Romania Prosumers 2027: New ANRE Multi-Site Rules

Direct answer

Romania is preparing a significant change to the way electricity produced by prosumers is sold, invoiced, compensated and ultimately used across multiple consumption sites.

Following the amendments introduced by Law No. 160/2026, the Romanian Energy Regulatory Authority — ANRE — has published a draft order approving a new *Methodology on the rules for commercialisation, invoicing, settlement and multi-location value allocation applicable to prosumers*.

The proposed framework is intended to apply, in its substantive form, from 1 January 2027.

For businesses and individuals with photovoltaic generation, the most important change is easy to summarise:

Romania is moving away from a system centred on carrying surplus electricity forward in kWh and towards a monthly system in which surplus energy is valued financially and, in certain circumstances, that value can be used against electricity — and sometimes gas — invoices at other locations of the same prosumer.

This is not merely a billing amendment. It changes how companies may structure portfolios of consumption sites, how suppliers will administer prosumer accounts, how legacy compensation balances will be treated and how prosumers should think about the economics of self-generation.

The regulation remains in draft form, and several implementation and transitional points would benefit from further clarification before the final order is adopted.

What is ANRE proposing for Romanian prosumers from 2027?

The draft methodology creates a common framework covering:

Two different commercial regimes remain central to the proposed framework.

The fundamental distinction therefore remains between quantitative compensation and financial settlement, but the practical operation of quantitative compensation would change substantially.

1. How will quantitative compensation work for prosumers below 200 kW?

Under the proposed methodology, quantitative compensation would be determined monthly and separately for each eligible location.

In simplified terms:

• electricity imported from the grid during the month is compared with electricity exported to the grid
• the lower of the two quantities is quantitatively compensated
• electricity injected above the amount consumed from the grid becomes surplus electricity for that billing period.

The major change concerns what happens next.

Under the new proposed architecture, the excess electricity would not continue to exist as a bank of kWh carried into future periods.

Instead, the surplus would be monetised within the relevant billing cycle.

This effectively changes the logic from:

energy carried forward → future quantitative compensation

to:

monthly energy compensation → monetary valuation → financial settlement or allocation.

For prosumers accustomed to thinking about the existing mechanism as a form of long-term electricity banking, this is a significant conceptual change.

What price is used?

For the energy subject to the quantitative compensation mechanism, the methodology works by reference to the price of active electricity under the supply contract, excluding regulated network tariffs and the other taxes, contributions and regulated components identified by the applicable legislation.

This distinction matters because one exported MWh should not simply be assumed to cancel the entire retail cost of one imported MWh.

Network charges, taxes and other regulated components remain legally distinct from the active-energy component.

2. What happens to prosumers between 200 kW and 400 kW?

For prosumers falling within the financial-settlement regime, the supplier would purchase electricity injected into the network by reference to the weighted average price recorded on the Romanian Day-Ahead Market (PZU) for the relevant month.

OPCOM would publish the applicable weighted average price on the first working day of each calendar month for the previous month.

The simplified calculation is therefore:

value of electricity sold = exported electricity × monthly weighted average PZU price

The supplier and prosumer then have reciprocal monetary claims:

• the supplier has a claim for electricity supplied to the prosumer
• the prosumer has a claim for electricity delivered into the network.

These claims are first reconciled at the individual location.

Only a remaining balance in favour of the prosumer becomes available for payment or, where the relevant conditions are satisfied, for allocation to another location.

This sequencing is important.

3. What is the new "multi-location" or "multi-site" mechanism?

The proposed multi-location mechanism is probably the most commercially interesting part of the reform.

It should not, however, be confused with physical electricity sharing or virtual net metering in the strict technical sense.

Electricity is not transferred physically or quantitatively from one POD to another.

Instead, the mechanism works at the level of monetary value.

Example

Assume a company has:

• Site A: rooftop PV installation and a monetary surplus after monthly settlement
• Site B: office with an outstanding electricity invoice
• Site C: warehouse with another electricity invoice.

If the statutory and contractual conditions are met, the surplus generated at Site A may be used to extinguish amounts owed for Sites B and C.

The mechanism is therefore more accurately described as:

multi-site value allocation rather than multi-site energy compensation.

That distinction is legally and commercially important.

4. What conditions must be met for multi-site allocation?

The proposed regime relies on a single list of eligible locations declared by the prosumer.

