Industrial electricity buyers across Southeast Europe faced a more complex procurement environment in Week 23, with wide country price spreads and volatile hourly price shapes. The period also featured elevated gas risk and shifting renewable output. For large offtakers, the market conditions meant annual budget assumptions could not be built on a single average power price.
Week 23 spreads across SEE markets
The weekly price spread was substantial across the region. Italy averaged €128.09/MWh, while Greece recorded €89.25/MWh. Serbia averaged €99.63/MWh, Croatia €99.29/MWh, Bulgaria €100.83/MWh, Romania €102.23/MWh and Hungary €103.15/MWh.
Türkiye remained structurally cheap at €22.53/MWh, but it was largely outside the normal SEE price range.
Demand, renewables and gas move procurement costs
For industrial buyers, the risk extended beyond high prices to unpredictable price formation. Demand rose by 8.2%, while variable renewables fell by 8.9%. Thermal generation increased by 24.5%, and gas prices stayed close to €50/MWh.
This combination could change procurement costs quickly, particularly during evening peaks and low-renewable periods.
Contract structures under volatility
Fixed-price contracts may help protect budgets, but they can become costly when suppliers incorporate volatility into pricing. Spot exposure preserves flexibility, but it leaves companies exposed to price spikes. Indexed contracts can reduce supplier premiums while transferring more market risk to the buyer.
The choice of structure increasingly depends on load shape, production flexibility, carbon exposure and risk appetite.
Corporate PPAs and compliance requirements
Corporate PPAs were described as becoming more important, though not as straightforward solutions for all demand profiles. A solar PPA may lower average cost and support green claims, but it may not align with industrial consumption during evening or night shifts.
A wind PPA may provide better output outside solar hours, but it carries forecast risk. Hybrid PPAs with storage may offer stronger value but require more complex structuring.
For exporters exposed to CBAM, procurement strategy also includes compliance considerations. Green electricity documentation, guarantees of origin, hourly matching and audit-ready metering can affect the credibility of low-carbon claims.
Layered hedging approaches for large offtakers
Hedging strategies were also expected to become more granular under the conditions seen in Week 23. Industrial buyers were advised to consider layered procurement combining fixed baseload volumes with indexed market exposure and PPA-backed renewable blocks.
The approach also included intraday optimisation, demand response and financial hedges where available. Large users with flexible production schedules may be able to monetise volatility by shifting consumption away from peak hours.
Week 23 indicated that SEE power markets are becoming more sophisticated and demanding for procurement planning. The earlier model of buying annual volume, accepting supplier pricing and managing invoices was no longer sufficient for industrial buyers.
The companies best positioned were those that understand their hourly load, carbon exposure, flexibility potential and contract risks. In SEE’s new power market, electricity procurement was described as becoming a financial discipline.
Elevated by energy.clarion.engineer
