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March 11, 2026
by AEA in News

Balkan power play: why the Western Balkans must ditch Russian fuels and fast-track EU market integration

A short, sharp truth: the Western Balkans sits at the crossroads of Europe’s energy security and its green ambitions, but patchy rules, lingering dependence on Russian fuels and slow market reforms mean the region risks being a weak link rather than a bridge. A new working paper from Bruegel lays out what’s at stake and what needs to happen next.

From leverage to liability: Russian ties still matter

Gas pipeline system in the Western Balkans

Gas pipeline system in the Western Balkans

The report finds that several Western Balkan states remain exposed to Russian energy influence notably Serbia and Bosnia and Herzegovina on oil and gas  which leaves them vulnerable to geopolitical pressure and imported price shocks. Negotiations and occasional extensions of Russian contracts in 2024–25 underline that diversification on paper does not always mean real independence. That dependence isn’t just political theatre: it alters investment choices, weakens bargaining power and complicates alignment with EU rules.

Why this matters beyond the region: the Western Balkans is a major transit corridor for electricity between the EU and Southeast Europe. The paper highlights that as much as “up to 70%” of electricity flows tied to the region actually pass between EU countries a signal that grid interdependence already exists and that isolation is neither realistic nor desirable. Faster regulatory alignment and market coupling would therefore strengthen European system resilience as well as the region’s.

 Western Balkan electricity imports and exports (TWh), 2020-2024

Western Balkan electricity imports and exports (TWh), 2020-2024

Market coupling: planned, stalled, urgent

European market coupling the technical and regulatory merging of power markets is the single policy lever that could deliver immediate gains: better price signals, more efficient dispatch across borders, and a buffer against supply shocks. The Bruegel authors point out that integration planned for the mid-2020s (originally aiming around 2027) is running behind because national rulebooks and market institutions in the Western Balkans are not yet aligned with EU standards. That delay has real costs: lost efficiency, higher system operation expenses, and a slower rollout of renewables.

 Day-ahead auction average prices (€/MWh), EU, Norway and Western Balkans, 2024

Day-ahead auction average prices (€/MWh), EU, Norway and Western Balkans, 2024

Uneven green progress  leaders and laggards

Not all Western Balkan countries are on the same page when it comes to the green transition. The paper singles out Albania as a regional leader largely because of its hydropower legacy and relatively favorable renewables policies and Montenegro as advanced across several indicators. Meanwhile, solar and wind potential across much of the region remains largely untapped and constrained by underdeveloped grids, weak permitting frameworks and scarcity of private investment. Simply put: the natural resource advantage (sun, wind, hydro) is mostly unexploited.

This mix of actors creates both a challenge and an opportunity. Countries with stronger renewables backbones could become exporters and stabilizers for neighbors but only if cross-border trade is enabled and market rules are harmonised.

Domestic electricity prices (€/MWh), EU, Norway and Western Balkans, 2024 and 2014

Domestic electricity prices (€/MWh), EU, Norway and Western Balkans, 2024 and 2014

Coal’s long shadow political economy vs. emissions

Phasing out coal is politically charged across the Western Balkans. Coal still provides baseload power and jobs in several countries, and switching it off without credible compensation or alternative industrial plans risks social backlash. The paper recommends phased, socially sensitive coal retirement plans tied to clear investment pathways for renewables and grid upgrades. In short: decarbonisation must be realistic and sequenced fast where possible, compensated where needed.

Practical steps the paper recommends (and why policymakers should care)

  1. Accelerate regulatory alignment with the EU. Aligning rules is the low-hanging fruit that unlocks market coupling and immediate efficiency gains. Market reforms are technical, but the payoff — lower costs and stronger security — is political and strategic.

  2. Reduce real dependence on Russian fuels. Diversification must go beyond headline contracts. It requires investments in LNG connections, alternative import routes, and faster roll-out of domestic renewables to reduce import vulnerability.

  3. Design a just coal phase-out. Pair plant retirement timetables with retraining, economic revitalisation, and clean-energy investment envelopes so communities are not left behind.

  4. Mobilise private capital for renewables and grids. Improve permitting, de-risk projects with public guarantees, and create transparent auction frameworks to attract the investors the region needs.

