Poland's household electricity prices are among the higher ones in the EU relative to average income, a situation that has persisted even as wholesale power prices have declined from their 2022 crisis levels. Understanding why requires looking at several overlapping factors rather than a single cause.
The structure of the Polish energy market
Poland generates around 65% of its electricity from coal — lignite and hard coal — compared to an EU average that is now well below 20%. Coal-fired power is not cheap to produce when carbon credit prices are included, and Poland has one of the highest carbon credit costs per megawatt-hour in the EU's power sector due to the intensity of its generation mix. Utilities pass those costs on to consumers through the regulated tariff structure.
The transition to renewable generation is underway — Poland has added significant solar and onshore wind capacity in the past three years — but the grid integration costs, backup capacity requirements, and the ongoing capital investment needed for the transition are also reflected in bills.
Government interventions and their limits
The government introduced household energy price caps in 2022 that shielded consumers from the worst of the global price spike. Those caps have been gradually unwound as the immediate crisis passed, but the unwinding itself caused bill increases that consumers experienced as a price rise, even though they represent the removal of a subsidy rather than an underlying cost increase. The URE (Energy Regulatory Office) approved tariff increases for 2025 that reflect both the end of cap arrangements and updates to distribution network costs.
The government has announced a new social energy tariff intended to target protection more narrowly at low-income households, replacing the broad cap approach. The details of implementation — income thresholds, administrative processes — are still being finalised, and the scheme has not yet been fully deployed.
What is planned for the longer term
Poland's energy transition plan includes a significant expansion of offshore wind in the Baltic Sea, which would — once operational — provide large volumes of electricity at lower marginal cost than the current coal-heavy mix. The first offshore projects are expected to produce power from 2027–2028, but their full contribution to the system will take until the early 2030s to materialise. Nuclear power is also in the plan, with the first reactor currently scheduled for 2033 — a date that has already been pushed back once and which most analysts treat as optimistic.
In the near term, bills are unlikely to fall significantly. The carbon transition costs, grid investments, and capacity market charges are structural features of the current period that cannot be quickly eliminated. The realistic scenario for households is stable or marginally lower prices in 2026–2027, followed by a more meaningful reduction as renewables scale up and coal's share declines.