How Do Grid Connection Rights Work Across the EU? Romania Compared with All 27 Member States

Direct answer

Grid-connection rights across the EU share principles of objective, non-discriminatory access, network security and increasingly flexible connections, but each Member State defines the documents, queue and milestones that reserve capacity. Romania's ATR is therefore not an EU-wide permit: it is one national instrument whose bankability depends on capacity, firmness, N-1 limits, reinforcement works, guarantees and continuing validity.

Cross-border grid-right matrix

Investor briefing

Grid connection rules are not identical across the European Union, but the underlying technical and investment concepts are remarkably transferable.

An investor familiar with Romanian renewable energy projects will recognise almost everywhere in Europe the same fundamental questions: how much capacity is available, where the project connects, whether the connection is firm or subject to limitations, what happens under an N-1 contingency, which reinforcement works are required, who pays for them, when capacity becomes legally reserved, what milestones preserve that capacity, and whether curtailment can affect project revenues.

What changes from one Member State to another is primarily the legal and procedural architecture through which those questions are answered.

Romania uses the Aviz Tehnic de Racordare – ATR, followed by the connection agreement and ultimately the connection certificate. Spain separates access and connection rights. Portugal uses a capacity-reservation title. Italy relies heavily on the connection estimate and the STMG technical solution. Greece uses a Final Connection Offer. Poland issues connection conditions. The Netherlands makes a particularly important distinction between the physical connection and the contractual right to transport electricity through a congested network.

There is therefore no EU-wide equivalent of the Romanian ATR.

There is, however, an increasingly recognisable European concept of a grid connection right.

For investors, developers and lenders, this means that the correct cross-border question is not:

“Does the project have an ATR?”

It is:

“What document or combination of documents gives this project an enforceable right to inject or withdraw a defined amount of power, at which connection point, under what technical conditions, and subject to what limitations?”

That question works across the European Union.

1. Why grid connection has become one of the principal investment risks in European renewables

Grid access was once treated primarily as an engineering and permitting workstream. Increasingly, it is a scarce economic resource.

Rapid deployment of solar, wind and battery energy storage systems has produced situations in which the nominal pipeline of projects is substantially larger than the capacity that existing electricity networks can immediately accommodate.

The consequence is visible across Europe:

grid capacity has become an asset in itself.

Project value may therefore depend not only on land rights, environmental approvals, construction permits or technology, but on the quality of the project's grid position.

For a buyer acquiring a renewable energy or BESS project, a statement that the project has “100 MW of grid capacity” is no longer sufficiently precise.

The investor needs to determine whether those 100 MW represent:

This distinction is increasingly central to European renewable energy due diligence.

2. The technical language is already substantially European

The technical foundation of grid analysis is much more harmonised than the national permitting terminology might suggest.

Commission Regulation (EU) 2017/1485 establishing the guideline on electricity transmission system operation expressly defines concepts such as:

• N-situation – the network configuration in which no relevant transmission-system element is unavailable because of a contingency

• contingency – broadly, the outage or failure scenario being analysed for system security purposes

• N-1 criterion – the rule according to which, after a relevant contingency occurs, the elements remaining in operation must be capable of accommodating the resulting network condition without violating operational-security limits

remedial action – a measure used to maintain or restore secure network operation.

These concepts are therefore not Romanian inventions.

A grid engineer in Bucharest, Madrid, Warsaw, Paris or Berlin may work under different national procedures, but the underlying question is substantially the same:

What happens to the network if a relevant line, transformer or other network element becomes unavailable?

This is why knowledge of N and N-1 analysis is highly transferable between European jurisdictions.

3. N, N-1 and contingency risk in practical terms

Assume that a 100 MW BESS connects to a network through infrastructure whose normal configuration includes two relevant transmission paths.

Under the N condition, all relevant elements are available.

If the system can accommodate the full 100 MW without violating thermal, voltage, stability or other operational limits, the project is technically acceptable in the intact-grid configuration.

