March 3, 2026
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Renewable Gas Injections in the EU Rise to 4.3 bcm Over Two Gas Years, ENTSOG Reports

Renewable gas injections into natural gas grids across the European Union have climbed steadily over the past two gas years, reaching 4.3 billion cubic meters (bcm), according to the latest assessment by European Network of Transmission System Operators for Gas (ENTSOG).

The report, covering the period from October 1, 2023, to September 30, 2025, examines annual renewable gas injections into transmission and distribution networks. It encompasses both biomethane and renewable hydrogen.

Steady Growth in Renewable Gas Volumes

According to ENTSOG, renewable gas injections rose from 38.1 TWh to 43.2 TWh over the two most recent gas years—equivalent to approximately 4.3 bcm—representing an annual increase of 12%.

This marks ENTSOG’s second dedicated report on renewable gas injections into European gas networks. The first assessment was included in its 2024 Annual Report, published in April 2025, and covered data for the 2023–2024 gas year.

The latest growth was primarily driven by the commissioning of new biomethane plants and existing facilities reaching their nominal production capacity.

Renewable hydrogen injections remained limited. Germany was the only member state reporting hydrogen injection into its gas system, with volumes declining from 3 GWh to 1 GWh during the reporting period.

It should be noted that the report does not account for biomethane flows occurring outside transmission system operator (TSO) and distribution system operator (DSO) grids.

Biomethane Growth Without Major Infrastructure Investments

Piotr Kuś, ENTSOG’s General Director, emphasized that renewable and low-carbon gases can be readily integrated into existing natural gas infrastructure, supporting the transport of sustainable and secure energy molecules.

He stressed that gas TSOs will continue to provide the necessary infrastructure to facilitate the energy transition.

“In particular, biomethane market growth can be facilitated without the need for significant infrastructure investments. This growth is essential if we are serious about meeting the EU’s REPowerEU target of 35 bcm biomethane by 2030,” Kuś said, referring to the European Union’s REPowerEU objectives.

Five Countries Dominate Renewable Gas Injections

The distribution of biomethane injections varies significantly among EU member states. Five countries—France, Germany, Denmark, Italy, and Netherlands—accounted for 94% of total renewable gas injections, the report reveals.

Several member states reported no injections, in some cases due to on-site consumption of renewable gases that eliminates the need for grid injection.

Among the five leading countries, all recorded significant increases in biomethane injections into TSO and DSO grids during the last gas year.

France posted a 2 TWh rise in injections, reaching 13 TWh—approximately 1.3 bcm—by the end of the reporting period. The increase was attributed to the continued rollout of new injection points and the gradual ramp-up of production sites to full operational capacity, a process that often takes time following initial commissioning, according to the Report on Annual Renewable Gas Injections into Gas Networks.

September 10, 2025
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Romania preparing to include biomethane in gas grid

Romania has drafted a directive that would regulate the production, transportation and distribution of biomethane and its inclusion into the gas network. The change is aimed at limiting the increase in the prices of gas for household heating, expected from the upcoming introduction of the ETS 2 carbon allowance scheme in the European Union. Delaying the shift would also affect the costs of industrial production and for other non-household consumers of gas.

Biomethane produced from sustainable sources is carbon neutral under the EU Emissions Trading System (EU ETS), making it appropriate for buildings and transportation, the Romanian Ministry of Energy said in a new draft emergency ordinance. With the executive order, it intends to pave the way for utilizing the renewable fuel in the natural gas network, Profit.ro reported.

The document is set to amend several acts and regulate the production, transportation and distribution of biomethane. It would counter, to an extent, the increase in gas prices for households, which is expected from the expansion of the EU’s carbon pricing scheme to buildings and transportation, the ministry explained. Namely, ETS 2 is scheduled to be introduced in 2027.

Biomethane is usually obtained by processing biogas to get methane of the same purity as in fossil gas

Any delay in allowing biomethane in the existing grid draws a risk of increasing the costs of natural gas consumption, both for non-household and household customers, the accompanying note reads.