Political and financial headwinds plus a window of opportunity

The paper is candid about constraints: weak institutions, fragmented markets, and geopolitical tensions complicate reform. But it also notes a narrow window where EU enlargement dynamics, conditional funding instruments (the EU Growth Plan for the Western Balkans) and post-Ukraine energy policy realignments create momentum and conditional financing that can be leveraged if countries move quickly and coherently.

Electricity generation mix in the Western Balkans, 2014 and 2024

Electricity generation mix in the Western Balkans, 2014 and 2024

What success looks like

A successful pathway would see the Western Balkans converge with EU market rules, complete market coupling, significantly reduce Russian fuel exposure, and scale renewables deployment while phasing out coal with social protections. Practically, that means lower wholesale price volatility, better utilisation of regional transmission assets, and an energy sector that attracts investment rather than fears it.

Conclusion integration first, transition faster

The Bruegel working paper’s central message is straightforward: the Western Balkans has the geographic and resource advantages to be a strategic partner for Europe’s energy security and green goals but only if the political will to align rules, diversify supplies and invest in renewables is found. Fast-tracking market coupling and decarbonisation in parallel, not in sequence will deliver both security and economic opportunity. For policymakers in Tirana, Sarajevo, Pristina, Podgorica, Skopje and Belgrade, the choice is clear: remain a transit corridor vulnerable to outside influence, or become a resilient, integrated bridge to Europe’s clean-energy future.

March 11, 2026
by AEA in News

ERE Solidifies 2026 Power Prices for Water Utilities: A Deep Dive into the New Tariffs

The Albanian Energy Regulatory Entity (ERE) has formally approved the electricity pricing structure for the nation’s Water Supply and Sewerage companies for 2026. Decision No. 57 marks a critical step in maintaining the financial stability of public utilities while ensuring the continuity of essential water services across the country.

The “Special Status” Shield

Under current regulations, water utilities are treated as high-priority consumers. Even as these entities move toward a liberalized market, they remain under the protection of the Last Resort Supplier (FSHU) to prevent any service interruptions that could arise from market volatility or payment disputes

Cost Breakdown: Stability in the Supply Chain

The 2026 price structure reflects a stabilized procurement strategy from the state power producer, KESH. The bulk of the cost is driven by the energy purchase price, which has been set at 5.70 ALL/kWh.

However, the final price paid by utilities varies significantly based on their connection to the national grid. For those connected to the 35 kV transmission-adjacent levels, the lower distribution fee results in a final tariff of 9.33 ALL/kWh. In contrast, utilities operating on the 20/10/6 kV distribution levels will face a higher tariff of 11.77 ALL/kWh, primarily due to the increased distribution service fee of 3.99 ALL/kWh.

Component (ALL/kWh) 35 kV Level 20/10/6 kV Level
Purchase Price (KESH) 5.70 5.70
Transmission Fee 0.85 0.85
Distribution Fee 1.55 3.99
Admin & Risk 1.23 1.23
Total Sale Price 9.33 11.77

Regulatory Oversight

The ERE Board, led by Chairman Petrit Ahmeti, emphasized that these rates are subject to revision should any of the underlying cost components such as transmission or distribution fees undergo changes during the fiscal year. This decision comes into effect immediately, providing a clear fiscal roadmap for the water sector’s energy expenditures for the upcoming year.

For the broader Albanian energy market, this decision reinforces the government’s strategy of balancing market liberalization with the protection of vital public infrastructure.

March 8, 2026
by AEA in News

Albania Moves Toward Oil Security Reserves Amid Global Energy Volatility

The Albanian government has been working for several years to pass legislation governing the creation, maintenance, and management of minimum security reserves for crude oil and its refined products.

According to international standards, these emergency stocks are calculated at either 90 days of net imports or 61 days of average daily consumption, whichever is higher. These reserves are designed to be deployed during extraordinary circumstances, such as physical supply shortages or geopolitical crises.

The initial draft, proposed in February 2019, introduced a co-management formula between the state and the private sector—a departure from the current model where reserves are held entirely by private companies and refineries. Under the proposed framework, a public entity would manage 60 days of average consumption, while the remaining 30 days would remain the responsibility of private operators.