The network study then tests contingencies.

Suppose one relevant line becomes unavailable.

The network is now operating under an N-1 condition.

If the remaining infrastructure can still accommodate the project's output, the project remains technically secure at full capacity.

If the remaining infrastructure becomes overloaded, the operator needs a solution.

Conceptually, the principal options are:

This last solution is increasingly important throughout Europe.

4. Operational limitation is not uniquely Romanian

Romanian projects frequently refer to limitări operaționale and to an ALO – automatizare de limitare operațională.

The terminology is local.

The concept is not.

Across European markets, investors will encounter expressions such as:

flexible connection, non-firm connection, conditional connection, active-power limitation, automatic curtailment, restricted export capacity, flexible import or export capacity, or congestion-based connection arrangements.

The precise mechanism differs, but the economic logic is similar.

Instead of requiring all reinforcement works to be completed before a project connects at its nominal capacity, the project may connect earlier provided it accepts defined limitations when the network reaches specified operational conditions.

The 2024 reform of the EU electricity market makes this direction particularly clear.

Directive (EU) 2024/1711 inserted Article 6a into Directive (EU) 2019/944 and requires national frameworks allowing transmission and distribution system operators to offer flexible connection agreements in areas where firm network capacity is limited or unavailable.

European legislation therefore increasingly recognises a distinction between:

firm capacity, and additional flexible capacity subject to operational restrictions.

For BESS projects, this distinction must be analysed in both directions:

export / discharge, and import / charging.

A 100 MW BESS should not automatically be assumed to have 100 MW of firm capacity in both directions merely because its installed power is 100 MW.

5. Reinforcement versus flexible connection: the economic decision behind the engineering

One of the most important project-development decisions is whether to accept a constrained connection or wait for – or participate in – network reinforcement.

Consider two alternatives.

A project may connect in 2027 but accept an operational limitation under a relatively rare N-1 contingency.

Alternatively, it may obtain a substantially firmer connection only after a reinforcement scheduled for 2029.

The economically rational choice cannot be determined simply by asking whether curtailment exists.

It requires comparing:

the expected economic cost of curtailment

against

the cost and timing consequences of reinforcement.

For a renewable generator, the curtailment analysis may focus primarily on lost export.

For a battery, the analysis is more complex because restrictions can affect both charging and discharging, arbitrage opportunities, balancing-market participation, ancillary services and contractual availability obligations.

The appropriate investment question is therefore:

> What is the expected curtailed energy and revenue exposure over the relevant period, and how does its present value compare with the cost and delay associated with the alternative reinforcement solution?

This is a bankability question, not merely an engineering one.

6. Curtailment and redispatch must also be distinguished

Operational limitation embedded in a connection arrangement should not automatically be treated as equivalent to every form of system redispatch.

Regulation (EU) 2019/943 establishes European rules on redispatching and provides, as a general principle, for objective, transparent and non-discriminatory selection and financial compensation of redispatched resources.

However, the legal and economic treatment changes where a project has voluntarily accepted a connection arrangement under which firm delivery is not guaranteed.

This distinction is important in due diligence.

An investor should determine whether a reduction in output constitutes:

a contractual or regulatory limitation inherent in the project's grid right, or

a subsequent system redispatch measure affecting an otherwise firm connection.

The compensation regime may be materially different.

7. Romania's grid-connection architecture

For Romanian projects, the principal legal and technical chain remains recognisable:

connection application → connection study / solution study → ATR → connection agreement → connection works and compliance → connection certificate.

The ATR establishes the project's individual technical and economic connection conditions.

Depending on the project, this may include:

For larger projects falling within the current capacity-allocation framework, an additional upstream layer has become important.

Romania's methodology for allocating available network capacity introduces a competitive mechanism for projects within its scope, including relevant projects of at least 5 MW.

The conceptual sequence therefore becomes:

capacity allocation → project-specific technical connection process → ATR → connection agreement → implementation.