As a general principle, the sites must belong to the same prosumer and must be covered by the contractual relationships required under the methodology.

The framework also relies heavily on the concept of the same electricity supplier.

For the purposes of the draft methodology, the supplier must generally be the same legal entity, not merely another company within the same corporate group.

Depending on the relevant category of prosumer, distribution-network restrictions may also apply.

Consequently, corporate prosumers operating portfolios across Romania should not assume that every production and consumption location can automatically be pooled nationally.

The contractual structure of their supply portfolio may become increasingly important.

Commercial implication

A company operating:

may have a stronger incentive to assess whether consolidating supply contracts with one supplier increases the economic value of its self-generation portfolio.

This turns what appears to be a regulatory billing rule into a potentially relevant energy procurement and portfolio-management consideration.

5. How does ANRE determine which invoices are paid first?

The draft methodology does not allow the prosumer simply to nominate each month which surplus should extinguish which invoice.

Instead, ANRE proposes a deterministic allocation algorithm.

The mechanism first identifies:

• source locations, where money remains available in favour of the prosumer; and
• beneficiary locations, where electricity invoices remain payable.

The methodology then establishes mandatory ordering rules.

Among other things, already overdue invoices are prioritised over invoices that have not yet reached their due date.

Within the relevant categories, the methodology applies additional criteria concerning due dates, outstanding amounts, issue dates and POD identification.

The objective is understandable: the same factual data should produce the same allocation outcome regardless of the supplier's internal billing system.

From a regulatory perspective this improves consistency.

From an implementation perspective, however, it creates a considerably more sophisticated billing and reconciliation exercise for electricity suppliers.

6. Can the mechanism also pay gas invoices?

For a specific category of individual prosumers, the proposal goes further.

Eligible individuals may choose between different destinations for the remaining value generated by their electricity production.

Subject to the statutory conditions, the balance may be allocated either:

• to electricity invoices relating to other eligible locations; or
• to natural-gas invoices where electricity and gas are supplied by the same qualifying supplier.

This creates an unusual but commercially attractive result:

electricity generated by residential rooftop PV may ultimately create monetary value that reduces a household's gas bill.

The options are alternatives rather than cumulative rights and are subject to the minimum option periods and contractual conditions established by the methodology.

7. What changes for companies with several Romanian locations?

For businesses, the reform may prove most relevant to organisations with decentralised electricity consumption.

Typical examples include:

Until now, the economic analysis of rooftop PV was frequently performed primarily at individual-site level.

The proposed mechanism may justify a broader analysis:

generation portfolio + consumption portfolio + supplier structure + invoicing structure.

A location with substantial midday electricity exports may become more valuable where the resulting financial surplus can effectively reduce liabilities elsewhere in the company's portfolio.

That does not eliminate the importance of self-consumption.

Direct self-consumption will generally remain economically different from exporting electricity and subsequently monetising it.

But the ability to utilise residual value elsewhere may reduce part of the economic inefficiency associated with surplus generation at individual sites.

8. Monthly meter reading becomes central to the new regime

The proposed methodology depends heavily on reliable monthly metering.

For the locations subject to the relevant prosumer mechanisms, meter readings used for invoicing based on actual consumption are intended to follow the calendar month.

Distribution operators are therefore critical to the functioning of the new model.

They must provide validated information concerning both directions of energy flow:

• electricity taken from the network; and
• electricity delivered into the network.

Where final validated data is temporarily unavailable, estimation and subsequent correction mechanisms may apply.

The prosumer should not be penalised for delays attributable to the supplier or network operator.

This is important because the new multi-site model effectively creates a chain:

metering → validation → invoice → local settlement → available value → multi-site allocation → reconciliation.

An error at the beginning of that chain may propagate through several downstream transactions.

9. How will self-billing work?

The methodology also addresses the tax-documentation side of the prosumer relationship.

Where applicable, the parties may use a self-billing arrangement, under which the supplier issues the relevant invoice in the name and on behalf of the prosumer.

The mechanism is particularly relevant where the prosumer is itself required to issue an invoice for the electricity sold to the supplier.

The draft addresses matters including:

The draft currently provides a very short period for objections to certain self-billing documents.

For large organisations, shared-service accounting environments and public institutions, the operational feasibility of this timeframe deserves careful consideration during the consultation process.

