific application is to be processed.

Licensing procedures under the Energy Act

Licensing authority

The Energy Act requires anyone who builds, owns or operates an installation for the production, transformation, transmission or distribution of electrical energy to hold a licence. This means that in addition to holding a licence for building a power plant, the developer must also hold a licence for the electric components in the facility under the Energy Act.

The Norwegian Water Resources and Energy Directorate is the licensing authority for electrical installations, except for new major power lines longer than 20 kilometres carrying a voltage of 300 kV or more, where the Government (King in Council) has the licensing authority. Before the King in Council makes a final decision, the Directorate will make a recommendation to The Ministry. Decisions made by the King in Council cannot be appealed. The Directorate’s decisions may be appealed to the Ministry of Energy.

The Licensing Process

For smaller and simpler cases, The Directorate can put the licensing case on a “fast track”. Fast track implies a quick process for handling well-prepared applications for projects that entail a minor or insignificant impact to public and private interests. For fast-track processing, the applicant must meet several requirements. These include consultations with relevant authorities and affected landowners and interest holders. The applicant must also complete an evaluation demonstrating that the potential damages are small, and a clarification with the owner adjacent grid infrastructure that the necessary capacity is available.

An applicant, for projects concerning 132 kV electrical power lines which is shorter than 15 km, does not have to send a notification before the application. See the figure above. The Directorate holds consultations and makes information available to stakeholders, and may also organise public meetings as part of the licensing procedure. The Directorate’s licensing decisions can be appealed. If the Directorate upholds its decision, the appeal is sent to the Ministry of Energy, which handle the case in according to the Public Administration Act. If necessary, and a part of the process, the Ministry may inspect the site before it makes a decision. The Ministry’s decision is final and cannot be appealed. Before the applicant can start the construction work, the Directorate shall approve a detailed plan for both the construction- and the operation phase.

All licence applications under the Energy Act require an environmental impact assessment (EIA) according to the EIA regulations. Projects that do not require a notification must still perform an EIA prior to the submission of the licence application. The EIA must be submitted together with the licence application.

Licence case that demands notification according to the EIA-regulation

New power lines longer than 15 km and carrying a voltage of 132 kV or more are required to send the government a notification together with a proposed programme for the EIA prior to the application stage. The notification of the project shall describe the visual impact of the grid infrastructure, the affected area and the consequences regarding the environment and society. The notification document shall also describe relevant and realistic alternatives, and how these alternatives shall be considered in the EIA. The applicant needs to present a proposal for programme of the EIA that describes the possible investigations and possible methodology. These documents will be part of a public hearing by the Directorate. Based on the proposal for the EIA-programme and the received testimonies of the hearing, the Directorate will decide on a final programme for the EIA. Then the process of the EIA can start and finally a submission of the licence application.

The Directorate will perform a public hearing of the application, inspect the area and hold public meetings. If Directorate’s decision is appealed, the appeal will be handled by the Ministry, as described above. After a licence has been awarded, the Directorate must approve a detailed plan before any construction can start.

New major power lines and governance of investment projects

Major power line projects are also subject to Norway’s rules for governance of investment projects. These rules were established in 2013. This involves a needs analysis and choice of concept, and external quality assurance to determine whether a project is viable. Full documentation of this procedure must be submitted to the Ministry, which decides whether a proposal can be submitted and the procedures described above can be started.

Processing time

Many factors affect the time spent on processing licence applications, for example the conflict level and complexity of the individual project. Hydropower and energy projects generally have impacts on commerce and industry, local communities, the environment and other user interests. The licensing authorities are responsible for ensuring that a project has been thoroughly assessed and described before a decision is made. They must also consider the need for additional studies of various topics and supplementary statements on issues raised during the licensing procedures. It is important to ensure that licence applications are properly and thoroughly assessed, and that procedures are as efficient as possible.

Regulation of grid operations

Electricity production and trading, are exposed to competition, and the Norwegian Energy Act is based on the principle that power trading should be market-based. Electricity transmission and distribution, on the other hand, is a natural monopoly. The fixed costs of grid development are high, and it is not rational to construct several competing grids. The grid operations are therefore not subject to competition; instead they are subject to monopoly control.

The authorities have established extensive control of monopoly operations to prevent the grid companies from exploiting their position. A licence under the Energy Act is required in order to construct, own and operate grid assets. Grid operations are regulated using a combination of direct regulation (specific requirements and obligations in licences) and incentive-based regulation in the form of a revenue cap. The overall purpose is to ensure that the operation, utilisation and development of the grid is rational and in the best interests of society.

The purpose of direct regulation is to ensure the necessary level of investment in the grid as well as satisfactory maintenance and operation. Further, the direct regulation shall ensure that all who require it are given access to the grid, that there is sufficient grid capacity and a satisfactory quality of supply, and that the security of supply is maintained in demanding situations.

Within the regulatory framework, the grid companies have considerable freedom to decide how to meet the requirements. The revenue cap regulation is intended to give the grid companies incentives to find cost-effective ways of meeting the requirements. This is important because a regulated monopoly whose costs are automatically covered will not necessarily have incentives to operate cost-effectively.

