FAQ: Biomethane

Yes, the main component of both fuels is methane (CH₄), so after upgrading biomethane is chemically interchangeable with natural gas, and differs solely in the origin of the feedstock.

Natural gas is a fossil fuel, while biomethane is produced from biomass or organic waste which, in the short carbon cycle, previously absorbed CO₂ from the atmosphere. For the end user it looks the same: the same flame, the same boiler, the same installation. Gas in the grid is mixed, so it is impossible to say which molecule comes from a biomethane plant. Origin is confirmed "on paper", mainly by a guarantee of origin and a sustainability certificate. Only these documents make it possible to account for the renewable share for renewable energy (OZE) purposes or in emissions reporting.

Sources: dena: Biomethane production — legal overview; European Biogas Association

Discussed in the article: Biomethane: what it is and how it differs from biogas and natural gas

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In practice a household uses biomethane indirectly: the gas in the grid is shared, so a customer can support biomethane only by buying a supplier's offer based on guarantees of origin, if such an offer is available.

Gas from a biomethane plant mixes in the grid with other gas, so you cannot deliver "your own" molecules to yourself. A supplier can, however, cancel guarantees of origin and offer green gas; such a product is developing in Europe. In Poland the biomethane market is only now taking shape: the first biomethane plants have been injecting gas into the grid since 2025, and the first guarantees were issued in 2026. Offers for individual customers are therefore limited. Before signing a contract, check exactly what the "green" product covers and how its origin has been confirmed.

Sources: Urząd Regulacji Energetyki; Towarowa Giełda Energii

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Yes, provided it meets the grid operator's quality requirements and the standards (e.g. EN 16723-1). Once injected, biomethane molecules cannot be distinguished from natural gas, so their origin is confirmed by documents.

Sources: IEA — Outlook for biogas and biomethane: Prospects for organic growth (2020); European Biogas Association; IEA Bioenergy Task 37 — Energy from Biogas

Discussed in the article: Biomethane: what it is and how it differs from biogas and natural gas

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Technically yes, compressed biomethane (bioCNG) can be delivered in containers, or liquefied (bioLNG) in tankers, to the injection point, but in Poland this solution requires clear regulations, which the industry is pushing for.

In such a model a small installation does not build its own gas pipeline but sends the gas by transport to a shared collection point at the grid, where it is decompressed and injected. The industry has put forward a demand for "biomethane collection points" as physical entry points to the grid for gas delivered by means other than a pipeline. The advantage is a lower connection cost for small producers; the drawback is the cost of transport and of compression energy. Before planning such a project, check the applicable regulations and the operator's rules.

Sources: globenergia.pl: Zmiany w ustawie jednak nie wyjdą branży biometanowej na dobre?; GAZ-SYSTEM

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Biomethane and hydrogen largely complement each other: biomethane is ready for use in existing gas grids and appliances, while hydrogen requires new infrastructure or limited blending into natural gas.

Biomethane can already be injected into the grid today and burned in existing boilers, engines or CNG and LNG vehicles. Hydrogen is a fuel with different properties: it has a lower calorific value per unit of volume, and its blending into the gas grid is limited. Both fuels can be produced from renewable sources and both will be needed where electrification is difficult. Their resources are, however, limited, and applications will differ depending on the sector, energy costs and the availability of infrastructure.

Sources: IEA — Outlook for biogas and biomethane: prospects for organic growth; European Biogas Association

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We found no confirmation of an operating installation injecting biomethane into the grid in South Africa. The projects described mainly concern compressed bioCNG supplied to industrial customers.

Sources: Biogas Valorisation to Biomethane for Commercialisation in South Africa: A Review — Energies 16(14), 5272 (MDPI); SABIA tackles biogas promotion with new vigour — Engineering News (17.10.2022); Afrox explores new market in bio-gas — gasworld (24.01.2017)

Discussed in the article: Biomethane in South Africa: what the 2023 review says about biogas upgrading and commercialisation

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There is no single threshold size, but upgrading and connection costs per unit of gas fall with scale, which is why biomethane plants are usually larger than biogas plants in cogeneration; the average in Europe is about 483 m³/h of biomethane.