Winning or securing capacity through an allocation mechanism does not by itself answer every project-specific connection question.

The technical study and ATR remain essential because allocated MW still need to be translated into a physical and operationally viable connection.

This distinction is especially important in M&A.

A buyer should distinguish between:

capacity allocated to a project, and the complete technical and contractual conditions under which that project will actually use the capacity.

8. There is no European “ATR” – but there are functional equivalents

The term ATR should normally be explained to a foreign investor rather than translated literally.

“Technical Connection Approval” may communicate its meaning, but the better cross-border approach is to explain its function.

The ATR combines elements that other European jurisdictions may place in several separate instruments.

The functional question is always:

> Which document defines the project's approved network capacity, connection point, technical conditions, reinforcement requirements and operational restrictions?

Depending on the jurisdiction, that may be a connection offer, connection consent, connection conditions, access permit, capacity-reservation title, technical solution or connection agreement.

The following comparison is therefore functional rather than terminological.

9. Grid connection across all 27 EU Member States

The table should not be read as suggesting that these documents are legally interchangeable.

They are not.

Its purpose is to show that the same investment questions repeatedly reappear under different names.

10. Five European grid-connection models are emerging

Rather than treating Europe as 27 entirely separate systems, investors can usefully think in terms of several broad models.

10.1 Connection-conditions model

This family includes systems where an operator studies the project and issues individual technical conditions or an offer before a connection agreement is implemented.

Romania, Bulgaria, Greece, Poland, Croatia, Slovenia, Czechia and Slovakia display important elements of this model.

For a Romanian adviser, these systems are relatively intuitive.

The terminology changes; the analytical structure does not.

10.2 Competitive scarce-capacity model

Where requested capacity substantially exceeds available capacity, some jurisdictions increasingly use competitive allocation.

Romania's post-2024/2026 capacity regime is an important example.

Competitive allocation also appears in different forms in jurisdictions such as Hungary, Spain and Portugal.

The critical distinction is:

allocation answers who obtains access to scarce capacity;

the connection process answers how that project physically and technically connects.

These should not be conflated.

10.3 Queue and network-planning model

France is a particularly clear example of a system where project queues interact with regional network-development frameworks.

The investor must therefore understand not only the individual connection documentation but also the network-development environment in which the project sits.

The same commercial question still applies:

> How much capacity is genuinely available to this project, when, and at what reinforcement cost?

10.4 Flexible or non-firm connection model

The Netherlands, Belgium, Sweden, Denmark and several Baltic and Central European systems increasingly demonstrate elements of this approach.

The idea is economically powerful:

do not necessarily wait years for a fully reinforced network if the project can connect earlier under controlled operating restrictions.

EU legislation now expressly encourages national frameworks for flexible connection agreements in constrained network areas.

This model is likely to become increasingly important as electrification, renewable generation and storage expand faster than network construction.

10.5 Batch and project-maturity model

Ireland provides the clearest example of an organised batch-style connection process.

Finland is also increasingly emphasising project maturity before network capacity receives a stronger commitment.

These mechanisms respond to a common European problem:

speculative projects can consume apparent grid capacity without reaching construction.

The regulatory answer is increasingly to require evidence that a project is real.

11. The European move from “first come, first served” to “first credible project”

This is one of the most important policy trends in European grid access.

A simple first-come-first-served system creates an obvious incentive:

apply early, reserve capacity, and determine later whether the project will actually be built.

Where grid capacity becomes scarce, this behaviour can sterilise network capacity.

European jurisdictions are therefore increasingly introducing combinations of:

financial guarantees, application fees, project-development milestones, permitting deadlines, construction deadlines, capacity-release provisions, competitive allocation, and project-maturity tests.

Romania's recent reforms should be understood in this wider context.

Financial guarantees and tighter development milestones are not simply additional administrative burdens.

They are instruments designed to distinguish genuine projects from speculative capacity reservations.