The Norwegian Energy Regulatory Authority (NVE-RME) sets an annual revenue cap for each grid company. The cap is set at a level that permits grid companies to earn revenues that over time cover the costs of grid operation and depreciation of the grid, and at the same time gives a reasonable return on invested capital, given efficient grid operation, utilisation and development. The design of the revenue cap regulation is intended to provide the grid companies with an acceptable financial framework, and simultaneously ensure that the grid tariffs are set at reasonable levels.

Grid companies earn most of their revenue from the grid tariffs. The grid companies are obliged to set the tariffs such that net earnings from grid operations over time do not exceed the permitted level.

The revenue cap regulation also gives grid companies incentives to maintain an optimal level of reliability of supply. In the event of power supply interruptions, grid companies’ permitted revenues are reduced by means of a quality-adjusted revenue cap for energy not supplied (known as the CENS/KILE scheme). Further, end users who experience power outages that last for more than 12 hours may claim compensation from the grid company.

In addition to the revenue cap and direct regulation, inspection and enforcement is of key importance. NVE-RME is the supervisory authority of grid operations, and may issue orders for compliance with regulations and licensing terms.

Grid tariffs

Grid customers pay point tariffs for the transmission and distribution of electricity. This means that the grid tariff is dependent on the location of the connection point. The tariffs are intended to cover a share of the costs that accrue at the relevant grid level as well as higher grid levels.

For consumers, this implies that the grid level to which one is connected affects the size of the tariff. Consumers connected directly to the transmission grid, pay a tariff based on the costs of operating the transmission grid. Therefore, they are charged less than customers connected to lower grid levels, who pay a share of the costs at the lower level as well as the transmission grid.

Electricity producers pay a fixed charge that does not depend on the grid level to which they are connected. In 2024 the transmission charge is 0.0149 NOK/kWh.

Distribution tariffs vary from one grid company to another. This is partly because the grid companies’ conditions vary and influence the cost of distributing electricity to the customer. Difficult natural conditions and a scattered settlement pattern can often result in high transmission costs. There is also some variation in the efficiency of grid operations between companies.

Grid companies are responsible for setting their own tariffs, but the national authorities set the general principles for the tariff design. Over time, the grid companies’ total tariff revenues must be within the permitted level set by NVE-RME. Grid tariffs must be objective and non-discriminatory, and they must be designed and differentiated based on relevant grid conditions. To the extent possible, tariffs should also be designed to provide long-term signals encouraging efficient utilisation and development of the grid.

Taxation of hydropower

Hydropower plants are subject to several different tax regimes to ensure that the public benefits from the use of natural resources. The sector is also unique in that the host municipalities for hydropower receive a significant share of the tax revenues.

Profits from electricity production are taxed as general income, in the same way as for other businesses. In addition, a resource rent (grunnrenteskatt) is levied on hydropower plants with generators of at least 10 MVA. Hydropower production often yields returns above normal levels because it relies on a limited natural resource. Such extraordinary returns are referred to as "resource rent," and the resource rent tax ensures that a portion of this profit is returned to society.

The resource rent tax is designed as a neutral tax, so that projects that are profitable before resource rent tax, are also profitable after resource rent tax. Hydropower plants with generators below 10 MVA are exempted from resource rent tax. The resource rent tax is calculated based on standardised market value of the power generated (actual power generated multiplied by spot market prices), less operating expenses, licence fees, property tax. As of 2021 the resource rent tax is designed as a cash flow tax, with immediate recognition of expenditures of investments. Investments prior to 2021 are subject to deduction through depreciation and uplift (return on investment). The uplift is used to compensate for investments prior to 2021 that are depreciated and will not be deducted immediately.

The resource rent can be positive, negative or zero. The resource rent is coordinated for companies who own several hydropower plants, which means that any negative resource rent in one hydropower plant is subtracted from positive resource rent from another hydropower plant. The resource rent tax is unlike other taxes in that tax value is paid out to companies if the resource rent is negative.

A natural resource tax of NOK 0.013 per kWh, paid to the municipalities and counties, is also levied on power plants rated at more than 10 MVA. Natural resource tax is deductible against the assessed tax on general income.

In addition, power producers normally pay property tax to the municipalities where their plants are situated. The property tax base is calculated according to specific rules for hydropower plants. The taxable value of a hydropower plant larger than 10 MVA is based on the plant's market value by estimation of an indefinite net present value calculation. However, the property tax base must be between a minimum of NOK 0.95 per kWh and a maximum of NOK 2.74 per kWh of the average production over a seven-year period at the plant in question. If a hydropower plant has been in operation for less than seven years, the period during which it has been operating is used as a basis. The property tax is deductible when calculating the economic rent. For hydropower plants smaller than 10 MVA, the property tax is calculated on the basis of the value of the investments.

Hydropower companies must also pay a licence fee and meet requirements for obligatory sales of power to the municipalities where their plants are situated, for more details see below.