10. Is a multi-location settlement statement itself a tax invoice?

No.

This is one of the useful conceptual clarifications made by the draft methodology.

The multi-location settlement statement is intended to operate as a non-fiscal allocation document.

It does not itself:

This distinction is essential.

The supplier must nevertheless maintain a sufficiently detailed audit trail connecting:

the originating document → the available value → the allocation → the beneficiary invoice → any subsequent correction or reversal.

For companies, this will matter not only for energy accounting but also for tax controls and financial audit.

11. What happens if the supplier or distribution operator later corrects the data?

The methodology recognises that corrections may occur after an allocation has already been completed.

This is particularly important because validated metering data, invoices and tax documents may subsequently require adjustment.

Where the amount originally used for an allocation proves incorrect, the draft requires the mechanism to reconstruct the relevant position.

Conceptually, this may involve:

The regulatory objective is therefore not merely to record the latest balance but to preserve traceability of the entire transaction history.

That is good regulatory design.

It is also technically demanding.

12. Can a prosumer still change electricity supplier?

Yes.

The methodology expressly seeks to prevent the new mechanisms from becoming a contractual prohibition on supplier switching.

A supplier should not condition access to statutory prosumer rights on the customer undertaking to remain with that supplier.

However, there is an important practical distinction between legal freedom to switch and economic continuity of a multi-location structure.

Because the mechanism generally depends on the relevant locations being served by the same supplier, moving one location to another supplier may remove that location from the multi-site structure.

Companies should therefore assess supplier switching not only against electricity prices but also against the value of any existing multi-location settlement structure.

13. What is the "reference location"?

The draft requires the prosumer to designate a reference contractual location for administration of the multi-location option.

This location does not appear to receive an economic priority simply because it is the reference location.

Its purpose is primarily contractual and administrative.

However, the draft also connects certain consequences to changes affecting that reference contract.

This is one area where the final regulation would benefit from further simplification.

If the reference location performs only an administrative function, a change of supplier or other modification affecting that location should arguably permit an easy or automatic migration of the reference function to another eligible site rather than risking disruption of the entire arrangement.

14. What happens to the existing 24-month prosumer balances?

The transition is one of the most important legal issues in the entire reform.

The draft does not simply erase monetary claims or invoices generated under the previous regime.

Existing claims should retain their legal origin and relevant maturity characteristics, including the extended settlement periods applicable under the previous rules where those remain legally relevant.

However, the transition is complicated because the new methodology expressly interacts with:

This creates a material drafting issue.

The transitional framework should be assessed as one package

The draft methodology refers to another ANRE transitional instrument governing contracts concluded before the end of 2026.

For market participants to understand their position with legal certainty, the complete transition should ideally be published and consulted in a consolidated manner.

Suppliers and prosumers need to know precisely:

Without that complete picture, implementation risk remains.

15. What must electricity suppliers do before 1 January 2027?

The draft imposes an ambitious implementation calendar.

Among other obligations, suppliers are expected to:

The difficulty is not the legal principle.

It is the systems integration.

A functioning solution must connect:

This is a significant implementation exercise.

16. Why standardised ANRE test scenarios may be necessary

The methodology determines how the allocation should operate but allows suppliers to develop their own internal procedures and technical implementation.

That creates flexibility, but also risk.

Two independently developed billing systems should not generate different economic results from the same inputs.

A practical solution would be for ANRE to publish a set of mandatory or reference worked examples and test cases.

For example:

The expected output could then be specified by ANRE.

This would enable suppliers to test system conformity before go-live and reduce disputes after implementation.

17. What changes after 31 December 2030?

The reform also prepares the market for another major transition.

Under the legislative framework reflected in the draft, the quantitative compensation mechanism is scheduled to end on 31 December 2030.

Eligible electricity would thereafter move towards a financial-sale model.

An important issue is that the draft does not simply assume that every prosumer will automatically migrate into the replacement contractual structure.

This deserves attention well before 2030.

A residential or small-business prosumer who fails to complete the necessary contractual steps should ideally not find itself injecting electricity into the network under an uncertain commercial arrangement.

A default migration mechanism, subject to a right to choose another lawful commercial arrangement, could provide greater continuity and consumer protection.

18. What does the ANRE proposal mean for corporate energy strategy?

The reform should not be treated merely as an electricity-billing development.