Small installations can be profitable when they have a cheap substrate, a nearby connection, support or additional revenue from accepting waste. Large ones benefit from economies of scale but need more extensive logistics for substrates and digestate. A solution for smaller producers is sometimes to collect biogas from several producers at a single upgrading point, which requires a gas pipeline or transport. In Poland a distinction is made between support for installations up to 1 MW and above 1 MW (for biomethane: the installation's capacity converted into installed electrical capacity – Article 83l of the Act on Renewable Energy Sources (ustawa o OZE)), which translates into the choice of business model.

Profitability is determined by the technology, the biomethane price, the cost of connection to the grid and the availability of heat; small installations are also combined with other solutions, e.g. liquefaction or compressed transport.

Sources: European Biogas Association — Statistical Report 2025 (komunikat); IEA Bioenergy Task 37 — Energy from Biogas; Angelidaki et al. (2018), Biogas upgrading and utilization: Current status and perspectives — Biotechnology Advances; IEA Bioenergy Task 37 — Methane slip (prezentacja, 2023)

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A guarantee of origin confirms that the energy comes from a renewable source, while a sustainability certificate confirms that the biomethane meets the sustainability and greenhouse gas emission reduction criteria of the RED Directive, which is needed, for example, for it to count towards transport targets.

These are two independent documents with different functions. A guarantee serves to inform the customer and is recorded in the guarantee system. A sustainability certificate is issued by a certification body within a recognised scheme, e.g. ISCC, after an audit of the supply chain and the mass balance, and batch data goes to the EU Union Database. Biomethane sold to the transport market usually needs a sustainability certificate; a guarantee of origin does not replace it and does not in itself demonstrate that the sustainability criteria have been met. Permits and requirements depend on the application, so it is worth consulting a certification body before selling.

Sources: Dyrektywa (UE) 2023/2413 (RED III) — EUR-Lex; ISCC — International Sustainability and Carbon Certification; Komisja Europejska: Union Database for Biofuels — materiały szkoleniowe

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Biomethane is produced from biogas (fermentation of organic waste), and e-methane from the reaction of hydrogen with CO₂ (methanation). Chemically it is the same CH₄, but e-methane requires large amounts of cheap electricity and a source of CO₂.

Sources: Japan Gas Association – prezentacja dla IEA o e-metanie (R. Kuzuki, 05.09.2024); Argus – Australia's Santos, Japan's Hokkaido agree LNG deal (29.05.2024); LNG Prime – Four firms to work on e-methane supply chain from UAE to Japan (23.01.2024)

Discussed in the article: E-methane in Japan: a target of 1% in city gas by 2030 and 90% by 2050

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Biomethane is settled in units of energy (kWh or MWh) on the basis of the gas volume and its heat of combustion, measured at a metering station with a chromatograph at the grid entry point.

Volume is measured with a gas meter with pressure and temperature correction (to normal conditions), and the heat of combustion is determined from analysis of the gas composition. The product of volume and heat of combustion gives the amount of energy injected into the grid. The same measurements are used for commercial settlements and for issuing guarantees of origin, as well as for reporting quantities for sustainability certification. Measurement accuracy is important, because an error in the heat of combustion or in the volume translates directly into revenue and into settlements with support schemes. Detailed requirements are set by the grid operator.

Sources: GAZ-SYSTEM: Biometan w regulacjach krajowych i UE (prezentacja); GAZ-SYSTEM

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Biomethane is produced in several stages: fermentation of biomass, removal of hydrogen sulphide and moisture from the biogas, removal of CO₂, quality control and metering, odorisation (if required) and injection into the grid or filling of tanks.