Licence fees

Owners of large hydropower plants are required to pay a licence fee to the state and to the municipalities affected by the hydropower developments. The size of the fee depends on the theoretical capacity of the power plant and is calculated independently of the actual production capacity. The theoretical capacity is expressed in natural horsepower and calculated from the rate of flow after regulation and the head of water. The fee rates are adjusted every five year by NVE. In 2023, the municipalities and the state received about NOK 930 million in licence fees.

Obligatory sales of power

Owners of large hydropower plants are required to deliver power corresponding to up to 10 per cent of the theoretical capacity to the municipalities affected by the hydropower developments. The purpose of this arrangement is to ensure that municipalities where there are large-scale hydropower developments obtain electricity for general consumption at a reasonable price. If a municipality is entitled to more electricity than is used for general consumption, the county is entitled to buy the surplus. The parties are free to agree on the price of power sold through these arrangements. Unless otherwise agreed, the price is as a general principle based on production costs. For licences awarded after 10 April 1959, the Ministry of Energy calculates a price based on the average production costs for a representative selection of power plants. In 2025, this price is NOK 0.1289 per kWh.

Counties and municipalities receive about 8.8 TWh of electricity through these arrangements every year, about one-third of which currently goes to the counties. The difference between the price of electricity sold through these arrangements and the normal market price is a source of revenue for the municipalities and counties.

Taxation of onshore wind energy

The profits of electricity production are taxed as general income, in the same way as the profits of other businesses. A linear five-year depreciation rules were introduced in 2015. The rule applied to fixed assets acquired up to the end of the approval period for plants under the electricity certificate scheme, i.e. up to and including 31. December 2021.

Wind farms can be subjected to property tax by the municipality. Valuation of wind farms are set equal to technical value, equivalent to replacement costs less deduction of wear and tear and untimeliness. The wind farms can also be valued by return value if this reflects the valuation better. A production fee on onshore wind power was introduced as of July 1^st 2022. As of 2025 this fee is NOK 0,0237 per kWh. The fee is fiscal and paid directly to the state, but the income is redirected back to the municipalities through NVE.

Property tax of electricity grid

Valuation of grid assets is based on the legislation on municipal property tax. This means that the objective sales value must be used, and the valuation must be carried out by the municipalities. The valuation is based on the replacement value of the assets.

The EEA agreement

The EU’s energy policy framework aims to ensure a sustainable, competitive, and secure energy supply. Since the EEA Agreement came into force in 1994, the EU’s regulatory framework for the internal energy market has evolved, becoming more comprehensive over time.

The framework directly affects Norwegian stakeholders through the EEA Agreement and indirectly impacts the European energy market – Norway’s primary export market for oil, gas, and electricity. Stable and predictable conditions are crucial for Norwegian energy producers. Therefore, monitoring the development of new directives, regulations, and decisions related to energy within the EU is of great importance for Norway.

The initial legislative packages from the EU concerning electricity and natural gas regulation primarily focused on opening national markets and applying competition policies to the energy sector. When negotiating the EEA Agreement in the early 1990s, nine legal acts (regulations and directives) related to energy were incorporated into the agreement. Article 24 of the EEA Agreement, located in the section on free movement of goods, specifically mentions energy. Directives and regulations related to energy are included in Annex IV of the EEA Agreement.

EU energy policy extends beyond the scope covered by the EEA Agreement. The Lisbon Treaty of 2009 introduced a dedicated provision on energy (Article 194). This article outlines objectives related to the functioning of the energy market, energy security, energy efficiency, renewable energy, and infrastructure. It also emphasizes that member states have the right to determine the national management of their energy resources and the national energy mix independently.

In 2015, the European Union’s Energy Union was launched by the European Commission. It can be described as a political framework for the goals and measures in the EU’s energy policy. The legal acts were framed as parts of the Clean Energy Package and adopted in 2018-2019. The Energy Union focuses on five areas, also known as dimensions: energy security, the internal energy market, demand-side management, decarbonization, and research, innovation, and development. Since then, regulations have been modified in the “Fit for 55” package and some internal energy market modifications.

The EU has set goals for emission reductions, increased use of renewable energy, and energy efficiency by 2030. In 2021, the EU legally committed to cutting at least 55% of its net greenhouse gas emissions by 2030 compared to 1990 levels. Later that year, the European Commission proposed a series of laws to help the EU achieve this target. This package is known as “Fit for 55.” Several measures in the package relate to the energy sector. For instance, the EU aims to increase the share of renewable energy by 2030 and ensure that most of the EU’s energy consumption is renewable by 2050. After Russia’s attack on Ukraine in February 2022, new initiatives were proposed to promote the green transition and reduce the EU member states’ dependence on gas imports, under the name REPowerEU.

Under the EEA Agreement, directives and regulations must be incorporated through separate decisions in the EEA Committee to apply to the EFTA countries. In this context, specific EFTA adaptations may be necessary.

Currently, Annex IV of the EEA Agreement covers over 80 legal acts related to energy. Several legal acts are still being considered for inclusion in the EEA Agreement. EU energy regulations are continually updated in response to the energy situation and policy objectives. Therefore, closely monitoring the regulatory developments in the EU is of importance and in the interest of EEA EFTA states.