For companies, it creates at least four strategic questions.

1. Should electricity supply be consolidated?

Where multi-site allocation requires a common supplier, the value of consolidation may need to be included in electricity procurement exercises.

2. Where should new rooftop PV capacity be installed?

The economics of a site should consider not only its own self-consumption profile but also whether residual monetary value can be deployed elsewhere.

3. Should existing PV portfolios be analysed together?

Companies may benefit from mapping:

4. How should energy procurement documents change?

Future supply tenders may need to address:

The new regulation may therefore influence energy procurement contracts as much as prosumer contracts themselves.

19. What are the main legal and implementation issues still open?

The draft is generally detailed and represents a significant improvement in the architecture of prosumer settlement.

Several points nevertheless deserve attention before adoption.

Transitional regime

The interaction between legacy contracts, historical balances, the new methodology and the separate transitional ANRE instrument should be made as explicit as possible.

Implementation timetable

The proposed timetable is demanding given the billing, tax, IT and data-exchange changes required.

Supplier system conformity

ANRE may need a stronger ex-ante testing mechanism rather than relying predominantly on subsequent regulatory intervention.

Self-billing objection period

Very short objection periods may be difficult for larger organisations and public bodies.

Reference-location continuity

A purely administrative reference location should not unnecessarily create termination risk for the whole multi-location arrangement.

Post-2030 migration

Automatic or default contractual migration may provide greater legal certainty than requiring passive prosumers to take affirmative steps.

Public-sector implementation

The application of the mechanism to public institutions should be aligned carefully with public accounting, budgetary and payment rules.

20. Is the reform positive for Romanian prosumers?

Broadly, yes.

The proposal addresses one of the structural weaknesses of distributed generation: electricity production and electricity consumption do not always occur at the same place or at the same time.

The new framework does not eliminate that mismatch physically.

But it may allow the economic value generated at one location to become useful elsewhere within the same prosumer portfolio.

For residential prosumers, this can increase flexibility.

For corporate prosumers, it may improve portfolio optimisation.

For suppliers, however, the new regime creates substantial operational obligations.

And for ANRE, the success of the reform will depend less on the legal concept itself than on whether the transition and implementation rules produce consistent outcomes across the market.

Key takeaways

From 1 January 2027, Romania is expected to move to a substantially revised prosumer settlement framework if the ANRE draft is adopted in its current direction.

The principal changes are:

The draft is therefore relevant not only to individual rooftop PV owners, but also to industrial consumers, multi-site businesses, electricity suppliers, public authorities and investors in distributed energy solutions.

Legal status, transition and official sources

The legal position has two layers that should not be conflated. Law no. 160/2026 entered into force on 26 July 2026. The detailed ANRE methodology analysed in this article was published for consultation on 20 August 2026 and remains a draft. Its principal new-contract and multi-site framework is proposed to apply from 1 January 2027.

ANRE's separate transitional proposal addresses existing prosumer contracts and historic balances, including the consequences of the legislative change from 26 July 2026. A business should therefore test its position against the date of each contract, the origin of each balance and the final wording of both ANRE orders, rather than treating every balance as if it followed the same rule.

The primary materials are ANRE's public-consultation page, draft methodology and framework contracts and approval memorandum. ANRE also published a separate transitional consultation and transitional approval memorandum. The consultation deadline stated by ANRE for the methodology is 31 August 2026.

Coordinating legal, contractual and technical workstreams

Multi-site allocation is not only a billing choice. ANRE regulatory advice should be coordinated with PPA, supply and energy-contract support to review supplier consolidation, self-billing, correction rights, payment mechanics and supplier-switching consequences. For rooftop portfolios and distributed generation, renewable-project legal support should also test land, permits, metering and ownership of the production assets.

The commercial model should be tested against the actual asset and load data. Technical development and bankability review can map generation and consumption profiles, while technical compliance and grid-interface support can verify metering, network interfaces and the data required for allocation and reconciliation. Where the portfolio is financed or acquired, technical due diligence should reconcile the operational assumptions with the legal contracts and financial model.

Related market analysis includes our guides to PPAs in Romania, sleeved PPAs for industrial buyers and trading versus aggregation in Romania's power markets.

This article reflects official materials available on 25 August 2026. It is general information and does not constitute legal, technical, tax, accounting or financial advice for a specific prosumer, supplier or portfolio.