The legislative proposal envisioned the creation of a dedicated public body named the State Agency for Oil Security Reserves, operating under the jurisdiction of the Ministry of Infrastructure and Energy (MIE).

The Cost of Energy Security

The draft law stipulated that the agency would be self-financed through a dedicated fee levied on every liter of fuel purchased by refineries and wholesale companies. This mechanism would essentially introduce a new fiscal obligation, which is expected to translate into higher pump prices for final consumers.

While the project has undergone various internal government discussions since 2019, it was only in October 2025 that it was formally released for public consultation. The current draft maintains the previous structure: a non-profit public entity, now dubbed the Security Reserve Authority, under the MIE.

Key administrative details include:

  • Article 10: Fees for obligated parties will be collected by the Customs Authority during the collection of excise duties.

  • Article 11: Payers are required to submit payment data within 30 days of the end of each calendar month.

Despite the fact that the project has yet to be finalized, market operators anticipate additional costs totaling hundreds of millions of euros. These costs cover the procurement, storage, and logistics of the security stocks—burdens that are expected to increase operational costs for companies and, ultimately, prices for the consumer.

Global Context: Iran Conflict Risks New Energy Crisis

As Albania formalizes its domestic security measures, the escalation of conflict in the Middle East—specifically involving Iran—is sending shockwaves through global energy and financial markets. International economic analysts warn that a prolonged conflict could trigger severe supply disruptions, oil price spikes, and renewed inflationary pressures worldwide.

A primary concern is the potential for conflict to damage regional energy infrastructure or obstruct oil transit through the Strait of Hormuz, one of the world’s most critical energy corridors.

Market Analysis

In a recent analysis titled “War with Iran is a Nightmare for Oil and Gas Markets,” Bloomberg noted that a broad regional conflict has long been considered the “worst-case scenario” for the energy sector. The report emphasizes that the Persian Gulf remains a cornerstone of global energy supply, and any disruption there triggers an immediate market reaction.

Similarly, The Economist has warned of a significant shock to global markets. In an article titled “War in Iran Could Trigger the Biggest Oil-Market Shock in Years,” the publication highlights the extreme sensitivity of energy markets to regional tensions. Any disruption to tanker traffic could drastically reduce global supply and drive energy prices to record highs.

Financial and Economic Ripple Effects

The geopolitical tension has already impacted financial markets:

  • Safe-Haven Assets: Investors are pivoting toward gold and bonds.

  • Volatility: Stock markets are experiencing fluctuations as geopolitical risk premiums rise.

  • Inflation: Analysts warn that high oil prices ripple through the economy by increasing costs for transport, manufacturing, and food production.

Experts conclude that countries dependent on energy imports are the most vulnerable. European and Asian economies, in particular, face the prospect of surging production costs and new inflationary cycles if energy prices remain elevated.

March 5, 2026
by AEA in News

PPC and Metlen Forge 1.5 GW Regional Battery Storage Alliance

In a major move to solidify their dominance in the Southeast European energy transition, Greece-based PPC Group and Metlen Energy and Metals (formerly Mytilineos) have entered into a strategic joint venture. The agreement aims to develop, construct, and operate a massive portfolio of Battery Energy Storage Systems (BESS) totaling 1.5 GW in power capacity and 3 GWh in energy storage across Romania, Bulgaria, and Italy.

Fast-Tracking Storage Infrastructure

The partnership is designed for rapid deployment, with both companies targeting the completion of 1 GW of capacity within just 12 months. This aggressive timeline underscores the urgency of integrating flexible assets into regional grids to manage the influx of intermittent renewables.

The technical specifications of the portfolio focus on high-efficiency, utility-scale technology:

  • Total Capacity: 1.5 GW / 3 GWh (representing two-hour duration systems).

  • Technology: Liquid-cooled Lithium-Iron-Phosphate (LFP) batteries.

  • Asset Management: The venture will be equally owned (50/50), leveraging PPC’s regional market presence and Metlen’s specialized EPC (Engineering, Procurement, and Construction) expertise.