As part of the EEA Agreement, Norway has implemented three of the EU’s energy market packages. The third package, introduced in 2009, further develops the internal market for electricity and gas. It was incorporated into the EEA Agreement in 2017. Subsequently, the regulatory framework was modified through the Clean Energy Package, adopted by the EU in 2018 and 2019. This package comprises eight different legal acts, including a revised Renewable Energy Directive and changes to the Energy Performance of Buildings Directive and the Energy Efficiency Directive. In 2020, the new Commission proposed the “Fit for 55” package with important revisions in the Clean Energy Package from 2018-2019.

The legal acts concerning the electricity market were replaced by a new Electricity Directive, a new Electricity Regulation, and a new ACER Regulation. As of February 2024, this regulatory framework has not yet been incorporated into the EFTA Agreement.   These energy market revisions must also be submitted to the Norwegian Parliament (Stortinget) for consideration.

The EEA Agreement has provided Norwegian stakeholders with opportunities to participate in various research and cooperation programs. Norway is involved in energy programs such as Intelligent Energy Europe (IEE) and the Competitiveness and Innovation Framework Programme (CIP). Additionally, Norway has engaged in research-based collaboration through Horizon Europe.

Under the EEA Agreement, Norway has the right to participate in the decision-making process at an early stage. Our experts are involved in discussions on new regulations and initiatives within expert groups under the European Commission. The Norwegian Energy Regulatory Authority also participates in the Agency for the Cooperation of Energy Regulators (ACER). The early involvement in decision shaping is crucial for the EEA EFTA experts and government representatives.

When incorporating EU directives and regulations into the EEA Agreement, there is some flexibility for EEA adaptations to individual legal acts. For instance, when the EU’s Third Energy Package was integrated into the EEA Agreement, several such adaptations were made. It is common for proposals regarding necessary EEA adaptations to be developed in collaboration among the three EEA member states Norway, Iceland, and Liechtenstein, and discussed with the EU.

How do we handle EEA matters in Norway?

The EEA Agreement extends the Single Market of the European Union to three of the four EFTA member states – Iceland, Liechtenstein and Norway. The fourth member of EFTA, Switzerland, is not a party to the EEA Agreement.

The EFTA Secretariat reviews regulatory proposals adopted by the EU on a weekly basis. Proposals that fall within the scope of the EEA Agreement are sent to the EFTA member states for assessment.

In Norway, the Government’s Guidelines for Impact Assessments outline the framework for further processing of regulatory proposals from the European Commission. If a proposal is deemed to have significant implications for Norway, the relevant ministry must send it out for public consultation. An EEA memorandum is prepared for all legal acts under consideration for incorporation into the EEA Agreement. The relevant ministry evaluates whether the act is relevant to the EEA. Affected ministries must be involved. Important matters related to the EEA must also be discussed within the government. If a regulatory proposal is expected to have substantial benefits or costs, a socioeconomic analysis is conducted.

After the European Commission’s proposal has been adopted by the European Council and the European Parliament, collaboration with other EFTA countries and the EU is necessary to reach consensus on an EEA Joint Committee decision. If the decision is applicable to Norway, it may be relevant to request specific adaptations to EU regulations. Both the EFTA countries and the EU must agree to such adaptations, as stipulated in Article 93 of the EEA Agreement. Once an EEA Joint Committee decision is made, EU regulations become part of the cooperation under the EEA Agreement and are binding for EEA EFTA states.

According to Article 26, paragraph 2 of the Norwegian Constitution, the parliament must give consent for international agreements of particular importance, as well as agreements requiring legislative changes or other decisions by the parliament. A decision by the EEA Joint Committee to incorporate legal acts (both directives and regulations) into the EEA Agreement may fall into this category, necessitating constitutional reservations. In such cases, a consent proposal must be submitted to parliament before the decision takes effect, as outlined in Article 103 of the EEA Agreement.

In such cases, a consent proposal must be prepared and submitted to parliament. During the process, it may also be relevant to keep the parliament informed about work related to EU regulations intended for incorporation into the EEA Agreement, through the parliament’s European Consultative Committee.

Once the EEA Joint Committee decision comes into effect, Norwegian law must be aligned with both EU regulations and the EEA Joint Committee decision. Necessary changes to existing regulations must be identified, and a consultation memorandum must be drafted. Then, regulations and possible legislative amendments must be adopted.

The electricity certificate market

The electricity certificate scheme is a Norwegian-Swedish, market-based support scheme for electricity produced from renewable energy sources, which was launched in 2012. Through the scheme, Norway and Sweden had a joint goal of developing 28.4 TWh of new renewable electricity production from 2012 to 2020. This goal was reached in 2019. The electricity certificate scheme is technology-neutral, meaning that all forms of renewable electricity production qualify for electricity certificates, including hydropower, wind power, and bioenergy.

