Montenegro’s electricity transmission operator, CGES, is set to experience a notable decrease in regulated revenue starting in 2027. This shift follows the company earning approximately €100 million more than expected from its cross-border transmission activities, particularly from the submarine electricity cable linking Montenegro and Italy.
According to regulatory guidelines, the surplus revenue accrued between 2022 and 2025 must be counterbalanced by lowering transmission charges in the upcoming regulatory period from 2027 to 2029. This adjustment aims to reduce the CGES component of electricity bills for households, businesses, and other network users, with some benefits potentially directed to local electricity producers.
The adjustment mechanism does not involve direct cash refunds to consumers. Instead, the Regulatory Agency for Energy and Regulated Utilities will deduct the excess earnings from the total amount CGES can recover through network tariffs. The correction, distributed over three years, is expected to average around €33 million annually. However, actual annual allocations may vary based on the regulator’s final decisions regarding consumer and generator distributions as well as CGES’s operating costs and investment needs.
In terms of excess revenue generation, CGES reported figures of approximately €34.5 million in 2022, €35.7 million in 2023, around €16 million in 2024, and €23.5 million in 2025. A portion of this surplus—about €9.5 million—was already factored into reduced tariffs for 2025.
The majority of the excess revenue arose from congestion charges and fees associated with cross-border transmission capacity, notably from the approximately 600 MW Montenegro–Italy submarine interconnector. This cable has positioned Montenegro as a crucial transit and trading hub for electricity between southeastern and western Europe.
As price disparities between Italy and the Balkans increase, traders are inclined to pay higher prices for limited interconnection capacity, leading to auction revenues that often surpass conservative forecasts used in regulated income calculations.
CGES’s increased revenues stemmed primarily from the commercial value of its network rather than an uptick in domestic electricity consumption. The interconnector and the Lastva–Pljevlja transmission corridor facilitate electricity flow between Italy, Montenegro, Serbia, and the broader Southeast European grid.
The regulatory framework stipulates that a transmission monopoly should not retain excessive profits generated from infrastructure funded by regulated tariffs paid by network users. Income derived from cross-border operations is intended to be reinvested into maintaining or expanding interconnection capabilities or reducing charges for consumers and generators.
<pPreviously, Montenegrin consumers contributed to CGES's investment initiatives through their electricity bills. The forthcoming correction effectively redistributes part of the infrastructure's unexpectedly strong financial performance back to lower future tariffs.
The implications of this adjustment on individual household bills remain uncertain. The projected €100 million reduction pertains to CGES’s overall permitted revenue across all transmission system users rather than a direct subsidy for households. This reduction will be allocated among various customer categories and tariff components.
The final retail electricity bill also encompasses costs associated with power supplied by EPCG, distribution charges collected by CEDIS, network losses, renewable energy components, taxes, and other regulated elements. Thus, while a lower CGES charge may provide some relief, it could be offset by changes in other areas of the electricity bill.
<pThe earlier €9.5 million correction applied in 2025 resulted in reduced CGES transmission fees; however, its impact on final consumer prices was below 2 percent due to transmission being just one element of the overall bill. The larger correction anticipated for 2027-2029 is expected to have a more noticeable effect but will not necessarily translate directly into household savings.
For CGES itself, this adjustment signifies a substantial shift in earnings rather than merely an accounting change. Management forecasts annual profits during the next three years will decline to between €1.4 million and €1.7 million compared to approximately €21 million in 2025.
At its lowest estimate, this would represent a profit decrease exceeding 90 percent. Such a decline could impact dividend distributions, internal financing capabilities, and the company’s ability to fund grid investments without incurring debt.
In anticipation of this revenue adjustment, CGES has opted to limit its dividend for 2025. Despite generating €21 million in earnings, shareholders approved only a €5 million distribution to maintain liquidity ahead of the new regulatory period.
The ownership structure of CGES is significant; the Government of Montenegro holds a majority stake of 55.38 percent, while Italy’s Terna owns 22.09 percent and Serbia’s Elektromreža Srbije holds 15 percent. Smaller institutional investors and private individuals own the remaining shares.
The approved €5 million dividend translates into approximately €2.77 million for Montenegro’s government, about €1.10 million for Terna, and roughly €750,000 for EMS before taxes are applied. A larger dividend payout would have enhanced immediate shareholder returns but would have diminished capital available for future transmission investments.
CGES expects to retain around €115 million in accumulated earnings after distributing dividends; at the end of 2025, it reported approximately €55.3 million in cash reserves.
It is important to note that retained earnings represent an accumulation over time while cash reflects liquidity at a specific point. Some retained profits may already be allocated toward substations, transmission lines, receivables, and other assets.
This financial pressure coincides with CGES’s largest investment cycle in recent years; its investment plan for 2026-2030 amounts to €194.1 million aimed at modernizing networks and enhancing system reliability while accommodating an increasing number of wind, solar, and battery-storage projects.
To complete this investment program successfully, CGES estimates it will require about €55.9 million in additional external financing over several years. Funding gaps are projected to start at €2.6 million in 2027 before rising sharply to €32.4 million in 2028 before tapering off again toward 2030.
This timeline indicates that funding pressures will peak during the mid-point of the tariff correction period while construction expenditures are expected to accelerate during 2028 when internally generated cash flow is anticipated to be weakest.
If CGES borrows €55.9 million against its planned investment program of €194.1 million, nearly 29 percent of its capital expenditure will need external financing—a proportion that could increase if project costs escalate or if cross-border income declines further.
