Romania’s Energy Ministry has proposed ending mandatory forward electricity-trading requirements on December 31, 2027, while retaining the existing producer and supplier quotas until then. The draft amendment, dated November 4, would make the obligations time-limited rather than remove them immediately, with implications for organised forward markets and buyers planning long-term hedges.
Quotas remain in place through 2027
Under the draft, qualifying producers would still have to trade at least 50% of annual output through organised markets, excluding day-ahead, intraday and balancing platforms. Suppliers would continue to cover at least 30% of customer requirements through their own production or eligible forward purchases.
The proposal preserves exemptions from the producer requirement for operators whose facilities are exclusively wind, solar, micro-hydro or high-efficiency cogeneration. It would also take account of volumes committed under contracts signed before the ordinance takes effect, to reduce the risk of disrupting existing sales agreements when the mandatory shares are calculated.
Direct household sales could count
Electricity generated by a producer and supplied directly to household customers could count toward its 50% requirement. The draft recognises that wholesale sales are not the only outlet for a producer’s output, a treatment relevant to integrated generation and retail businesses.
Hidroelectrica, Romania’s largest electricity producer and an important retail supplier, reported net generation of 9,328 GWh in the first nine months of 2026. Sales to final customers reached 6,739 GWh, while wholesale-market sales totalled 4,288 GWh across venues during the same period. Those figures illustrate why a rule based on wholesale volumes may not fully reflect the exposure of a producer serving its own retail customers.
Market effects depend on trading behaviour
Romania’s forward-trading requirements were designed to support market depth and reduce dependence on short-term price formation. Their scheduled end could affect OPCOM’s organised contract markets, the volumes available to independent retailers and the transparency of long-dated prices.
Ending the mandate would not necessarily reduce total hedging: companies could continue to trade forward voluntarily to protect earnings, secure cash flow or meet lender requirements. Traders would need to assess whether supply shifts toward bilateral contracts or internal generation-retail allocations. A narrower pool of exchange-listed forward products could raise the cost of constructing hedges and make counterparty credit limits, collateral and settlement terms more important, particularly for buyers without their own generation.
The proposal could also affect Hungary and neighbouring Southeast European markets through portfolios using Romanian forward contracts alongside HUPX and other exchanges. The size of any cross-border effect cannot yet be quantified and will depend on trading behaviour, not only on the draft’s wording.
The proposal remains subject to approval; if enacted in its current form, the requirements would continue through 2027. Producers, retailers and financial intermediaries will need to assess the final exemptions, contract-accounting treatment and potential effects on market liquidity before changing procurement strategies.