The electricity certificate scheme will end in Norway in 2035. Power plants approved under the scheme are awarded electricity certificates for up to 15 years. The deadline for commissioning new facilities covered by the scheme expired in December 2021.

The goals of the electricity certificate scheme have already been exceeded, and the price of electricity certificates now more or less only covers the administrative costs of the scheme. NVE has been tasked with assessing whether the electricity certificate scheme should be terminated earlier than the agreed end date of 2035. The Swedish Energy Agency has received a similar assignment

This is how the electricity certificate market works

1. The power producers receive one electricity certificate for every MWh they produce, over a maximum of 15 years.
2. The electricity certificates are sold in a market where supply and demand determine the price. In this way, the producer gets and extra income in addition to the power price.
3. The demand for electricity certificates arises from the fact that power suppliers and certain electricity customers are required by law to purchase electricity certificates corresponding to a certain proportion of calculation-relevant electricity consumption.
4. The electricity customer pays for the development of renewable power production because the electricity certificate costs are included in the electricity bill.
5. Every year, the electricity certificate holder must cancel electricity certificates in order to fulfill his electricity certificate obligation.

Norway has competitive advantages in its abundant renewable energy resources and a well-functioning energy sector. Our energy policy is intended to encourage modernisation of the energy supply system and adapt policy instruments and the regulatory framework to rapidly changing markets.

The question of how to develop an energy supply system that is sustainable in the long term is a key policy issue in many countries. Security of energy supply, climate change, environmental considerations and value creation must all be taken properly into account in energy policy development. It is vital to find solutions that create the maximum value for society at the lowest possible cost.

Improving security of supply

A smoothly functioning power market is of crucial importance for security of electricity supply. In Norway, security of supply is closely linked to the capacity of the supply system to ensure an uninterrupted supply of electricity to end users. The power supply system must be able to deal with variations in electricity consumption through the day, through the year and between years. We depend on a robust power grid. All important societal functions, business and industry and consumers are dependent on reliable power supplies. It is therefore vital to maintain and expand the grid to meet the challenges of the future. Major investments are currently being made in the power grid, and will improve security of supply.

Both production-side and demand-side flexibility have a positive effect on security of supply. Price signals play a decisive role in determining which elements of short-term flexibility are actually used. Operation of the power supply system and power trading should as far as possible be market-based. Effective markets send the right price signals to producers and consumers, and promote sound use of resources, innovation and security of supply.

Security of energy supply is vital in modern society. Norway has abundant energy supplies, but also needs to find good ways of responding to the growing demand for power. Regulation by the authorities is intended to facilitate the development of new, effective solutions that will ensure security of energy supply in the future.

Profitable development of renewable energy

One goal of Norwegian energy policy is to facilitate profitable production of renewable energy in Norway. Renewable production should be developed on the basis of profitability, allowing Norway’s renewable energy resources to be used in a way that creates the maximum value for society at the lowest possible cost.

Norway produces a large amount of flexible hydropower, which will continue to be the backbone of its energy supply system. Hydropower production is also important in the context of climate change in Europe, and hydropower production makes it possible to maintain security of supply in the Norwegian and Nordic electricity systems.

More efficient and climate-friendly energy use

Norway already derives a large share of its energy supplies from renewable sources. The electricity generation sector is virtually emission-free. However, fossil energy use in transport, manufacturing and oil and gas production still results in greenhouse gas emissions. Our energy policy is intended to facilitate more efficient and climate-friendly energy use.

Value creation based on Norway’s renewable energy resources

Renewable energy is an important sector in Norway. The industry employed about 20 000 people in 2021 throughout the country, including employment in grid operations. Renewable energy supplies are essential for the development and growth of other industries. Hydropower has been the basis for Norway’s industrial development and prosperity for more than 100 years. The renewable energy industry will continue to play a key role as the transition to more climate-friendly energy use continues in Norway and the rest of Europe.

Norway’s energy policy is intended to provide a framework that enables the country to further develop its renewable energy resources and make use of its competitive advantages. This includes ensuring that there are well-functioning markets, so that profitable renewable resources can be used efficiently and provide a good basis for business development and value creation. Flexible hydropower production, the widespread use of electricity for many purposes and Norway’s pioneering role in market reform in the power sector are competitive advantages in a European energy market that is undergoing transformation.

The availability of abundant supplies of renewable electricity was the basis for Norway’s large energy-intensive sector. This is a good starting point for developing new markets for energy services, new technology and new energy-intensive products. Norway must continue to use its power, and to use it as efficiently as possible.

Norwegian municipalities and counties have large investments in the power sector. Together with central authorities, they own about 80% of Norway’s electricity production capacity. About 35% of the production capacity is owned by the state through Statkraft SF, which answers to the Ministry of Trade, Industry and Fisheries. Statkraft is organised as a state-owned enterprise, and the Norwegian state must therefore be the sole owner. Many other companies have several owners, and there is a significant level of cross-ownership in the electricity sector.