For foreign investors, this makes Romania easier to explain:

the country is participating in the same broader European transition from passive capacity reservation towards commitment-based grid allocation.

12. The Netherlands illustrates why “connected” does not always mean “grid capacity secured”

The Netherlands is particularly useful for demonstrating why international investors must avoid literal document comparisons.

A project can have a physical network connection while facing separate limitations on its ability to use network transport capacity because the relevant area is congested.

This distinction makes the following question dangerous:

“Is the project connected?”

The better questions are:

How many MW can physically be connected?

and separately:

How many MW of transport capacity can the project contractually use, and how much of that right is firm?

For Romanian due diligence, the comparable lesson is broader:

the physical installation, the approved MW figure and the economically usable grid right should never be assumed to be identical without reviewing the complete grid file.

13. How to analyse an ATR-equivalent anywhere in Europe

For cross-border due diligence, the name of the document matters less than the questions it answers.

A robust grid review should reconstruct at least the following matrix:

This matrix can be applied substantially throughout the EU.

14. Operational limitations should be quantified, not merely flagged

One of the most common weaknesses in grid due diligence is to identify a curtailment provision and stop there.

For example:

“The project may be curtailed to 0 MW under N-1.”

That statement sounds severe, but it does not yet quantify the investment risk.

The real questions are:

Which contingency activates the limitation?

How frequently has that network element historically been unavailable?

Were those outages planned or forced?

How long did they last?

Does every outage automatically activate the maximum limitation?

What was the project likely to be doing during those periods?

Which network reinforcement would remove the constraint?

When is that reinforcement expected?

The economic risk can then be modelled more realistically:

> expected frequency × expected duration × MW actually curtailed × economic value of lost operation.

For a BESS, the calculation should consider not only energy volumes but potentially lost arbitrage, balancing, ancillary-service and availability revenue.

A nominally severe limitation may therefore be economically modest if the relevant contingency is extremely rare.

Conversely, a seemingly moderate MW restriction can become material if it occurs frequently during valuable operating periods.

15. Why the distinction between buyer and seller matters

Grid connection risk is often described differently depending on which side of the transaction is speaking.

A seller may state:

“The project has a 100 MW grid connection.”

A buyer should reconstruct the statement more precisely:

> The project has 100 MW of approved export capacity at the relevant connection point; operation is subject to specified N-1 limitations; reinforcement X remains outstanding; capacity preservation depends on milestones Y and Z; and the connection right may be affected if specified guarantees or deadlines are not maintained.

Both statements may refer to the same project.

Only the second is useful for valuation.

This is why grid diligence should directly inform the transaction documents.

Material grid risks may need to become:

conditions precedent, specific warranties, seller covenants, long-stop mechanisms, price-adjustment provisions, indemnities, retentions, or termination rights.

A technically complex grid issue therefore frequently becomes a legal risk-allocation issue in the SPA.

16. BESS requires a more sophisticated grid analysis than conventional generation

Battery storage makes cross-border grid diligence even more important because the asset can operate in both directions.

For solar or wind, the principal connection question historically concerned export.

For a standalone BESS, investors should separately establish:

maximum approved export capacity;

maximum approved import capacity;

firm export capacity;

firm import capacity;

operational restrictions affecting each direction;

whether charging and discharging restrictions differ;

whether restrictions interact with congestion-management arrangements;

whether the project can perform the revenue activities assumed in its financial model.

A 100 MW / 200 MWh battery with a technically installed 100 MW PCS is not economically equivalent to a battery with a firm 100 MW import-and-export network right.

That distinction will become increasingly important as European BESS transactions mature.

17. How Romanian grid terminology should be explained to international investors

Romanian terminology can be translated into internationally intelligible concepts without suggesting that the legal instruments are identical.

Using this language avoids over-explaining Romanian law while still accurately describing the local mechanism.

18. How Romania should be positioned in discussions with European investors

Romania should not be presented as having a fundamentally unusual grid system.

