In January, Guarantees of Origin in South-East Europe increasingly shaped how utilities and industrial buyers monetise low-carbon attributes, even as physical power prices moved on flexibility and constraints. The regional market continued to link GO value to the ability to source and trade certified attributes through registries and contracts. January also showed that GO pricing did not track spot power movements during peak-hour volatility.
Regional GO supply and demand imbalances
South-East Europe remained a net exporter of low-carbon attributes, but with sharp internal asymmetries. Countries with large hydro and nuclear fleets, primarily Bulgaria and Romania, generated a surplus of potential GOs relative to domestic voluntary demand. By contrast, countries with limited certification depth, fragmented registries, or high industrial offtake—such as Serbia and Montenegro—remained structurally short certified green attributes even when physical power was not scarce.
The January dynamics reinforced that split between attribute availability and physical electricity conditions. Physical prices rose during evening ramps while GO prices stayed comparatively stable. This indicated that carbon and origin scarcity did not coincide with energy scarcity in the same time window.
Decoupling between spot power peaks and GO values
January’s peak-hour pricing reached €200–300/MWh, while GO prices did not show a corresponding shock. The divergence pointed to spot price formation driven by flexibility and congestion rather than the availability of certified renewable or nuclear output. As a result, GO markets behaved more like a slow-moving structural instrument than a volatile spot commodity.
The pattern also reflected how revenue streams can move independently in practice. Hydropower operators monetised energy volatility on exchanges such as SEEPEX, while simultaneously monetising attribute value through GOs via separate issuance channels. Even when hydro withheld energy and spot prices spiked, GO issuance continued at a steady pace.
Hydro-led issuance across the Western Balkans
Hydropower dominated the January GO supply profile in the Western Balkans. Serbia, Montenegro, and Bosnia and Herzegovina generated most of their certifiable renewable output from hydro assets. Their hydro plants continued issuing GOs regardless of whether water was dispatched into peak hours or conserved.
The two channels—physical electricity trading and GO issuance—were described as only loosely correlated in January. Steady GO issuance persisted even during days when hydro output decisions coincided with higher physical prices. This supported the view that GO supply stability was not directly tied to short-term dispatch patterns.
Wind, solar, and timing effects for corporate buyers
Wind and solar contributed incremental volumes to the January GO market, but seasonal conditions limited solar certificates and made wind issuance episodic. The impact was framed as more about buyer perception than absolute volume levels. Corporate buyers increasingly differentiated between “hydro-heavy” certificates and those specific to wind or solar.
For multinational offtakers pursuing hourly or granular matching, January’s wind volatility translated into temporal mismatches rather than outright shortages of GOs. The issue was presented as more relevant for advanced matching approaches than for standard annual procurement structures.
Nuclear certificates as a firm low-carbon option
Nuclear GOs were identified as the most strategically significant element of the January market. Bulgaria and Romania’s nuclear fleets issued large volumes of low-carbon GOs that were increasingly attractive to industrial buyers seeking 24/7 clean power matching or firm baseload decarbonisation claims.
Although nuclear does not qualify as renewable, nuclear GOs were described as a preferred instrument for heavy industry where firmness is valued over intermittency. In January, nuclear certificates were also said to cap the upside of renewable GO prices by offering a scalable, stable alternative for buyers focused on emissions intensity rather than technology purity.
Cross-border flows: physical imports versus attribute sourcing
The dynamic mattered for exporters because Bulgarian and Romanian utilities exporting physical power into neighbouring markets also exported options to source GOs from their domestic registries. Even when electricity flowed physically into Serbia or Croatia, GO flows followed contractual and registry pathways rather than electrons.
This reinforced that physical imports do not automatically provide green attributes for compliance or reporting needs. January highlighted the cost gap for industrial buyers facing ESG requirements, CBAM-related considerations, or customer-driven decarbonisation obligations when attribute access is not aligned with electricity supply.
Serbia and Montenegro: certification constraints despite physical clearing
Serbia cleared January without systemic energy shortage from a physical perspective, but its domestic GO issuance remained dominated by hydro. The level of issuance was described as insufficient to cover rising voluntary demand from export-oriented industry. Serbian buyers therefore increasingly relied on imported GOs, often from Bulgaria or Romania.
This reliance created a price premium that was described as unrelated to local power prices. January’s volatility on SEEPEX did not materially change that premium, indicating that GO pricing reflected structural certification imbalance rather than short-term market stress.
Montenegro faced an even sharper version of the same problem despite being overwhelmingly hydro-based in physical terms. Limited market size and registry liquidity constrained GO availability and tradability. January’s extreme price dispersion on MEPX had almost no impact on GO values, but it underscored a gap between being green in physics and green-poor in certification when registry depth and offtake channels are weak.
Procurement timing separates energy risk from GO risk
For corporate and industrial buyers, January signalled that spot power volatility does not translate into GO opportunity. Buyers who delayed GO procurement expecting cheaper green attributes during €60–70/MWh baseload days were disappointed. Instead, GO prices were described as anchored to longer-term scarcity, particularly for hydro and nuclear certificates with firm delivery profiles.
The procurement approach described for SEE was decoupled management of energy price risk versus GO risk using different timing and counterparties. This reflected how GO markets were characterised as structurally driven rather than responsive to short-term electricity price swings.
GO markets as parallel infrastructure under reporting scrutiny
The policy framing around January emphasised that GOs were becoming parallel market infrastructure rather than an accessory to power trading. As hourly matching requirements, CBAM-adjacent reporting, and Scope 2-related scrutiny intensified, firm traceable regionally recognised certificates were expected to carry greater value regardless of spot power behaviour.
The same framework indicated that systems with nuclear and large hydro would continue monetising this advantage through certificate availability. Systems without such capacity would face a structural premium even in months where physical power was abundant.