Private capital is no longer optional for Southeast Europe’s energy transition—it is becoming the decisive factor in whether the region can absorb the scale of renewable capacity already in the pipeline.
The core issue is simple. The grid—transmission, distribution and flexibility—must expand at a pace that public balance sheets alone cannot sustain. The scale of required investment across Southeast Europe is already moving into multi-billion-euro territory per country, once transmission upgrades, cross-border corridors, battery storage and digitalisation are included. Traditional funding sources—state utilities, sovereign budgets and EU grants—remain essential, but they are no longer sufficient on their own.
The question is not whether private capital can participate. It is how it can be structured to enter a system historically dominated by state-owned infrastructure and regulated tariffs.
The investment gap is structural, not cyclical
Across Southeast Europe, grid operators are facing a dual pressure.
On one side, renewable project pipelines are accelerating. Solar and wind capacity announcements now exceed what current grids can absorb without curtailment or connection delays.
On the other side, grid investment cycles remain slow, capital-intensive and politically sensitive. Transmission expansion—particularly 400 kV corridors—requires long permitting timelines, cross-border coordination and significant upfront capital.
The mismatch creates an investment gap.
In Serbia, Bosnia and Herzegovina, Montenegro and North Macedonia, transmission system operators are largely state-owned, with limited capacity to raise capital at the scale and speed required. Even where EU funding is available, it typically covers only part of project costs and is often tied to lengthy approval processes.
This is where private capital becomes critical.
Transmission: The most challenging segment for private entry
Transmission remains the most difficult segment for private participation.
High-voltage networks are considered strategic infrastructure, typically owned and operated by national TSOs. Revenues are regulated, and tariff-setting mechanisms are often conservative, limiting returns.
However, models for private participation are beginning to emerge.
In parts of Central and Western Europe, transmission expansion has been supported through:
• Regulated asset base (RAB) models with private co-investment
• Public-private partnerships (PPPs)
• Project-specific concession structures for new lines or interconnectors
These models can be adapted to Southeast Europe, particularly for cross-border projects where multiple jurisdictions share benefits.
For example, major corridors such as the Trans-Balkan 400 kV upgrades or Bosnia–Montenegro interconnections could be structured with partial private financing, backed by regulated returns and multilateral guarantees.
The key challenge is regulatory clarity.
Private investors require:
• Transparent tariff frameworks
• Predictable return mechanisms
• Clear rules on asset ownership and operation
Without these, capital will remain cautious.
Distribution networks: A more accessible entry point
Distribution networks offer a more immediate opportunity for private capital.
Unlike transmission, distribution systems are often more fragmented and closer to end users. They are also directly affected by the rise of distributed generation—particularly commercial and industrial solar installations.
Investment needs at this level include:
• Grid reinforcement for two-way power flows
• Digitalisation and smart metering
• Integration of local storage and flexibility
These investments are smaller in scale but more numerous, making them suitable for portfolio-based financing structures.
Private capital can enter through:
• Minority stakes in distribution companies
• PPPs for grid modernisation
• Financing of specific upgrade programmes
Returns are typically lower than in generation, but more stable, aligning with infrastructure investment profiles.
Battery storage: The fastest route for private capital
Battery energy storage represents the most immediate and scalable entry point for private investors.
Unlike transmission, storage assets can be developed and owned by private entities, often without the need for full regulatory overhaul. They also offer exposure to multiple revenue streams, including:
• Intraday and day-ahead arbitrage
• Balancing and ancillary services
• Capacity-like value during peak demand
With capital costs currently in the range of €350–500/kWh, utility-scale BESS projects require investments of €15–30 million per 50–70 MWh system—a scale well suited to infrastructure funds, private equity and strategic investors.
Return profiles are increasingly attractive:
• Base case IRR: 10–12%
• Upside (high volatility): 13–16%+
The key driver is volatility. As renewable penetration increases, price spreads widen, creating monetisable opportunities.
For private capital, BESS offers a combination of:
• Relatively short development timelines
• Scalable deployment
• Exposure to market dynamics
This makes it a natural entry point into the region’s energy transition.
Renewable-linked infrastructure: Hybrid investment models
Another emerging opportunity lies in hybrid projects combining generation, storage and grid integration.
These projects blur the boundaries between traditional asset classes.
A solar-plus-storage project, for example, may include:
• Generation capacity
• On-site or co-located storage
• Dedicated grid connection infrastructure
From an investment perspective, this creates a more complex but also more attractive asset.
Revenue streams are diversified, combining:
• Contracted PPA revenues
• Market-based trading income
• Flexibility services
For lenders, this improves bankability. For equity investors, it provides both stability and upside.
In Southeast Europe, where standalone grid investments can be difficult, hybrid projects offer a way to embed infrastructure investment within generation assets.
Industrial offtake as a credit anchor
One of the most significant developments is the role of industrial offtakers.
Energy-intensive industries across the region are increasingly seeking renewable electricity to manage carbon exposure. This creates demand for long-term PPAs, which in turn support project financing.
From a private capital perspective, these offtakers act as credit anchors.
Unlike traditional corporate PPAs, where electricity is a discretionary cost, CBAM-exposed industries have strong incentives to maintain renewable supply. Electricity sourcing becomes linked to export viability, strengthening contract durability.
This improves the risk profile of projects and supports higher leverage.
It also creates opportunities for direct investment partnerships, where industrial companies co-invest in renewable or storage assets to secure supply.
Role of multilateral institutions
Private capital in Southeast Europe does not operate in isolation.
Multilateral institutions such as the EBRD, EIB and World Bank play a critical role in de-risking investments through:
• Co-financing structures
• Guarantees and credit enhancement
• Policy support and regulatory alignment
These institutions act as bridges between public and private capital, reducing perceived risk and enabling larger investment flows.
In many cases, private investment is contingent on multilateral involvement, particularly in early-stage markets.
Market design will determine capital flow
Ultimately, the ability of private capital to finance grid and flexibility infrastructure depends on market design.
Key enablers include:
• Transparent and predictable tariff frameworks
• Functional ancillary service markets
• Clear rules for storage participation
• Efficient cross-border capacity allocation
Without these, revenue visibility remains limited, constraining investment.
Conversely, well-designed markets can unlock significant capital.
In regions where flexibility services are properly valued and remunerated, storage and grid investments become commercially viable without heavy subsidies.
A capital shift underway
The direction of travel is clear.
Southeast Europe’s energy transition is moving from a state-led model to a mixed capital model, where private investment plays an increasingly central role.
The drivers are structural:
• Rapid growth in renewable capacity
• Increasing need for flexibility
• Carbon-linked industrial demand
Public capital alone cannot meet these needs.
Private capital, if properly structured and supported, can.
The challenge is not availability of capital. Global infrastructure funds, pension funds and strategic investors are actively seeking opportunities in energy transition assets.
The challenge is creating the conditions under which that capital can be deployed efficiently.
From constraint to opportunity
If those conditions are met, Southeast Europe’s grid challenge can become an investment opportunity.
Transmission corridors, storage assets and distribution upgrades are not just costs. They are long-term infrastructure investments with stable returns and strategic importance.
For the region, the stakes are high.
Failure to mobilise private capital risks slowing the energy transition, increasing curtailment and undermining industrial competitiveness.
Success would position Southeast Europe as a dynamic, integrated energy market, capable of attracting investment and supporting economic growth in a carbon-constrained Europe.
In that sense, private capital is not just a financing tool.
It is a key enabler of the region’s future energy and industrial model.
Elevated by virtu.energy