First, biogas is produced in the biogas plant from substrates (slurry, manure, silage, biowaste, sludge). The gas then undergoes desulphurisation, drying and possibly removal of trace compounds, after which the upgrading installation separates CO₂ from methane. Next the gas is compressed to the pressure required by the grid, measured at the metering station and checked for quality. In Poland, biomethane, like natural gas, requires odorisation in distribution networks, if the operator requires it. The residual CO₂ stream is cleaned of methane, and the CO₂ is released or used.

Sources: European Biogas Association; IEA Bioenergy Task 37 — Energy from Biogas

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Most often two or three, with permeate recirculation. A multi-stage arrangement lowers methane losses and raises the purity of the biomethane, at the cost of a larger compressor.

Sources: IEA Bioenergy Task 37 — Energy from Biogas; European Biogas Association

Discussed in the article: Membrane upgrading: how CH₄ and CO₂ separation works in a biomethane plant

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With biogas containing about 50–60% methane, about 1.7–2 m³ of biogas is usually needed for 1 m³ of biomethane, because part of the volume is taken up by CO₂, which is removed.

The conversion depends on the methane content of the biogas, on the quality of the biomethane at the outlet and on the methane recovery in the upgrading installation. If the biogas contains 55% CH₄ and the product has about 97% CH₄ with almost full recovery, the result is about 1.8 m³ of biogas per 1 m³ of biomethane. Methane losses in the residual gas increase this requirement. That is why, when comparing technology offers, what matters is not only the methane concentration in the product but also the recovery, i.e. how much of the methane in the biogas actually ends up in the biomethane.

Sources: IEA Bioenergy Task 37 — Energy from Biogas; European Biogas Association

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According to industry estimates, the EU produced several billion m³ of biomethane a year; the target of 35 billion m³ by 2030 means roughly a tenfold increase relative to the 2020 level.

Sources: Komisja Europejska — plan REPowerEU, COM(2022) 230; Komisja Europejska — REPowerEU

Discussed in the article: REPowerEU: the Commission bets on biomethane – a target of 35 billion m³ a year by 2030

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According to the European Biogas Association, in 2024 Europe produced about 5.2 billion m³ of biomethane, of which 4.3 billion m³ in the EU-27, and installed capacity at the beginning of 2025 was about 7 billion m³ per year.

The number of installations differs between compilations, because it depends on the date and definitions: the GIE and EBA biomethane map gives 1548 installations in 2024 and 1678 in 2025. The most biomethane is produced by countries with a long biogas tradition, such as Germany, France, Italy and Denmark, as well as the United Kingdom and Sweden. For comparison, total gas consumption in the EU-27 is, according to the same sources, about 332 billion m³ per year, so biomethane covers only a small fraction for now. The REPowerEU target is 35 billion m³ of biomethane by 2030.

Sources: European Biogas Association — Statistical Report 2025 (komunikat); GIE i EBA: Europejska mapa biometanu 2025

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An application for connection conditions is submitted to the gas grid operator, and once they are issued, a connection agreement is concluded, an injection station and connection are built, followed by acceptance tests and commissioning.

Smaller installations are connected to the distribution network, and usually the largest ones to the transmission network operated by GAZ-SYSTEM. The operator assesses whether the grid at a given location is able to accept the planned volumes of gas; the absorption capacity of the local grid is often the main constraint, because gas consumption falls in summer. The process usually takes a long time, so investors start it in parallel with obtaining permits. Costs depend on the distance to the grid, the pressure and the station requirements. This is general information; the details result from the Energy Law, regulations and the operator's conditions.

Sources: GAZ-SYSTEM; Polska Spółka Gazownictwa; Ustawa Prawo energetyczne (Dz.U. 1997 nr 54 poz. 348) — ISAP

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Biomethane plants larger than those covered by the FIP premium (up to 1 MW) will be able to obtain support in biomethane auctions organised by the President of URE at least once a year – on the basis of the Act of 4 September 2026 (Journal of Laws (Dz.U.) 2026, item 1347), signed on 15 October 2026.