One characteristic of the Norwegian hydropower sector has been the right of reversion to the state for licences granted to private companies after 1917. The right of reversion means that the state assumes ownership of waterfalls and any hydropower installations free of charge when a licence expires. As the date of reversion stated in the licences approaches, private power plants will either be sold to publicly-owned companies or ownership will revert to the state on the specified date. This system has resulted in gradual restructuring of the ownership of Norwegian power production and is continuing to do so.

In 2008, the water resources legislation was amended to strengthen public ownership of Norway’s hydropower resources. New licences for the ownership of waterfalls and licences to transfer already licensed waterfalls may now only be granted to public developers such as state-owned enterprises, municipalities and county authorities. Licences may also be awarded to companies that are partly owned by state-owned enterprises or one or more municipalities or county authorities, provided that the public sector holds at least two-thirds of the capital and the votes in the company, and the organisation clearly indicates genuine public ownership. In other words, private actors may own up to one-third of a company. Private actors may also own power production facilities that do not require a licence under the Industrial Licensing Act, such as wind and solar power installations and some small-scale hydropower installations.

There are private ownership interests in all parts of the power sector: production, grid operations and trading. Foreign ownership interests are relatively limited, but increasing.   Some foreign companies have been granted trading licences in Norway and there is a growing number of foreign stakeholders that have invested in Norwegian wind and small-scale power production.

Population

Population growth influences energy use both directly and indirectly. As the population rises, so will total household demand for energy services – for transport, heating and electrical equipment. A larger population means a larger labour force and higher production of goods and services. This creates a growing demand for offices, shops, supermarkets, cafés and production plants, which in turn increases energy demand. More people also need more schools, child daycare centres and health services, all of which use energy for heating and to run equipment.

Population structure and population distribution also influence energy use. Urbanisation is expected to continue, with more and more people living in towns. Urbanisation tends to mean that more people live in flats, where each person generally has less living space and therefore uses less energy for heating. Centralisation also reduces energy needs for transport, because travel distances are shorter and people can use public transport more extensively or walk or cycle to their destinations. Compact towns generally have a less energy-intensive industrial structure and more service industries.

Economic growth

Economic growth results in greater demand for goods and services. This in turn increases energy demand, both for the production of goods and services and for transport of people and goods. Although economic growth, population trends and energy demand have become less closely linked in recent years, the level of activity in the Norwegian economy will continue to have a strong influence on trends in energy demand.

Industrial structure

The Norwegian economy consists of a large number of sectors and industries, and their energy use varies considerably. For example, manufacturing industries are generally more energy-intensive than service industries. Changes in industrial structure therefore influence energy use in Norway. Energy use will therefore rise more slowly than would be expected if more energy-intensive industries were growing.

Technological advances

The effects of technological advances on energy use are complex. New technology is often more efficient, which tends to moderate any increase in energy use; on the other hand, energy use may increase as new machinery and equipment is introduced. For the economy as a whole, technological advances act as a stimulus for growth. Technological developments are the most important driver of growth in productivity, which in turn is a key driver of economic growth, which brings with it more energy use. Technological advances also shift production towards capital-intensive industries, and these are generally also relatively energy-intensive. Thus, the overall effect of technological advances is to increase energy use, even if the energy is used more efficiently.

Energy prices

Energy prices influence both the energy mix and overall energy use. If the price of one energy carrier rises, this may both reduce its consumption and increase demand for other energy carriers. In the short term, however, the technology available limits how much consumption can be reduced and whether it is possible to switch to another energy carrier. Relatively large price changes that are maintained over time are needed to make it financially worthwhile to reduce energy use or switch energy carriers. People do not immediately replace inefficient fridges or install heat pumps when electricity prices rise.

In isolation, rising energy costs tend to result in lower demand and lower production of goods and services. Energy-intensive sectors become less profitable, and less energy-intensive sectors such as services become relatively more profitable. In the long term, higher energy prices may therefore result in a less energy-intensive industrial structure and reduce overall energy demand.

In 2024, Norway's net domestic energy consumption was 215 TWh. A large share of this is electricity. Norway has a significant energy-intensive industry that consumes a substantial amount of electricity, and electricity use for heating buildings and domestic hot water is high. In the transport sector, energy use is mainly based on fossil fuels. However, electricity use in the sector is increasing, and strong growth is expected in the coming years due to the electrification of vehicles and maritime transport. Read more about the factors that influence energy use here.

In the mainland economy electricity is the dominant energy carrier, followed by fossil fuels. This is especially true in the industrial sector (excluding the oil and gas sector), households, and service industries.

Manufacturing

Energy use in the industrial sector, excluding the oil and gas sector, was 72 TWh in 2024. Norway has a significant share of energy-intensive industry, largely due to historically good access to electricity at competitive prices. The industrial sector is characterized by many large individual players with high energy consumption. The main industrial segments in Norway are the chemical industry, the metal industry, and the pulp and paper industry. Energy in the industrial sector is used to meet cooling and heating needs, industrial processes, and the operation of electrical equipment.

The high share of electricity use in industry is largely due to aluminium production. This process is highly energy-intensive and relies almost entirely on electricity as its energy source. The production of other metals, chemical raw materials, and cement involves a higher share of fossil fuels. The pulp and paper industry uses a significant amount of biomass in addition to electricity.