Synergy Beyond Solar

This deal follows a landmark 2024 agreement between the two entities, which saw them collaborate on a 2 GW solar pipeline across Italy, Romania, Bulgaria, and Croatia. While that previous arrangement focused on an “at-completion” acquisition model by PPC, this new BESS venture creates a deeper operational partnership.

The storage facilities are intended to perform two critical functions:

  1. Renewable Support: Balancing the output of adjacent photovoltaic and wind farms.

  2. Grid Stability: Providing essential ancillary services to national electricity systems to prevent frequency fluctuations.

Strategic Implications for Southeast Europe

For the government-controlled PPC Group, this alliance secures a significant portion of its three-year energy storage targets. For Metlen, the deal represents a pivotal milestone in its broader European strategy, positioning the firm as a leading player in the continent’s storage infrastructure sector.

“This agreement creates value for both parties and further expands our group’s already significant presence in Southeast Europe,” noted Konstantinos Mavros, PPC Group’s Deputy CEO for Renewables.

As the Balkan and Mediterranean markets continue to decarbonize, the rapid commissioning of these 3 GWh of storage capacity is expected to be a cornerstone for regional energy security and market liquidity.

March 5, 2026
by AEA in News

MEPSO Advances Strategic 400 kV Interconnection Project for Energy Community Priority Status

North Macedonia’s electricity transmission system operator, MEPSO, has officially nominated the “400 kV East–West Interconnection Corridor – Western Section” for inclusion in the prestigious list of Projects of Energy Community Interest (PECI). This strategic move aims to solidify the project’s status as a regional priority, facilitating cross-border energy cooperation and bolstering the stability of the Balkan power grid.

A Vital Link in the Regional Energy Spine

The nominated western section focuses on establishing a high-capacity link between Tetovo in North Macedonia and Prizren in Kosovo. This infrastructure is a critical component of a broader corridor designed to integrate the networks of Turkey, Bulgaria, Greece, North Macedonia, Kosovo*, Albania, and Montenegro.

Key specifications of the project include:

  • Total Length: Approximately 255 kilometers.

  • Primary Objective: Connecting the capital, Skopje, and the city of Ohrid via Tetovo, while providing a robust cross-border link to Kosovo*.

  • Capacity Upgrade: Replacing the current single 220 kV link between North Macedonia and Kosovo with a modern 400 kV interconnection.

Infrastructure and Operational Enhancements

The project involves a series of interrelated investments beyond simple transmission lines. MEPSO has outlined plans for significant substation developments to manage increased load and ensure operational flexibility:

  • Tetovo Substation: A new 400/110 kV facility will serve as a central hub for multiple high-voltage lines, significantly strengthening the transmission capacity in Western North Macedonia.

  • Oslomej Substation: Another 400/110 kV facility is planned for Oslomej. This location is particularly strategic as it transitions from a traditional coal-fired power site to a hub for new renewable energy projects.

Strategic Significance and Regional Synergy

MEPSO emphasizes that this investment is highly complementary to existing regional efforts, specifically the approved PECI project to upgrade the line between Prizren (Kosovo) and Fierza (Albania) to 400 kV. This synergy will create a seamless high-voltage path connecting North Macedonia, Kosovo*, and Albania.

This regional integration was further solidified last year (2025) through a Memorandum of Understanding signed between MEPSO and KOSTT (Kosovo’s Transmission, System and Market Operator).

“Achieving PECI status is a recognition of the project’s pronounced regional relevance. It directly contributes to the Energy Community’s objectives of secure, sustainable electricity supply and the efficient integration of renewable energy sources.” — MEPSO Statement

Timeline and Next Steps

The selection process for the second PECI list follows a rigorous biannual cycle. With the call for nominations having closed on January 19, the final list is expected to receive official approval by December 31, 2026.

Projects granted PECI status benefit from streamlined permitting processes and enhanced access to regulatory and financial support, accelerating the region’s progress toward decarbonization and a unified energy market.

March 5, 2026
by AEA in News

Slovenian Energy Market 2025: Household and Industrial Electricity Prices Record Annual Declines

The Slovenian Ministry of the Environment, Climate and Energy has released its final statistical report for 2025, revealing a general cooling of retail electricity prices across the country. According to the data, which covers the fourth quarter and the full calendar year, households and non-household consumers both benefited from lower year-on-year costs, driven largely by significant adjustments in grid fees and government exemptions.