Auctions are held in two baskets: for installations below 2 MW and from 2 MW of electrical capacity (the capacity of a biomethane plant is converted using a unit efficiency of 41%). The winner is entitled to coverage of the negative balance for 20 years from the first sale, but no longer than until 31 December 2054, and must sell the first biomethane within 48 months of the close of the auction session. The producer chooses either an auction or FIP. The auction provisions enter into force on 17 February 2027, but apply only after a positive decision by the European Commission on state aid. Volumes will be set by a regulation of the Council of Ministers, and reference prices by the minister responsible for climate. This is general information, not legal advice.

Sources: gramwzielone.pl: Jest podpis prezydenta pod nowymi przepisami (16.10.2026); enerad.pl: Senat przyjął nowelizację ustawy o OZE; Ustawa o odnawialnych źródłach energii (Dz.U. 2015 poz. 478) — ISAP; Ustawa z 4 września 2026 r. o zmianie ustawy o OZE (Dz.U. 2026 poz. 1347) — API ELI Sejmu

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In practice, yes: the term 生物天然气 refers to biogas upgraded to natural gas quality, which can be directed, among other places, to city gas networks. The English-language press can be imprecise and simply writes “biogas”.

Sources: China Daily / Xinhua — China vows industrial development of biogas in new guideline (23.12.2019); China Energy Portal — Guiding opinions on promoting the industrialization of bio natural gas (tłumaczenie nieoficjalne); Xinhua (english.gov.cn) — doniesienie o wytycznych dla przemysłu biogazowego z 20.12.2019

Discussed in the article: China: ten institutions announce guidelines for “bio natural gas” — a target of 10 billion m³ by 2025

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The choice depends on the location and market conditions: cogeneration (CHP) is simpler and cheaper if electricity and heat can be sold, while biomethane pays off at larger scale, with a nearby gas grid and available support or an offtaker.

A CHP installation converts biogas on site into electricity and heat, part of which is used to heat the digesters. It needs a heat customer to achieve high efficiency. A biomethane plant sells gas that is more versatile and can be transported, but it needs investment in upgrading, a connection and metering. The average European biomethane plant produces about 483 m³/h of biomethane (EBA data for 2024), which shows that profitability grows with size. The decision is worth basing on a feasibility study with a sensitivity analysis of prices and support.

Sources: European Biogas Association; IEA Bioenergy Task 37 — Energy from Biogas

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Biomethane can feed the gas grid (heating, industry, cogeneration), serve as a transport fuel in the form of bioCNG or bioLNG, and be a feedstock in the chemical industry and for the production of synthetic fuels.

After injection into the grid, biomethane reaches customers in the same way as natural gas: boiler houses, industrial plants and gas-fired combined heat and power plants, and transport and industry, which are looking for low-emission fuels, are becoming increasingly important. The carbon dioxide separated during upgrading can be an additional product. For biomethane, the role of proof of origin is also growing, because it is this that allows the gas to be sold as renewable. The application depends on local conditions, the gas price, support and the availability of a grid or refuelling stations.

Sources: IEA — Outlook for biogas and biomethane: prospects for organic growth; European Biogas Association

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The separated CO₂ is usually released into the atmosphere after residual methane has been removed, but it can also be liquefied and sold for industrial or food uses, or for capture and storage.

This is biogenic CO₂, because it comes from the decomposition of biomass that previously took up that carbon from the atmosphere. Its recovery requires an additional cleaning and liquefaction installation and a buyer within a reasonable distance, which limits the profitability of smaller plants. As a food or beverage additive, CO₂ must meet quality and safety requirements, and not every stream from a biogas plant is suitable. In the longer term, biogenic CO₂ is considered a feedstock for synthetic fuels and for negative-emission applications (BECCS), but today this is mainly a direction of development.

Sources: European Biogas Association; IEA — Outlook for biogas and biomethane: prospects for organic growth

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A biomethane guarantee of origin is an electronic document that confirms to the end customer that a given amount of energy in the gas was produced from renewable sources, and it can be traded independently of the physical gas.