Biomethane is usually obtained by processing biogas to get methane of the same purity as in fossil gas. The gaseous biofuel can also be produced from clean hydrogen and carbon dioxide. The EU allows incentives for biomethane facilities. Some countries in Southeastern Europe, like Greece, are developing the legal framework for embracing the technology within their energy transition.

Share in gas network planned to reach 10% by 2050

Romania is planning a 5% share of biomethane in its natural gas network in 2030 and to double it by mid-century. The sectors of waste management and agriculture can produce an estimated 501,000 tons of oil equivalent in 2050.

The EU is imposing strict requirements on the removal of biodegradable organic matter from wastewater and the reduction of food waste, the ministry noted. Together with agricultural and organic municipal waste, they are the main raw materials for the production of biogas.

According to the proposal, publicly announced business plans can secure a share of renewable gases in the grid up to 1.5%. However, without an urgent legislative intervention, the investments can’t materialize, the Ministry of Energy warned. The draft directive would update the definitions of guarantees of origin, biogas, biomethane, natural gas, renewable gases and biomethane producers.

BSOG Energy, Engie Romania at forefront of upcoming biomethane investment wave

As for other developments in the segment, BSOG Energy (BSOGE), a subsidiary of Black Sea Oil and Gas, recently hired industrial services provider Bilfinger for a biomethane facility in Alba county in Transylvania.

Earlier, BSOGE said it would invest EUR 30 million in the construction of a biomethane plant. It has signed deals with milk producer DN Agrar Group for up to 15 MW in capacity, with the possibility of exceeding 20 MW in later stages.

In April, the firm partnered with Unigrains Trading in a project for a biomethane and organic fertilizer facility. They estimated the investment at EUR 65 million, for 57 MW of biomethane capacity and over 250,000 tons of organic fertilizers per year. Parent company BSOG is controlled by controlled by investment firm Carlyle.

Engie Romania launched plans a year ago with Heineken to build a biodigester for brewery waste

Last November, French-owned Engie Romania obtained the first license in the country for biogas and biomethane supply. Earlier it established a partnership with Heineken for decarbonization projects in three breweries in Romania, including heat pumps and one biodigestion system.

The firm is the largest supplier and distributor of natural gas in the country, as well as an electricity producer and supplier.

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July 24, 2025
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IRENA: 91% of new renewables units are more cost-effective than fossil fuel alternatives

The fossil fuel age is crumbling, according to UN Secretary-General António Guterres. Renewables maintained their cost leadership in global power markets, the International Renewable Energy Agency said in an annual report. In 2024, onshore wind farms were the cheapest of all versus the lowest-cost fossil fuel alternatives, by 53% on average, while photovoltaic systems were 41% cheaper.

Onshore wind power was also the cheapest in levelized cost of electricity (LCOE) terms, followed by solar power. At the same time, 91% of newly commissioned utility-scale capacity was delivering power at a cost lower than for the cheapest electricity from new fossil fuel–fired units.

The Renewable Power Generation Costs in 2024 report confirmed the price advantage of renewables over fossil fuels, with cost declines driven by technological innovation, competitive supply chains and economies of scale, the International Renewable Energy Agency said. IRENA expects cost reductions to continue, but highlighted the short-term challenges.

Geopolitical shifts including trade tariffs, raw material bottlenecks, and evolving manufacturing dynamics, particularly in China, could temporarily raise costs.

Asia, Africa and South America, with stronger learning rates and high renewable potential, could see pronounced cost declines.

Higher costs are likely to persist in Europe and North America, driven by structural challenges such as permitting delays, limited grid capacity, and higher balance-of-system expenses, according to the update. In contrast, regions like Asia, Africa and South America, with stronger learning rates and high renewable potential, could see pronounced cost declines.

The organization pointed to the need for stable and predictable revenue frameworks to lower investment risk and attract capital.

“Clean energy is smart economics – and the world is following the money,” United Nations Secretary-General António Guterres stressed. In his view, the fossil fuel age is crumbling.

