Romania is introducing competitive auctions for access to the electricity grid, making transmission and distribution capacity an explicitly priced requirement for investment. The system could affect project valuations, financing costs and the market for existing electricity assets. National transmission operator Transelectrica will hold the first competitive capacity-allocation sessions on October 30, offering 1,566 MW of future connection capacity in designated network zones, subject to additional network development.
Published opening prices range from approximately €136,000 to €719,000 per MW, depending on location, connection year and network classification; winning prices may be higher. The offered capacity is concentrated between 2032 and 2037, reflecting long waits for some categories of new electricity projects. Romania is moving away from the traditional first-come, first-served approach for qualifying projects, requiring developers instead to show their willingness and financial ability to pay for scarce network access.
The change extends beyond grid engineering for infrastructure investors. A project’s financial value increasingly depends on its connection rights, the contractual security of those rights and the date when electricity can physically enter the network.
Capacity allocations begin in 2032 and carry different opening prices
Transelectrica’s published allocation schedule covers 2028–2037, but the latest assessment identifies no capacity available under the new auction mechanism before 2032. The operator is offering 412 MW in 2032, 80 MW in 2035, 862 MW in 2036 and 212 MW in 2037. The 2036 allocation is the largest, representing approximately 55% of the total capacity offered.
These figures cover capacity made available through identified additional network development works. They do not mean that Romania has prohibited all new electricity connections before 2032: existing connection approvals, other applicable procedures and projects outside the auction mechanism must be considered separately. The new system divides the electricity network into 10 allocation zones, each with its own capacity volumes and opening prices.
The lowest published starting price is approximately €136,000/MW for capacity in Zone D in 2036. The highest is approximately €719,000/MW for a different network-category allocation in Zone D in 2037. These prices show the variation in network-capacity economics, but they are not directly comparable alternatives for the same project.
A hypothetical 100 MW development facing those respective opening prices would incur a capacity-allocation cost of approximately €13.6 million or €71.9 million, before additional connection expenditure. This illustrates potential financial exposure, not the actual cost of a specific eligible project. Developers must separately finance substations, connection lines, installation works and other applicable infrastructure; the winning auction price is an additional cost of securing capacity, not an all-inclusive construction budget.
Financial guarantees add costs and liquidity requirements
The new mechanism also imposes stricter financial requirements. Qualifying developers had to provide a participation guarantee of €20,000/MW when submitting applications, equivalent to €2 million in committed financial security for a 100 MW project before competitive bidding. Under Transelectrica’s procedures, unsuccessful bidders can recover their guarantees, while successful participants recover them after completing the prescribed contractual steps.
Successful bidders must also provide a further guarantee equal to 1% of the allocation contract value before finalising their capacity-allocation agreements. Failure to sign the required agreement and provide the prescribed guarantee by the applicable deadline can lead to the loss of allocated capacity and enforcement of the participation guarantee. The requirements are intended to deter applications from developers without sufficient financial resources or credible implementation plans, while creating additional liquidity needs for legitimate investors.
For project-finance banks, the auction adds an expenditure category to be assessed alongside land acquisition, environmental approvals, construction, equipment procurement and conventional connection costs. The challenge is particularly significant for projects expected to enter commercial operation six to eleven years in the future. Long development periods expose investors to higher financing costs, regulatory changes, equipment-price fluctuations and uncertainty over future electricity-market revenues.
A project that appears profitable before connection-rights expenditure may become economically unattractive after the auction price and other development costs are included. Romania’s mechanism therefore changes the assumptions used in project financing before a project reaches financial close.
Romgaz and private developers apply for capacity
The initial application phase attracted 12 projects representing 491 MW, according to published Transelectrica application data. Romanian state-controlled energy producer Romgaz submitted proposals for two photovoltaic projects with storage, each of 20 MW, and a 100 MW standalone storage installation near Iernut. Other applicants include companies associated with Turkish investment groups.
Energy Capital Group, associated with the Güris group, submitted a 51 MW storage project. Hessmaier, linked to the FIBA group, registered several proposed generation and storage developments. The applications cover different technologies, locations and intended commissioning dates, and include both established energy companies and private investors examining the new framework.
Applications are not completed investments, financing commitments or awarded connection rights. Nor can the 491 MW of initial requested capacity be directly compared with the 1,566 MW offered across different zones and years to determine whether individual auctions are oversubscribed. A project may need capacity in a location or year where the relevant allocation is unavailable, even when capacity exists elsewhere in the system.
