Southeast Europe has developed increasingly sophisticated short-term electricity markets, but the ability to transfer risk further along the curve remains uneven. That gap is becoming one of the region’s most important trading challenges as generators, suppliers and industrial consumers face increasingly volatile merchant exposure and seek greater price certainty.
The SEE spot market has changed significantly.
Romania, Bulgaria, Hungary, Croatia, Slovenia and Greece are increasingly integrated into broader European day-ahead and intraday structures. Quarter-hour pricing has improved market granularity, while market coupling plays a growing role in determining cross-border flows. Serbia operates its own organised spot market and remains closely watched by regional trading desks.
Yet when a generator asks a different question — “What price can I lock in for next year?” — the regional market becomes considerably less uniform.
That is the central paradox of SEE electricity trading.
Short-term price discovery is becoming more sophisticated, while long-term risk transfer remains fragmented.
This matters because most electricity businesses cannot operate solely on a day-to-day basis.
A renewable generator may want to hedge a substantial portion of next year’s production. A supplier may have agreed fixed-price contracts with industrial customers. An industrial consumer may need budget certainty, while a trading house may want to warehouse seasonal or structural risk.
All of them require an effective forward market.
EEX now offers a broad range of SEE-related power futures, including Hungarian, Romanian, Bulgarian, Serbian, Slovenian and Greek contracts across different monthly, quarterly and annual maturities. Location-spread structures such as Hungary-Serbia, Hungary-Romania, Hungary-Bulgaria, Hungary-Slovenia and Hungary-Greece further recognise that regional participants face location risk as well as outright price risk.
This represents important market infrastructure.
Hungary has also taken another step in integrating derivatives with the physical market following the phase-out of HUDEX. In 2026, cooperation between HUPX and EEX enabled physical delivery of Hungarian power futures, strengthening the connection between the futures market and HUPX day-ahead activity.
EEX had also extended its Future-to-Spot mechanism to Hungary, allowing eligible futures positions to feed corresponding bids into the HUPX day-ahead auction.
But the availability of products does not automatically create deep and reliable liquidity.
That remains one of the central challenges for Southeast European power markets.
In Germany, participants can rely on a mature derivatives ecosystem with broad participation, established market makers and substantial clearing infrastructure.
Many SEE products continue to operate in thinner markets.
That can result in wider bid-ask spreads, greater difficulty executing large transactions and stronger dependence on established OTC relationships.
OTC trading is therefore not simply a legacy mechanism waiting to disappear.
Across much of Southeast Europe, it remains essential market infrastructure.
Bilateral EFET-style agreements allow counterparties to negotiate credit terms, delivery structures, volumes, profiles and locations that may not be efficiently available through listed products.
The trade-off is greater dependence on counterparty relationships and credit capacity.
A participant with strong bilateral relationships can therefore have materially better access to forward liquidity than a smaller market participant.
This is why the development of forward markets and the development of credit and collateral infrastructure are closely connected.
Another structural challenge is proxy hedging.
Consider a Serbian renewable generator that cannot obtain sufficient liquidity in Serbian forward products. It may use HUPX as a proxy hedge.
The strategy reduces exposure to the outright electricity price, but it leaves the Serbia-Hungary basis open.
If Serbian power settles €5/MWh above Hungary when the hedge is realised, the generator’s physical revenue and Hungarian hedge will not fully offset each other.
The same issue appears whenever a participant uses a more liquid neighbouring market to hedge a less liquid domestic exposure.
Proxy hedging is therefore not a perfect hedge.
It transforms outright price risk into basis risk.
For sophisticated trading desks, that may be an acceptable and actively managed exposure. For smaller generators or industrial consumers, the residual risk can be much less visible.
There is also another problem: shape.
A baseload future can hedge average electricity prices while providing only limited protection against the actual capture price of a solar or wind portfolio.
As renewable penetration increases, generation can become concentrated in periods when wholesale prices are structurally lower.
A producer can therefore have a successful annual baseload hedge while still carrying substantial profile and capture-price risk.
The forward market of the future will need to address more than country and maturity.
It will increasingly need to price location, shape and timing.
This creates an important role for trading houses.
They can intermediate risks that standardised exchange products cannot always efficiently capture, including renewable generation profiles, balancing exposure, cross-border basis and customised load shapes.
That intermediation carries an economic value and therefore a margin.
The strategic question is whether Southeast Europe will gradually transfer more of this risk onto transparent, cleared markets or continue relying on a combination of exchanges, OTC agreements and proxy hedges.
The most likely outcome is a hybrid model.
Listed markets can provide transparency, standardisation and clearing, while OTC markets continue to handle customised structures and exposures where exchange products are not sufficiently liquid.
What matters is that forward liquidity becomes deep enough for electricity companies to manage long-term exposure without embedding excessive risk premiums into their commercial decisions.
Southeast Europe does not lack sophisticated spot markets.
What it still lacks in many areas is depth along the forward curve.
Until that depth develops, the cost of managing long-term electricity risk will continue to depend not only on market prices, but also on relationships, collateral, credit capacity and balance-sheet strength.
Elevated by virtu.energy