Household Sector: Grid Fee Relief Offsets Rising Energy Costs

For the average Slovenian household, the retail electricity price in 2025 settled at €95 per MWh, representing a 4% decrease compared to 2024. This downward trend continued into the final months of the year, with Q4 prices dipping an additional 2%.

While the overall retail price fell, the underlying “electricity component”—the cost of the energy itself—actually rose by 7% to an average of €111 per MWh (excluding VAT). The net reduction for consumers was primarily achieved through aggressive cuts to regulated charges:

  • Grid Fees: Averaged €42.1 per MWh (excluding VAT), a substantial 30% reduction from the previous year.

  • Policy Support: Households enjoyed a total exemption from renewable energy (RES) and high-efficiency cogeneration (CHP) fees during the first half of 2025, with partial exemptions remaining in place for the second half. These surcharges averaged just €5.2 per MWh.

  • Excise Duty: Stood at €1.53 per MWh.

By the end of 2025, the cost structure for a typical household invoice consisted of the energy component (56.9%), grid fees (21.6%), VAT (18%), energy taxes (2.7%), and excise duties (0.8%).

Non-Household Sector: Significant Annual Savings Despite Q4 Spike

The broader consumer category, dominated by the business and industrial sectors, saw an even sharper annual decline. The average price for non-household consumers in 2025 was €181 per MWh, a 13% drop over 2024.

However, the sector faced a volatile end to the year; while annual figures were down, prices in the fourth quarter alone actually climbed by 6%.

The ministry highlighted a across-the-board reduction in core cost drivers for businesses:

  • Energy Component: Decreased by 13% to €116.7 per MWh.

  • Regulated Grid Fees: Also fell by 13%, averaging €20.7 per MWh.

  • Fiscal Charges: Energy taxes dropped 14% to €9.5 per MWh, though excise duties saw a marginal increase of 2% to €1.3 per MWh.

For these consumers, the energy component represents the vast majority of the total cost at 78.7%, followed by grid fees at 14%, energy taxes at 6.4%, and excise duties at 0.9% (all figures excluding VAT).

March 5, 2026
by AEA in News

The Double Squeeze: Europe’s Energy Sovereignty in the Shadow of Two Fronts

The European energy landscape has reached a critical inflection point as of early March 2026, characterized by the simultaneous escalation of two major geopolitical crises that threaten the continent’s industrial foundation and long-term energy security. The recent outbreak of direct hostilities between the United States, Israel, and Iran has fundamentally altered the global energy calculus, compounding the existing stresses of the prolonged Russia-Ukraine conflict. As an expert observer of these markets, it is evident that Europe is no longer just managing a transition away from Russian fossil fuels; it is now navigating a systemic “supply-chain fragmentation” that challenges its strategic autonomy on every front.

The most immediate and destabilizing factor is the conflict in the Middle East, which has seen the effective closure of the Strait of Hormuz following retaliatory strikes and the reported death of the Iranian Supreme Leader. This maritime blockade has paralyzed nearly 20% of the world’s liquefied natural gas (LNG) and oil supplies, with Qatar—a cornerstone of Europe’s post-2022 diversification strategy—forced to halt its production entirely. The market reaction has been swift and severe, with European gas futures surging by approximately 50% in the final week of February and early March. While the European Commission and industry leaders like Statkraft’s CEO Birgitte Vartdal have noted that Europe has fortunately passed the peak of winter heating demand, the physical security of supply is less of a concern today than the economic reality of the coming months. The real danger lies in the summer injection season; without Qatari and Persian Gulf volumes, analysts warn that European storage levels may only reach 70-75% by next winter, far short of the 90% mandate. This structural deficit ensures that any future cold spell will translate directly into extreme price volatility and potential industrial demand destruction.