Capital costs inflating LCOE in developing countries

Mitigating financing risk is central to scaling renewables in both mature and emerging markets. Instruments such as power purchase agreements (PPAs) play a pivotal role in accessing affordable finance, while inconsistent policy environments and opaque procurement processes undermine investor confidence, IRENA added.

In many developing countries of the Global South, high capital costs, influenced by macroeconomic conditions and perceived investment risks, significantly inflate the levelized cost of electricity (LCOE) of renewables.

Onshore wind power production cheapest by far of all kinds of electricity

In 2024, onshore wind farms were the cheapest of all versus the lowest-cost fossil fuel alternatives, by 53% on average, while photovoltaic facilities were 41% cheaper. Of note, the cost of battery energy storage systems (BESS) declined by 93% from 2010 to 2024, to USD 192 per kWh.

Onshore wind remained the most affordable source of new renewable electricity, with a global weighted average LCOE at USD 0.034 per kWh (USD 34 per MWh), followed by new solar, at USD 0.043 per kWh, and new hydropower plants, USD 0.057 per kWh.

Again per the levelized cost of electricity, 91% of newly commissioned utility-scale renewables capacity was delivering power at a lower cost than the most affordable new fossil fuel–based units.

That said, LCOE increased slightly for solar power, by 0.6%. Onshore wind power was 3% more expensive than in 2023, compared to 4% for offshore wind and 13% for the bioenergy segment. Meanwhile, costs declined for concentrated solar power (CSP), by 46%, followed by electricity from geothermal units, 16%, and hydropower, which slipped 2%.

Solar and wind energy prices have begun to stabilize, which is a natural sign of market maturity, the authors underscored.

Photo: Renewable energy LCOE 2010-2024, in United States dollars per kilowatt-hour (IRENA)

Clear path to affordable, secure, sustainable energy

The addition of 582 GW of renewables capacity in 2024 led to significant cost savings, avoiding fossil fuel use valued at about USD 57 billion, new data shows. Looking at all renewables in operation, the avoided fossil fuel costs in 2024 reached up to USD 467 billion, IRENA’s Director-General Francesco La Camera stated.

New renewable power outcompetes fossil fuels on cost, offering a clear path to affordable, secure and sustainable energy, he pointed out.

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June 26, 2025
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Greece to rely on carbon price, renewables potential in green hydrogen development

Despite early efforts to develop green hydrogen and its first regulatory framework, Greece finds itself on a steep curve.

The government has presented the first law on hydrogen and renewable gases in parliament. At the same time, refineries and other industries are working on projects that will determine green hydrogen’s cost-effectiveness.

However, a significant obstacle is the government’s unwillingness to support the new technology, either through subsidies or other financial instruments. The Ministry of Environment and Energy has specified that no upcoming technology would benefit from public funds. The goal is to maintain a low cost for the consumer during the energy transition.

According to Professor Pantelis Kapros from the National Technical University of Athens (NTUA), it means hydrogen will have to rely almost exclusively on the price of carbon. As the European Union’s European Trading System (EU ETS) is about to enter its second phase in 2026, the price of carbon allowances is projected to rise steeply.

Even so, market participants estimate that a ton of carbon dioxide equivalent would need to cost EUR 140, two times more than today, to make green hydrogen competitive against grey hydrogen, which is produced from natural gas.

Exports and power prices added to the equation

Regardless, Greece sees an opportunity to produce and export green hydrogen. The reason is its high renewables potential and production. The ever-increasing photovoltaic capacity has caused an overabundance of energy during the day. More demand is needed to balance the system and hydrogen can provide a way out.

Tsafos: We want to become a supplier

The hope is that the low renewable energy cost, combined with potential interest in shipping hydrogen abroad, will justify long-term investments.

“Our view is that as long as the market is interested, we want to become a supplier,” Deputy Minister of Environment and Energy Nikos Tsafos said at the Hydrogen & Green Gases Forum in Athens.

A potential problem is that green hydrogen plants are not expected to be viable if they only produce during the day, when renewable energy prices are usually lower. “Ten hours of operation are not enough to support producers and there are also technical issues to solve,” said Dimitris Kardomateas, head of the Center for Renewable Energy Sources and Saving (CRES).