Under EU law a standard guarantee corresponds to 1 MWh of energy, and its issuance is not state aid. In Poland guarantees are issued by the President of the Energy Regulatory Office (URE) at the producer's request, and the register is kept by the Polish Power Exchange (Towarowa Giełda Energii), which also organises their trading. According to reports, URE issued the first guarantees for biomethane injected into the grid on 25 September 2026 (for the first half of 2026). A guarantee confirms origin, but it does not replace a sustainability certificate or proof that the emission-reduction criteria have been met.

Sources: gramwzielone.pl: URE wydał dwa ważne dokumenty dla biometanu; Dyrektywa (UE) 2018/2001 (RED II) — EUR-Lex; Ustawa o odnawialnych źródłach energii (Dz.U. 2015 poz. 478) — ISAP

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Biomethane is biogas that has been cleaned and upgraded to natural gas quality, usually with more than 95% methane, so it can be injected into the gas grid, compressed or liquefied and used in the same way as fossil gas.

Raw biogas from methane fermentation usually contains about half methane, the rest being mainly CO₂ and trace amounts of hydrogen sulphide, water vapour and other impurities. During upgrading, CO₂ and contaminants are removed and the gas is adjusted to grid parameters. Chemically, biomethane does not differ from methane in natural gas; it differs in origin, because it is produced from waste and agricultural by-products, biowaste or sewage sludge. This is why, in trade, documents confirming origin matter, such as guarantees of origin and sustainability certificates.

Sources: European Biogas Association; IEA — Outlook for biogas and biomethane: prospects for organic growth

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It includes hydrogen and gaseous fuels produced from fossil fuels with CO₂ capture or from nuclear energy that meet the life-cycle emission reduction threshold. It is distinguished from renewable gases, including biomethane, by the source of the feedstock.

Sources: Wniosek COM(2021) 803 — dyrektywa o wspólnych zasadach dla rynków gazów odnawialnych i ziemnego oraz wodoru (EUR-Lex); Wniosek COM(2021) 804 — rozporządzenie w sprawie rynków gazów odnawialnych i ziemnego oraz wodoru (EUR-Lex)

Discussed in the article: Gas package: definitions of renewable and low-carbon gases and easier access for biomethane

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Methane slip is the loss of unrecovered methane in the CO₂ stream leaving the upgrading installation; it matters because it reduces the amount of gas sold and worsens the climate balance, since methane is a potent greenhouse gas.

A good installation has systems that limit this loss, for example thermal or catalytic oxidation of the residual gas or a multi-stage membrane arrangement. Methane losses are calculated as the share of methane in the residual gas relative to the total amount of methane in the biogas. Producers want low losses for two reasons: every cubic metre lost is lost revenue, and in emissions accounting (e.g. under RED) losses raise the carbon footprint of the biomethane. When purchasing technology, it is worth asking about guaranteed recovery, and after commissioning regularly checking tightness and emissions.

Sources: IEA Bioenergy Task 37 — Energy from Biogas; IEA — Outlook for biogas and biomethane: prospects for organic growth

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The industry estimates that Poland could produce even several billion m³ of biomethane per year (in some statements up to 8 billion m³), but this is a theoretical potential dependent on support, grid access and the availability of substrates.

Poland has large feedstock resources: high livestock production (slurry, manure, poultry droppings), waste from the food industry and agriculture, and municipal biowaste and sludge. To the technical potential, however, constraints must be added: local competition for substrates, residents' opposition, grid requirements and costs. Estimates differ depending on assumptions and institutions, and the "over a hundred" projects reported by investors is not equivalent to the number of installations built. Higher figures are best treated as a scenario requiring support, not as a forecast.

Sources: globenergia.pl: Zmiany w ustawie jednak nie wyjdą branży biometanowej na dobre?; globenergia.pl: Biogaz i biometan w Polsce — bilans sektora na koniec 2025 r.

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The REPowerEU plan of 2022 envisages reaching 35 billion m³ of biomethane per year by 2030 in the European Union, which would replace part of the imported natural gas.