Despite these challenges, CGES should remain financially viable due to its operation of strategic monopoly infrastructure backed by substantial retained earnings and stable institutional ownership comprising two major European transmission operators as shareholders. Its investment program may also attract financing from institutions like the European Bank for Reconstruction and Development or commercial banks.
However, lower regulated earnings may weaken debt-service coverage ratios while increasing reliance on consistent regulatory treatment moving forward. Lenders will scrutinize whether tariff methodologies allow CGES adequate recovery of operational costs alongside reasonable returns on new investments following adjustments for past excess earnings.
The regulator is also considering changes that could further limit CGES’s permitted income beyond corrections related to excess revenue accumulation; potential adjustments include modifications to quality factors or allowable returns on regulated assets.
A reduced allowed return would diminish earnings generated per euro invested across substations and control systems while stricter quality measures might expose CGES to penalties if service reliability falls short of regulatory standards.
This situation poses risks as it may impede necessary investments required for network strengthening due to financial constraints resulting from aggressive regulatory measures during significant capital programs.
The urgency is heightened given that Montenegro’s renewable energy development pipeline is expanding faster than current grid capabilities can accommodate; integrating new generation capacity involves extensive planning beyond merely issuing construction permits.
Wind projects necessitate infrastructure capable of managing high production levels across diverse regional weather patterns while solar developments exert pressure on midday network capacity leading potentially towards congestion issues during peak periods.
A delay in CGES’s investments would consequently shift costs onto renewable developers who might face prolonged connection timelines or increased curtailment assumptions alongside additional requirements for privately financed connection assets.
Lenders could experience negative impacts stemming from extended grid delays lasting between 12-18 months which might erode project equity returns due to heightened interest expenses during construction phases or postponed sales revenue generation despite underlying renewable resources remaining robust.
Regulatory distinctions between excess income warranting consumer redistribution versus capital necessary for sanctioned efficient network expansions must be clearly established; while the €100 million correction addresses historical over-recovery concerns—the upcoming investment program totaling €194.1 million addresses future system demands—treating both as part of a single cash pool risks undermining tariff stability long-term.
CGES’s historically elevated profits since operational commencement of its Italy interconnector illustrate underestimations within regulatory forecasts regarding cross-border revenues; net profit surged from around €3.6 million in 2019 up until reaching approximately €35.7 million by 2023 prior corrections taking effect commenced influencing profitability trends adversely thereafter
This raises additional policy considerations concerning whether significant congestion revenues should be more accurately projected alongside timely applications thereof; postponing corrections can lead towards temporary windfall profits succeeded abruptly by steep tariff reductions occurring several years later—creating volatility affecting consumers’ financial predictability along with shareholder interests impacting overall investment strategies
An alternative smoother mechanism could involve annual updates regarding cross-border revenue assumptions or establishing dedicated accounts specifically earmarked towards network development—this approach minimizes later tariff shock occurrences whilst preserving funds allocated towards projects enhancing cross-border capacities thereby facilitating renewable integrations effectively
Such treatment also bears ramifications on CGES’s market valuation given its public listing on Montenegro Stock Exchange where investors must delineate recurring regulated earnings distinctly apart from transitory congestion income streams; profits accrued throughout periods spanning from 2022-2025 were not entirely available for permanent distributions since substantial portions would subsequently revert via regulatory mechanisms applied thereafter
The restrained dividend payout approved reflects management’s recognition concerning encumbered economic nature surrounding excess revenues anticipated; elevated historical profit levels do not guarantee sustained increases within dividends where regulators possess rights allowing offsets against future tariff calculations accordingly
This regulatory adjustment may further influence government fiscal dynamics wherein Montenegro derives benefits through dividends alongside majority ownership stakes held within CGES whilst consumers stand poised receiving advantages stemming reduced network charges instituted accordingly—redistributing excess income via tariffs transitions value away from state dividend streams towards households businesses along with electricity producers directly involved
This redistribution approach potentially supports disposable income enhancement alongside improved industrial competitiveness though simultaneously constraining resources accessible towards state-controlled infrastructure entities; ultimately governments might recuperate portions via diminished borrowing necessities elsewhere within economies coupled stronger tax receipts arising among businesses benefiting reduced electric expenses incurred subsequently
Cross-border revenues themselves could also face unpredictability challenges due EU Carbon Border Adjustment Mechanism imposing carbon-related costs associated with imported electrical energy originating from carbon-intensive systems—though not directly penalizing CGES it nevertheless alters trading flows impacting capacity values directed towards Italy significantly
Electricity exports reliant upon coal-intensive generation sources risk becoming less competitive once EU importers factor embedded emissions into pricing structures thus potentially diminishing cable utilization during certain periods leading narrowing congestion revenues concurrently elevating importance low-carbon verified electricity sourced hydroelectricity wind solar alternatives produced instead
The precise outcome remains contingent upon regional pricing dynamics carbon valuations methodologies utilized determining emissions alongside Montenegro’s progress aligning market coupling adhering EU electrical regulations established frameworks respectively—declines witnessed within coal-linked export volumes offsetting potential growth observed renewable output transitioning enhanced interconnections neighboring systems present opportunities arise accordingly
Overall strategic value associated with cable remains intact albeit revenue profiles likely evolving overtime whereby capacity-derived incomes generated volatile price spreads ought not regarded guaranteed substitutes stable regulated revenues accrued previously observed trends