He also pointed to the average daily wholesale power price, as it is higher in Greece than in most other European markets. It should be noted that electricity makes up about 70% of the total operating cost of electrolyzers.

Biomethane considered more mature

On the other hand, biomethane is considered much easier to develop.  The technology depends less on power prices and also faces fewer technical hurdles. “Biomethane has a clear role, especially through its ability to enter the gas network, and we want to utilize it”, said Tsafos.

Gas distribution company Enaon EDA emphasized its readiness to include biomethane in its network. Its CEO Barbara Morgante noted that a study is underway to pinpoint the various existing and planned biomethane production plants around the country, as well as their proximity to Enaon’s network.

Biomethane is usually obtained by processing biogas to get methane of the same purity as in fossil gas. The renewable fuel can also be produced from clean hydrogen and CO2.

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April 24, 2025
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Greece’s DEPA Commercial picks contractors for PV plants of 500 MW

Construction companies Terna and Aktor are about to start building a solar power plant of 400 MW in northern Greece and another 100 MW near Larissa, for state-owned DEPA Commercial, according to a new report. In its switch toward cleaner sources, the gas holding has also finished the construction of its biomethane plant.

Greek state-controlled gas supplier, importer and trader DEPA Commercial has completed the tenders for photovoltaic parks of 500 MW overall, OT learned. The 400 MW facility in Kozani in the Western Macedonia province would currently be the largest in the country.

However, Lightsource bp, owned by BP, started the construction of a 560 MW solar park last summer in Central Greece and Thessaly. State-controlled Public Power Corp. (PPC or DEI) is about to finish a 550 MW photovoltaic facility in Ptolemaida, near Kozani.

DEPA Commercial is also known as DEPA Emporias (in Greek), DEPA Commerce and DEPA Trading. Both for the giant PV plant in northern Greece and another 100 MW in Farsala, Larissa, it selected the consortium of Terna, part of the GEK Terna conglomerate, and Ellaktor’s Aktor.

The turnkey deals are worth EUR 270 million in total

The turnkey agreements are worth a combined EUR 270 million. The company obtained a EUR 390 million loan in July from the European Investment Bank (EIB) for its photovoltaic projects. The portfolio amounted to 816 MW.

The projects, which are at various stages of maturity, are conducted under subsidiaries North Solar, North Solar 1 and New Spes Concept.

DEPA Commercial’s new move comes after the government bought a 35% stake from Helleniq Energy. The company is now fully owned by the Hellenic Republic Asset Development Fund (HRADF or TAIPED). The transaction was completed at the turn of the year, when the vehicle also integrated the so-called Superfund.

DEPA Commercial starts producing biomethane for its fuel stations

Within its energy transition efforts, the gas giant is entering biomethane production as well. DEPA Commercial said early this month that it produced Greece’s first quantities of the fuel.

The new pilot unit, Farma Hitas (Chitas) in Filippiada in the country’s west, makes 97% pure methane and compresses it. The bio-CNG goes to the company’s Fisikon gas stations, where it is mixed with natural (fossil) gas and sold as vehicle fuel.

Ownership stakes in Alexandroupolis gas complex, IGB pipeline

As for its conventional business operations, DEPA Commercial holds a 29% stake in special purpose firm Ilektroparagogi Alexandroupolis (Alexandroupolis Electricity Production). PPC is the majority partner, with 71%.

They are building a combined-cycle gas turbine (CCGT) of 840 MW. In addition, DEPA Commercial owns 20% of the Alexandroupolis LNG Terminal and 25% of ICGB, which operates the Interconnector Greece-Bulgaria (IGB) gas pipeline.

The company is participating in the Fier Thermoelectric project for a 174 MW gas power plant in Albania. DEPA Commercial intends to supply some of the renewable electricity that it generates to its wholly-owned subsidiary Fysiko Aerio – Hellenic Energy Co. The gas and electricity distributor has more than 530,000 customers.

Notably, DEPA Commercial already owns an aggregator license – FOSE, allowing it to trade in the wholesale power market on behalf of a group of producers.

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