Russian President Vladimir Putin has moved quickly to weaponize this Middle Eastern instability, framing the global price surge as a consequence of Western aggression and “erroneous” European energy policies. In a calculated maneuver, Putin has signaled that Russia is considering an early halt to its remaining gas exports to Europe, citing “commercial reasons” and the EU’s own plans to phase out Russian pipeline gas by 2027. By suggesting that it is more profitable to redirect these volumes to emerging Asian markets now, Moscow is attempting to pre-emptively sever the final energy ties with the West on its own terms. Furthermore, the Kremlin has heightened the sense of insecurity by alleging Ukrainian-backed plots to sabotage the TurkStream and Blue Stream pipelines, which remain vital for energy flows into Southern Europe and Türkiye. This rhetoric serves a dual purpose: it pressures European nations to reconsider their support for Ukraine while simultaneously driving up the risk premiums that domestic industries must pay for energy.

The European response has shifted toward a more aggressive form of “strategic autonomy,” as seen in the launch of the European Industrial Maritime Strategy and the EU Ports Strategy on March 4, 2026. These initiatives represent a belated recognition that energy security is inseparable from maritime and industrial sovereignty. By prioritizing the “Made in Europe” provision and focusing on high-tech shipbuilding and offshore wind support, the EU is attempting to build an infrastructure that can withstand the decoupling of global trade routes. However, as trade unions and industrial groups have pointed out, these long-term structural changes do little to mitigate the immediate “price shock.” The reliance on the spot market to replace lost Middle Eastern and Russian volumes has left European utilities competing with Asian buyers at record-high premiums, a situation that Statkraft warns will erode the competitiveness of energy-intensive sectors like chemicals and steel.

Ultimately, the confluence of the Iran crisis and the Russia-Ukraine war has exposed the fragility of Europe’s “bridge” strategy, which relied on replacing Russian pipeline gas with global LNG. The current paralysis of the Strait of Hormuz demonstrates that LNG is not a risk-free alternative but is instead subject to the same geopolitical vulnerabilities as pipelines, albeit across different geographic chokepoints. For Europe, the path forward is increasingly narrow: it must accelerate its demand-side response and the deployment of renewables while simultaneously bracing for a prolonged period of high inflation and supply-chain uncertainty. The coming year will likely be defined by a shift from “just-in-time” energy procurement to a “security-first” model, where the cost of resilience is high, but the cost of continued dependence is now proving to be unsustainable.

March 5, 2026
by AEA in News

Kosovo Government Caps Fuel Profit Margins After Sudden Price Surge

The Government of Kosovo has introduced new measures to limit the rise in fuel prices after suspicions that market operators were taking advantage of recent developments to increase profits. Through a new decision, authorities have established maximum profit margins per liter for both wholesale and retail fuel sales.

Within just one day, fuel prices in Kosovo increased by more than 20 cents per liter. The rapid price movement followed escalating tensions in the Middle East and disruptions in the global energy supply chain.

However, such a sharp increase over a short period has been widely described as excessive and potentially exploitative. Data from Kosovo Customs indicate that the actual import price of fuel rose only marginally.

According to Customs figures, the import price increased by just 1.5 cents per liter. On Monday, a liter of diesel was imported at 54 cents, while on Tuesday the price rose slightly to 55.6 cents.

Meanwhile, retail prices at fuel stations showed a much larger increase. On Monday, diesel prices ranged between €1.18 and €1.25 per liter. By Wednesday, the same fuel was being sold for between €1.35 and €1.40 per liter. Gasoline prices followed a similar trend, rising from between €1.17 and €1.24 on Monday to as high as €1.35 per liter by Wednesday.

Due to the significant discrepancy between the modest rise in import costs and the sharp increase at fuel stations, the Minister of Trade, Mimoza Kusari-Lila, signed a decision on Wednesday establishing temporary price caps.

Under the decision, the maximum allowed profit margin for wholesale fuel sales is set at 2 euro cents per liter, while the retail margin is capped at 12 euro cents per liter.

According to the ministry, the measure follows continuous monitoring of the oil market, analysis of daily data from Kosovo Customs, and reports from the Central Market Inspectorate, which concluded that increases in import prices were immediately and disproportionately reflected in retail prices. Inspectors will be deployed in the field to oversee the implementation of the decision.

The regulation will enter into force one day after its publication in the Official Gazette.