A more accurate description is:

> Romania applies the same underlying European technical principles for grid security and connection analysis, including N and N-1 assessment, network reinforcement and operational-security constraints. Its local grid-right instrument is the ATR, followed by the connection agreement. For projects within the current capacity-allocation regime, scarce capacity is increasingly allocated competitively and protected by financial guarantees and development milestones. Operational limitations can also form part of the connection solution, conceptually comparable with flexible or non-firm connection arrangements increasingly used elsewhere in Europe.

That explanation places Romania immediately inside the European framework.

The remaining work is jurisdiction-specific rather than conceptual.

19. What a Romanian energy professional can carry into another EU jurisdiction

A professional who genuinely understands a Romanian connection file should already understand much of the analytical framework required elsewhere in Europe.

The transferable knowledge includes:

What must be relearned in each jurisdiction is principally:

which document creates the relevant right;

when capacity becomes reserved;

what determines priority;

whether capacity is firm or flexible;

who pays for reinforcement;

what keeps the right alive;

whether curtailment is compensated;

and

how the grid right interacts with local permitting and project-development milestones.

This is a materially smaller learning exercise than rebuilding grid expertise from zero.

20. Conclusion: the real skill is not ATR analysis – it is grid-right bankability analysis

The ATR is an important Romanian legal instrument.

But from an international investment perspective, the more valuable skill is broader.

It is the ability to determine whether a project's apparent network capacity constitutes a durable, financeable and economically usable grid right.

Across Europe, that analysis increasingly requires combining legal and technical diligence.

A document stating “100 MW” is only the beginning.

The investor must understand:

where the 100 MW connect;

whether they apply to import, export or both;

whether they are firm;

what happens in N-1;

which contingencies create restrictions;

whether those restrictions are compensated;

which reinforcement works remove them;

who pays for those works;

when those works will be completed;

which guarantees and milestones preserve the capacity;

and

whether another project, queue rule, auction result or network constraint can alter the expected connection path.

Those questions are increasingly universal across the European renewable energy market.

The legal documents differ.

The investment problem does not.

For investors acquiring or financing solar, wind and battery-storage projects in Romania, understanding the ATR, the underlying connection study and the connection agreement therefore provides more than local regulatory knowledge.

It provides a practical framework for understanding grid connection risk across Europe.

Official sources and methodology

The common EU layer is grounded in Commission Regulation (EU) 2017/1485 for N-1, contingency analysis and remedial actions; Commission Regulation (EU) 2016/631 for generator connection requirements; and Regulation (EU) 2019/943 for congestion and redispatching. Directive (EU) 2024/1711 inserted Article 6a into Directive (EU) 2019/944, requiring frameworks for flexible connection agreements where firm capacity is limited or unavailable.

The 27-country comparison is a functional synthesis supported by the European Commission's Guidance on efficient and timely grid connections and the Commission study covering network planning, tariffs and connection requests in all 27 Member States. It is not an exhaustive statement of each national regime. Voltage level, technology, operator, project stage and later legal changes can alter the applicable document and priority rules.

For Romania, the principal project-level sources include the consolidated ANRE Connection Regulation and the capacity-allocation framework introduced by ANRE Order no. 53/2024. Each cross-border investment still requires current local-law and operator-rule verification.

Coordinated legal and technical support

Start with Energy Law and grid connection and permitting advice to identify the Romanian right, its validity and the procedural route. Energy M&A and project-finance counsel can translate cross-border grid findings into valuation, conditions precedent, warranties and lender protections, while battery-storage advice addresses separate import and export exposure for BESS.

The legal conclusion should be tested against engineering evidence through technical grid-interface advisory, renewable-energy technical due diligence and lender's technical advisory. Related analysis includes Romania's 2026 grid reform, earlier ATRs and post-connection curtailment and what an ATR means in Romanian energy projects.

This article reflects sources available on 25 August 2026. It is general information, not legal, technical or financial advice for a specific project or jurisdiction.