Household and service industries

Energy use in households is often referred to as energy use in residential buildings. In 2024, consumption was 46 TWh. Electricity dominates energy use in households, followed by biofuels and district heating. Since the ban on oil heating was introduced in 2020, fossil energy sources like oil and parrafin are no longer used for residential heating. More than 75 percent of household energy is used for heating of space and tap water.

In Norway, electricity covers much of the heating of buildings. In other European countries, energy sources such as bioenergy, district heating, and fossil fuels are more common. The high share of electricity used for heating means that the annual electricity consumption in Norway fluctuates with the weather and outdoor temperature. Electricity use is typically high in the winter and lower in the summer. The correlation between outdoor temperature and electricity use is stronger in Norway than in other European countries.

While energy use in buildings is largely influenced by the outdoor temperature, energy consumption in the industrial sector is relatively even throughout the year. In areas with many homes and little industry, the overall use of electricity varies more than in industrial areas. In the Oslo area, which has less industry than other parts of the country, the electricity consumption is therefore particularly high in winter and low in summer.

Despite a population increase in Norway of 20 percent from 2000 to 2021, the  use of energy in households has increased relatively little. A moderate growth from 2020 to 2021 can be explained by improved energy effenciency in buildings, electrical appliances and other technical solutions. Additionally, many households have installed heat pumps, mainly air-to-air pumps. According to The Norwegian Water Resources and Energy Directorate, in 2021 18.8 TWh of heat was produced from heat pumps consuming 8.1 TWh of electricity.

Energy use in the service sector was 36 TWh in 2024, of which about 25 TWh came from electricity. The service sector includes a wide variety of non-residential buildings, such as nursing homes, hospitals, schools, cultural buildings, hotels, office buildings, and retail buildings—the last two being the largest categories. The service sector also includes the armed forces.

In this sector, about half of the energy use goes to lighting, fans, pumps, and other electrical equipment. Approximately 40 percent is used for space heating, while a small share is used for heating tap water. The use of fossil fuels in the service sector occurs primarily within military sector.

Read more about energy use in buildings here.

Transport

Energy consumption in the transport sector was 53 TWh in 2024. This includes all domestic transport activities. Road transport accounts for the majority of the sector’s energy use—about 70 percent. Domestic maritime transport accounts for 22 percent, domestic aviation eight percent, and rail transport two percent. Fossil fuels still make up the largest share of energy use in the transport sector. However, electricity use is increasing, and strong growth is expected in the coming years due to the electrification of vehicles and ferries.

In 1990, the total energy use in the transport sector was around 40 TWh. Between 1990 and 2022, energy use in road transport increased by just over 40 percent. The maritime sector has seen a slight increase over the same period. Air traffic has had a relatively stable consumption level since the early 2000s, with the exception of 2020 and 2021 when activity was lower due to the COVID-19 pandemic.

In recent years, there has been a shift from fossil fuels to electricity in road transport. Favorable policies for electric vehicles, increasingly available charging infrastructure, and a wider range of EV models have driven this development. Since electric motors use energy nearly three times more efficiently than internal combustion engines, this shift to electricity is reducing overall energy consumption in road transport. An overview of the current share of new zero-emission vehicles in different segments can be found on the Norwegian Public Roads Administration’s website.

Electrification is also underway in coastal transport and fisheries. More new ferries are being ordered with electric propulsion; there are examples of electric express boats, and hybrid solutions are being installed in older vessels. Charging infrastructure is also being developed in ports, including shore power for larger ships. For larger, long-distance vessels, the transition to zero emissions is progressing slowly, but hydrogen and ammonia are emerging as important energy carriers for phasing out fossil fuels in the future.

Technical Regulations on buildings

Building standards have a long history in Norway, and the first energy requirements for buildings were introduced as far back as 1949. The Ministry of Local Government and Regional Development is responsible for determining the requirements of the Technical Regulations on buildings.

The Technical Regulations apply to new buildings and when large-scale renovation and alterations are carried out on existing buildings. The regulations set minimum standards that must meet for the construction to be legal. These minimum standards include requirements relating to energy use in buildings. New buildings correspond to only about 1-2 % of the building stock per year. However, buildings have a long lifespan, and the energy requirements will therefore influence energy use for many years to come. Norwegian energy requirements have been revised and made stricter a number of times, most recently from 1 January 2016.

Phasing out oil-fired heating

In 2020, the use of mineral oil for heating buildings was banned. Traditionally, oil heating had been a widespread local energy solution and functioned well in interaction with the power system. High taxes and clear signals that the use of fossil oil for heating buildings would be prohibited contributed to a significant shift in energy use in buildings ahead of the ban. Fossil energy sources in buildings have largely been phased out in favor of electricity, district heating, and bioenergy.

From an energy system perspective, it is beneficial to find new heating solutions that do not place additional load on the power system during the winter.