Maximum Allowed Commercial Margins

  • Wholesale sales: up to 2 euro cents per liter

  • Retail sales: up to 12 euro cents per liter

The calculation of these maximum margins is based on Article 4, paragraphs 1.1 and 1.2 of Administrative Instruction No. 03/2022 on the Regulation of Petroleum Product Prices and Renewable Fuels, as well as other protective measures. Authorities stated that the decision was made after assessing current market conditions and within the legal competencies of the ministry.

Earlier on Tuesday, Fadil Berjani, head of the oil traders’ association, warned that geopolitical tensions in the Middle East are directly affecting global oil markets.

According to Berjani, rising tensions and the risk of disruptions in production or transportation are increasing uncertainty in global supply, pushing oil prices higher. Particular attention is being paid to the Strait of Hormuz, one of the most critical oil transit routes in the world. Any disruption in that corridor typically has an immediate impact on markets and translates into higher fuel costs for consumers.

Global oil prices have risen significantly following attacks by Iran on several countries in the Middle East, reportedly in response to bombings carried out by the United States and Israel.

March 5, 2026
by AEA in News

KESCO announces the second phase: businesses enter the open electricity market.

KESCO in Kosovo has announced that, beginning 1 April 2026, the second phase of commercial consumers’ transition to the open electricity market will commence.

From that date, businesses currently supplied under the regulated market will move to the liberalized market and will be able to select their own licensed electricity supplier. The measure is intended to encourage greater competition and reflect market-based pricing.

Under the country’s Electricity Law and at the request of the regulator, businesses that employ more than 50 staff or report an annual turnover exceeding €10 million will no longer be eligible for regulated tariffs under the universal service framework. As a result, KESCO — in its role as Universal Service Supplier — will be unable to continue providing those businesses with regulated-rate supply after 1 April 2026.

According to the company, official records from the Tax Administration indicate that a number of businesses no longer meet the universal-service eligibility criteria. Affected businesses must select a licensed supplier in the open market by 1 April 2026 and initiate the supplier-switching procedure at least 21 working days before the new contract takes effect.

If a business fails to secure a contract within that timeframe, it will be supplied on a temporary basis by the Supplier of Last Resort for up to 60 days. Should no contract be concluded within that period, electricity supply may be disconnected in accordance with applicable legislation.

The company also clarified that self-consumers (prosumers) will no longer remain under the regulated-tariff scheme from the same date; the terms for energy produced and injected into the grid will be set out in the new supplier contract.

Finally, businesses are asked to confirm their employee numbers, annual turnover and active metering units with the company to ensure a smooth transition to the open market.

March 3, 2026
by AEA in News

How Oil and Gas Prices Are Rippling Through Europe and the Balkans

The widening military confrontation involving Iran has triggered immediate turbulence in global energy markets, underlining once again the structural fragility of interconnected supply chains. Within days of escalation, Brent crude rose above 80 USD per barrel as markets reacted to fears of supply disruption and potential interference with maritime traffic in the Strait of Hormuz, a chokepoint through which roughly one-fifth of global oil trade transits (Reuters, 2026a). Even in the absence of a complete closure, the perception of heightened risk has increased tanker insurance costs and freight rates, reducing effective supply and embedding a geopolitical premium into global oil pricing.

Approximately 20% of global oil consumption and 20% of the world’s liquefied natural gas (LNG) transit the Strait of Hormuz. According to recent analysis by The Soufan Center, Iran has shifted its strategy from regional military confrontation to a “global economic shock event.” By targeting critical energy infrastructure—including drone strikes on Qatar’s Ras Laffan facility and Saudi Arabia’s Ras Tanura—Tehran has effectively neutralized the world’s “spare capacity” safety net.

In the first 72 hours of the conflict, Brent crude futures surged by over 10%, while European natural gas prices (Dutch TTF) skyrocketed by a staggering 50%. Analysts from Wood Mackenzie warn that if the blockade of the Strait persists, oil prices could comfortably shatter the $100-per-barrel mark, with worst-case scenarios projecting peaks of $140.

ICE Endex
Dutch TTF Natural Gas Futures

European Energy Security Under Renewed Pressure

Strategic analysis from the European Union Institute for Security Studies highlights that conflict involving Iran has implications extending well beyond the Middle East battlefield (European Union Institute for Security Studies [EUISS], 2026). Although the European Union imports limited volumes of Iranian hydrocarbons directly, it remains deeply exposed to global price formation mechanisms. Oil markets operate globally; a disruption anywhere reverberates everywhere.