The allocation process is scheduled to run on successive working days through November 12, with separate sessions for the relevant allocation years. As bidding begins, final prices, winning allocations and successful contracts have yet to be established. The outcome will depend on whether technically suitable capacity can be matched with projects prepared to pay the required price and accept the implementation timetable.
Existing grid rights may affect asset valuations
Competitive allocation distinguishes projects with established grid-access arrangements from those still seeking capacity. An operating installation with secure injection rights and proven physical access to the electricity system may carry a different risk profile from an otherwise comparable development that needs a future auction award. This distinction could become more prominent in acquisitions, refinancing and project-portfolio valuations.
Investors acquiring electricity assets will increasingly need to examine the legal validity, technical scope and contractual restrictions of grid-connection arrangements. Relevant matters include permitted export capacity, connection date, the validity of technical approvals, required reinforcement works and conditions affecting changes of ownership or project configuration. Connection approvals should not be treated as freely transferable financial instruments: their value depends on the applicable legal framework, contractual provisions and technical obligations.
Scarcity could nevertheless create a commercial premium for projects able to demonstrate reliable, enforceable and timely network access. Investment funds may shift towards acquiring advanced projects with completed permits and credible grid rights rather than large early-stage development pipelines. For banks, a valid connection position could carry greater weight in collateral assessments and project due diligence, although it cannot replace a bankable revenue model.
The market may consequently place greater value on demonstrated deliverability than announced installed capacity. Lenders generally assess repayment capacity against construction expenditure, projected electricity revenues, operating costs, debt-service obligations and downside scenarios; network-capacity expenditure must now be included in the capital budget before financial close.
Grid costs and delivery schedules enter financing assessments
Timing is important when substantial funds must be committed years before construction or electricity delivery, leaving investors without operating income for longer. A future connection that depends on several network-reinforcement projects also creates technical and scheduling dependencies beyond the developer’s immediate control. Banks may therefore require more detailed independent-engineering assessments and stronger contractual protections before accepting proposed commissioning dates.
Investment committees will need to distinguish the price paid to secure an allocation from the cost of physical connection, the cost of financing the development period and the probability of completing the project on schedule. The auction may also create demand for specialist advisory work in grid-rights due diligence, capacity-allocation strategy, engineering assessment and project restructuring. Developers may reconsider planned connection locations, capacity sizes or ownership structures if auction costs exceed what their projects can support.
Romania’s approach offers a regional reference point
Romania’s system provides a regulatory case study for the wider Southeast European electricity market. Serbia faces substantial pressure on transmission connection capacity and growing uncertainty over the timing of access for new projects, but has not introduced an equivalent general competitive auction regime for transmission connection rights. The Romanian experience illustrates how scarce grid capacity can affect the financing and valuation of electricity investments.
For Serbia’s independent power producers, acquisition targets and infrastructure lenders, the practical issue is the cost and reliability of securing a deliverable grid connection. Montenegro faces a different challenge because its electricity system and domestic investment market are smaller; there, the timing and technical conditions of grid access can strongly influence individual project economics. A competitive capacity-pricing system may not suit every network or market structure, but Romania’s framework provides a reference for assessing transparent allocation, financial guarantees and the management of speculative connection applications.
Similar questions arise in Bulgaria, Croatia and North Macedonia, where developers must reconcile investment plans with limited network availability and changing technical requirements. For regional investors active in several electricity markets, connection rights could become a substantial and unevenly priced component of infrastructure expenditure.
Connection access becomes a project-bankability factor
Romania’s first capacity auction marks a change in the relationship between electricity infrastructure developers and the transmission network. Investment discussions have traditionally focused on technology costs, financing conditions and expected electricity-market revenues; the competitive allocation system adds the cost of obtaining network access at a particular location and date as another measurable economic factor.
The system’s effectiveness will depend on whether it attracts credible projects, produces commercially sustainable prices and helps turn planned network reinforcement into operational capacity. High opening prices and distant connection dates could strengthen financial discipline in the development market, but could also deter otherwise viable investments. The first auction results will show whether developers accept the costs and whether the available allocations match actual demand.
For lenders and infrastructure investors across Southeast Europe, the reform offers an early indication of a broader change in electricity investment economics. Grid connection is no longer simply a technical milestone before construction; it is becoming a separately priced investment requirement that can determine whether a project is financially viable. As competition for network access intensifies, an electricity asset’s value will increasingly depend not only on how much power it can produce, but also on when, where and under what enforceable conditions that power can reach the market.