District heating

Mandatory connection to district heating

A sufficiently large number of customers is required for a district heating system to be developed for an area, since the cost per customer drops as capacity is more fully used. In, Norway, a municipality is entitled to require new buildings to be connected to a district heating system when a district heating license has been issued.

Ministry of Local Government and Regional Development and the Ministry of Energy has published guidelines explaining how municipalities can use requirements for mandatory connection to a local district heating system for new buildings. They emphasize that the municipalities can modify the requirements to suit local conditions, for example by specifying which types of buildings are to be connected or defining the geographical areas where the requirements apply. The district heating companies are responsible for providing municipalities with the information they need in order to make good decisions on mandatory connection. This is to make sure that the municipal planning process is as effective as possible.

Energy performance certificates for buildings

Since 1 July 2010, it has been mandatory in Norway to hold an energy performance certificate for any building that is constructed, sold or rented out. The energy performance certificates are intended to improve knowledge and awareness of energy use in buildings. Inspection of large heating, ventilation and air conditioning systems has also been made mandatory to encourage sound operation and inspection routines. Owners of private homes may choose to use a free online system for obtaining energy certificates for buildings, while commercial buildings and new buildings must be certified by an expert.

The energy rating ranges from A (very energy efficient) to G (low energy efficiency). The rating provides an assessment of the building’s need for delivered energy, meaning the number of kWh the building or home requires for normal use. The energy rating is based on a calculation of the building’s need for delivered energy and is independent of the actual measured energy consumption. Standard values, such as indoor temperatures and climate data, are used in the calculation.

Energy used for heating from sources other than electricity—such as district heating or bioenergy—is also included in the calculation of a building's energy rating. These energy carriers help reduce the load on the electricity system and are rewarded in the energy labeling scheme by only counting as 45 percent of the actual delivered energy. This means that 1 kWh of district heating is counted as only 0.45 kWh when calculating the energy rating in the labeling system.

Buildings constructed according to the 2016 building regulations (TEK17) will normally receive a B rating, while older buildings with lower energy performance and no upgrades will receive lower ratings. Buildings with an energy need that is 10 percent lower than TEK17 requirements will generally receive an A rating.

Ecodesign and energy labelling

Ecodesign and energy labelling establish minimum requirements for energy efficiency and eco-friendly design.  NVE is market surveillance authority for eco-design and energy labeling related to energy efficiency.

More information on ecodesign and energy labelling can be found here.

Energy labelling of products

The purpose of energy labeling is to provide consumers with easily recognizable and comparable information, which provides a basis for choosing the most energy-efficient products. The products are graded according to how energy efficient they are, based on a scale, where A is the best and G gives the worst grade. Energy labeling regulation imposes information requirements on manufacturers and suppliers, while retailers (shops) are required to place the energy labeling clearly visible.

In 2017, the EU decided to update the energy label. The purpose of the change is to make it as easy as possible to understand the energy label arrangement. This includes, among other things, a new grading scale that goes from A to G without further division. This means that the grades A+ to A+++ will disappear gradually.

Ecodesign

The Ecodesign Directive sets requirements for improving the energy efficiency and environmental performance of energy-related products for placing/or putting into service on the EU internal market. The directive is aimed at manufacturers/importers and covers the household sector, the service sector and the industry. If products meet specified ecodesign requirements, they qualify for CE marking, and may be sold throughout the internal market. Ecodesign requirements are intended to remove the least energy-efficient products from the market and reduce the environmental impact of energy-related products at all stages of their life cycle.

The EU is drawing up product-specific rules under the Ecodesign Directive on an ongoing basis, in the same way as for products covered by the Energy Labelling Directive. The EU has signaled that ecodesign will be a tool to achieve circular economy. Future requirements could be related to a products use of resources, how easy the product is to repair or recycle. Several products covered by eco-design requirements are also covered by energy label requirements.

Guarantees of origin

Guarantees of origin are certificates to show an end customer that an amount of electricity is produced from a specific source. Guarantees of origin were first introduced in the 2001 Renewable Energy Directive (2001/77/EC), which entitled all producers of renewable electricity to obtain guarantees of origin. These provisions were retained in the 2009 directive (2009/28/EC), and extended to heating and cooling produced from renewable sources.

Guarantees of origin are tradable, and a facility that is approved for issuing guarantees of origin is certified for five years, after which it must be reapproved. Several European countries, including Norway through Statnett, are members of the AIB (Association of Issuing Bodies), which ensures that records of the purchase and sale of guarantees of origin are maintained and facilitates cross-border trading of these certificates. In Norway, Statnett manages the registry, while the Norwegian Water Resources and Energy Directorate (NVE) supervises the guarantee of origin scheme. Guarantees of origin do not constitute a financial support mechanism that directly triggers the development of new production, but they can be used for marketing purposes.

Based on the EU Electricity Market Directive, Norwegian electricity suppliers are required to inform their customers about the origin of the electricity delivered in the previous year through disclosure statements. This information must be provided in promotional materials and on invoices. Each year, NVE calculates a climate declaration based on the physical delivery of electricity, and a disclosure statement based on the sale of guarantees of origin