The inflationary consequences are particularly concerning. As reported by the Financial Times, economists warn that a sustained energy price spike could complicate the European Central Bank’s monetary trajectory by reigniting cost-driven inflation across the eurozone (Financial Times, 2026). Higher crude prices feed directly into transport and manufacturing costs, while elevated gas prices influence electricity markets in member states still reliant on gas-fired power generation.

The International Energy Agency has consistently emphasized that limited spare production capacity globally leaves markets highly sensitive to geopolitical shocks (International Energy Agency [IEA], 2025). In such an environment, even the risk of disruption can produce disproportionate price movements, amplifying economic uncertainty across the continent.

Transmission of the Shock to the Western Balkans

While Western Balkan states do not rely directly on Iranian crude or gas, they are deeply integrated into European pricing structures. Wholesale gas contracts across Southeast Europe are often indexed to benchmarks such as the Dutch TTF. As those benchmarks climb, the impact is transmitted almost automatically into domestic procurement costs.

Regional analysis from Kosovo Online underscores the potential economic consequences for Southeast Europe if the conflict escalates further (Kosovo Online, 2026). The report notes that higher fuel and electricity prices would strain household budgets and industrial competitiveness in economies already operating with limited fiscal buffers. Energy poverty, already a structural concern in parts of the region, could intensify.

While Brussels debates strategic reserves, the Balkan countries are already facing a “fossilflation” crisis. Data from Vox News and Monitor reveal that in countries like Albania, fuel prices at the pump are expected to rise by 15–20 lek per liter within days.

The Balkans suffer from a unique “import-dependency” trap. Unlike Western Europe, which has more diversified energy portfolios and deeper pockets for subsidies, the Balkan economies have high “pass-through” rates. In Romania and Hungary, every 10% increase in oil prices translates to a direct and significant jump in the Consumer Price Index (CPI).

Macroeconomic and Political Implications

The broader economic implications extend beyond energy bills. Rising import costs worsen trade balances in energy-importing economies, increasing external vulnerability. For Balkan states seeking closer integration with the European Union, prolonged energy instability risks undermining economic convergence.

Kosovo Online analysts warn that economic stress triggered by sustained energy price hikes could generate secondary effects, including migration pressures and political instability (Kosovo Online, 2026). In smaller economies with limited social safety nets, rapid increases in living costs can quickly translate into political volatility.

At the European level, policymakers are monitoring the situation closely. Coordinated gas storage strategies and diversification efforts implemented after the 2022 energy crisis provide a degree of resilience. However, as the EUISS analysis makes clear, geopolitical risk in the Middle East remains a systemic vulnerability for Europe’s energy security architecture (EUISS, 2026).

Outlook: Volatility as the New Baseline

The trajectory of oil and gas prices now hinges on the scale and duration of the conflict. Should the confrontation escalate to directly affect major production or LNG export facilities in the Gulf, further price surges are likely. Conversely, rapid diplomatic de-escalation could reduce the geopolitical risk premium currently embedded in futures markets.

For Europe, the challenge lies in managing macroeconomic stability while reinforcing long-term diversification. For the Balkans, the stakes are more immediate: household affordability, industrial resilience, and political equilibrium. In a globalized energy system, geographic distance offers no insulation. Conflict in the Gulf transmits through freight markets, commodity exchanges, and supply contracts — and ultimately into consumer bills in Belgrade, Sarajevo, Skopje, and Pristina.

The unfolding crisis underscores a fundamental reality of modern energy economics: security, stability, and price are inseparable. When geopolitical tensions rise in one region, the economic consequences reverberate across continents.

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AEA – Albania Energy Association is a industry association dedicated to representing the interests of Albanian and West Balkan for energy producers and consumers. AEA works to advance the development and adoption of sustainable energy solutions in Albania and the Western Balkans, supporting the region’s transition toward a cleaner, more secure, and more competitive energy future. AEA is registered by decision of the Court of Tirana, DECISION NO. 3032, (VAT:L11827451K).

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