Denmark: An Energy Overview

Introduction

Denmark’s energy sector continues to undergo rapid transformation, shaped by ambitious climate legislation, large-scale infrastructure investments, and an evolving policy landscape. The legal and commercial story in 2026 is no longer simply about climate ambition. It is increasingly about execution: Denmark is now confronting the practical challenges of translating political ambition into commercial reality – a process that is reshaping the regulatory environment and creating new opportunities for market participants. That shift matters for both investors and counterparties. Denmark still offers a stable policy environment and broad political support for the green transition, but the projects now moving forward are larger, more infrastructure-heavy and more dependent on getting the regulatory design right.

The past year has been marked by significant policy recalibrations. A failed offshore wind tender exposed the limits of subsidy-free auction models, prompting the government to redesign its procurement framework. At the same time, landmark bilateral agreements on offshore wind and hydrogen infrastructure have opened new cross-border dimensions to Denmark’s energy transition.

Regulatory Framework

The Danish energy sector is governed by a comprehensive and evolving legislative framework. Key statutes include the Climate Act, which mandates emission reduction targets and underpins carbon pricing; the Renewable Energy Act, regulating support schemes and environmental considerations for renewable energy production; the Electricity Supply Act, governing grid operation, tariffs, and consumer protection; the Gas Supply Act, which now also covers hydrogen supply; and the Heat Supply Act, governing the district heating sector.

The Danish Energy Agency and the Danish Utility Regulator remain the principal regulatory authorities.

Offshore Wind: A Reset and New Horizons

The most consequential development in the offshore wind sector over the past year has been the failure of Denmark’s 6 GW offshore wind tender in late 2024, which attracted zero bids. The result forced a fundamental rethink of the procurement model. The government cancelled the ongoing 3 GW tender and announced a shift from the previous no-subsidy approach to a two-sided contract-for-difference (CfD) subsidy scheme with a 20-year duration. The revised tender framework, announced in November 2025, also adjusts bidding deadlines and eases minimum capacity requirements.

Meanwhile, cross-border co-operation has advanced significantly. In January 2026, Denmark and Germany signed a landmark bilateral agreement on the Bornholm Energy Island project, including cost allocation and support design. The project will integrate 3 GW of offshore wind capacity and deliver electricity to both countries. That agreement suggests that the next phase of Danish energy regulation will be increasingly regional and infrastructure-based, with cross-border co-ordination becoming central to project execution. For international sponsors, lenders and referral counsel, this makes Denmark especially relevant not only as a domestic renewables market, but as a platform for interconnected North Sea and Baltic Sea development.

The North Sea Energy Island, by contrast, has faced further delays. Originally scheduled for completion in 2033, the project has been pushed to 2036, with construction costs estimated at over DKK200 billion.

Hydrogen Infrastructure and Power-to-X

Denmark’s hydrogen ambitions have moved decisively from planning to implementation. Following the political agreement of 6 February 2025, Energinet focused the first phase on Danish Hydrogen Backbone 1 (DHB1), the hydrogen pipeline from Esbjerg via Veerst to Frøslev at the German border. In late August 2025, the Minister for Climate, Energy and Utilities approved Energinet’s business case for the project, subject to binding market commitments. DHB1 combines new pipeline construction with the conversion of an existing natural-gas pipeline, and Energinet has since moved into the next stages of market dialogue, regulatory development and capacity allocation, including the opening of the capacity-sale process in January 2026.

This is commercially significant because it begins to turn Denmark’s PtX story into a transport and export story. The legal issues are no longer limited to support schemes for production. They now include infrastructure access, timing risk, cross-border alignment and the interaction between project finance, capacity booking and future tariff structures.

Grid Capacity: An Emerging Bottleneck

As projects evolve, Denmark’s green transition is now being shaped as much by access to network capacity as by access to seabed, land or subsidies. The sheer volume of planned projects has outpaced transmission infrastructure, and many projects face delay. In March 2026, Energinet introduced a temporary pause on new grid connection agreements while accelerating emergency measures to free up capacity and prioritise more mature projects. A new prioritisation model is also being implemented for transmission-grid access. For businesses entering the Danish market, this means that grid strategy has become a front-end legal and commercial issue. Connection rights, queue position, maturity criteria, curtailment risk and tariff design can be as important as the core project documents.

Carbon Capture and Storage

Carbon capture and storage is following a similar trajectory from policy ambition to investable infrastructure. Denmark has deliberately positioned CCS as a core element of its 2030 and 2045 climate toolkit. The Danish Energy Agency launched the CCS Fund with a budget of DKK28.7 billion, designed to support the full value chain – capture, transport, and geological storage – through 15-year contracts.

Denmark’s longer-term ambition is to become a European CO₂ storage hub, making CCS one of the most important legal growth areas in the Danish energy market for industrial emitters, waste-to-energy operators, utilities, and infrastructure investors.

Other Developments and Security of Supply

While large infrastructure projects dominate the headlines, smaller regulatory changes also say something important about the Danish market. In 2025, Denmark abolished the surplus-heat price cap in order to remove barriers to district heating investments based on industrial surplus heat.

In a significant policy shift, the Danish Parliament in 2025 endorsed the government’s launch of an analysis of new nuclear power technologies, including small modular nuclear reactors (SMRs), and the implications of lifting the long-standing ban on nuclear power in Danish energy planning. The study is expected to conclude in Q2 2026 and will examine issues including regulatory requirements, competencies, safety and emergency preparedness, waste management, decommissioning, siting, and economic implications.

Finally, it is worth noting that the Danish transition still sits alongside conventional supply-security concerns. The Danish Energy Agency’s updated outlook for oil and gas production shows that the timing and ramp-up of the Tyra field remain relevant to short- and medium-term gas supply expectations. Even in a country strongly identified with wind and green fuels, security of supply remains a live consideration, and that continues to shape both political priorities and regulatory choices.

Outlook

Denmark’s energy transition is entering a phase defined by execution rather than aspiration. The coming years will test whether the redesigned offshore wind framework can attract investment, whether hydrogen infrastructure can be delivered on schedule, and whether new technologies such as CCS and potentially nuclear power can complement renewables at scale.

For industry participants, the landscape presents both complexity and opportunity. Cross-border projects, evolving subsidy models, and new asset classes in hydrogen and carbon storage are creating a dynamic market that demands careful navigation of an increasingly sophisticated regulatory environment.