Energy #24 Legislative focus

ANRE published Order no. 59/2026, modifying the technical rules used to calculate and allocate additional own technological consumption in public 110 kV electricity networks.

The order was published and entered into force on 24 September.

Under the new rules, additional technical losses are allocated for each settlement interval between electricity producers and the transmission system operator based on their respective electricity injections into the 110 kV network during that interval.

The total quantity attributed to producers and the transmission system operator is then calculated by aggregating the amounts determined for each settlement interval.

The amendment changes how the cost of additional losses in 110 kV networks is distributed among the market participants contributing to those flows.

Instead of relying on a more aggregated allocation approach, the methodology now links the calculation more closely to actual injections during each settlement interval.

For producers connected to 110 kV networks and the transmission system operator, this means exposure to additional technical-loss costs will depend more directly on their contribution during individual settlement periods.

Distribution operators will also need to apply the calculation at settlement-interval level, increasing the importance of accurate metering, settlement and data-processing arrangements.

ANRE published Order no. 58/2026, which approves the methodology for assessing the costs and benefits generated by distributed energy sources within renewable energy communities. The order was published on 23 September and entered into force on 25 September.

The final methodology defines more precisely which electricity can be taken into account when assessing the activity of a renewable energy community.

Electricity must be produced from renewable sources within the community, or previously stored from the community’s own production, and consumed by members within the same settlement interval.

The methodology also introduces network boundaries. At low voltage, the relevant electricity flows must use feeders supplied from the same transformer station. At medium voltage, they must use feeders supplied from the same substation.

Renewable energy communities must provide estimates of the electricity produced or stored and consumed within the community, while distribution operators must provide data including network losses, associated costs, monthly electricity volumes, expected or avoided investments, congestion and power-quality effects.

If the analysis identifies net benefits for the distribution system, ANRE may approve a reduction of the distribution tariff applicable to the relevant electricity volumes for a period of up to five years.

The methodology creates the operational route through which renewable energy communities may obtain lower distribution tariffs, but the reduction is not automatic.

Communities will need to demonstrate that electricity production, storage and consumption meet both the settlement-period requirements and the geographical limits of the distribution network defined by ANRE.

For distribution operators, the methodology introduces additional data-provision and monitoring responsibilities and requires information on costs, losses, congestion and investment effects to be incorporated into the assessment.

The first analyses carried out under the methodology will therefore be important in showing how easily renewable energy communities can demonstrate net benefits and what level of tariff reduction ANRE may approve in practice.

The Ministry of Energy published an updated version of the state aid scheme supporting investments in new biofuel production capacities financed through the Modernisation Fund.

The scheme has a total budget of EUR 500 million, with an indicative EUR 100 million allocation for bioethanol and EUR 400 million for SAF and HVO production.

Several eligibility and implementation conditions have changed compared with the previous version.

Newly established companies are now eligible, provided they have subscribed and paid-up share capital of at least RON 200,000. They may also demonstrate financial capacity through a comfort letter issued by an eligible financial institution.

The minimum production capacity for bioethanol projects has been reduced from 50,000 to 20,000 tonnes per year.

At the same time, projects must now use technologies with a Technology Readiness Level of at least 8, while eligible feedstocks must be certified under voluntary schemes recognised by the European Commission.

The previous requirement to complete investments within 48 months has been removed. Projects must instead be completed and commissioned by 31 December 2030.

The revised version also removes the general prohibition on combining the scheme with other state aid, de minimis support or EU funding, provided the applicable maximum aid intensity or amount is not exceeded.

The revised scheme broadens the range of companies and projects that may qualify for support.

The lower minimum capacity threshold may make bioethanol funding accessible to smaller projects, while allowing newly established companies to apply widens the potential beneficiary pool.

The removal of the general restriction on combining funding also gives developers greater flexibility in structuring project financing.

At the same time, the new technology-maturity and feedstock-certification requirements create clearer eligibility filters. Beneficiaries will also remain subject to progressive production targets, with proportional recovery of aid where the required production levels are not achieved.

The commercial attractiveness of the scheme will therefore depend not only on the available aid intensity, but also on whether projects can meet the technological, feedstock and production requirements through the full monitoring period.