This target was announced by the European Commission in May 2022 in response to the gas crisis following Russia's aggression against Ukraine. It is a political target, not a binding requirement for individual countries. Delivering it requires simplified permitting, investment support, access to the grid and stable demand. According to industry data, in 2024 the EU-27 produced about 4.3 billion m³ of biomethane, so reaching the target requires a manifold increase in production. The pace depends on national support systems, including Polish auctions and FIP.

Sources: Komisja Europejska — Dyrekcja Generalna ds. Energii; European Biogas Association

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It is a British system of tariffs paid for 15 years for biomethane injected into the gas grid, financed from a charge (the Green Gas Levy) imposed on gas suppliers. It replaced older support mechanisms and is open to anaerobic digestion installations.

Sources: UK government extends Green Gas Support Scheme to 2028 — Bioenergy News; Green Gas Support Scheme (GGSS) — GOV.UK

Discussed in the article: UK extends Green Gas Support Scheme to March 2028

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There is no single legal threshold for all countries. In practice, modern plants aim for values below 1%, and where off-gas afterburning is used, the effective emission is even lower.

Sources: IEA Bioenergy Task 37 — Energy from Biogas; IPCC AR5 — Climate Change 2013: The Physical Science Basis

Discussed in the article: Methane slip in biogas upgrading: how much we lose and what it costs

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Biomethane must meet the grid operator's quality requirements, including an appropriate calorific value and Wobbe index, a low content of sulphur, oxygen, CO₂ and moisture, and no contaminants harmful to the grid and to customers.

The specific limits result from regulations on the quality of gaseous fuels, from the operator's network operation and maintenance code and from the connection agreement. In Europe the reference point is the EN 16723-1 standard (applied in Poland as PN-EN 16723-1), which describes the specification of biomethane intended for injection into the natural gas grid. The producer monitors quality continuously (chromatograph, dew point and sulphur measurement), and gas that does not meet the requirements is automatically recirculated or flared. Check the current limits directly with the operator of the grid you intend to connect to.

Sources: GAZ-SYSTEM; GAZ-SYSTEM: Biometan w regulacjach krajowych i UE (prezentacja)

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Small biomethane installations with an installed capacity of up to 1 MW (converted into installed electrical capacity) can use the feed-in premium (FIP) system, in which the producer sells biomethane on the market and the missing difference up to the reference price is covered by a premium paid by the Settlement Administrator (Zarządca Rozliczeń).

To benefit, the producer submits a declaration of intent to sell biomethane at the reference price, and the President of URE issues a certificate confirming the possibility of sale. According to reports, URE issued the first such certificate on 24 September 2026. The support is limited in time and by state aid rules, and the 2026 amendment changes some of the FIP parameters. Check the exact level of the reference price, the support period and the conditions in the Act on Renewable Energy Sources (ustawa o OZE), regulations and URE announcements. This is general information.

Sources: gramwzielone.pl: URE wydał dwa ważne dokumenty dla biometanu; Ustawa o odnawialnych źródłach energii (Dz.U. 2015 poz. 478) — ISAP

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Four families of technology are used most often: membrane separation, pressure swing adsorption (PSA), water scrubbing and amine absorption, and increasingly also cryogenic separation.

Membranes let CO₂ through faster than methane and are modular, so they suit installations of various scales. PSA uses an adsorbent (usually carbon or zeolite) that retains CO₂ at elevated pressure. Water scrubbing relies on the better solubility of CO₂ in water than of methane. Amines give very high methane recovery but require heat to regenerate the solvent. Cryogenics cools the gas to separate CO₂ and combines well with liquefaction to bioLNG. The choice depends on scale, heat availability, CO₂ purity requirements and energy costs; there is no single best technology.

Sources: IEA Bioenergy Task 37 — Energy from Biogas; European Biogas Association

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The first biomethane plant connected to the gas grid in Poland was commissioned in September 2025 at the Strzelin sugar factory (Südzucker Polska), and in September 2026 the first agricultural biomethane plant started up, in Komorowo in the municipality of Ostrów Mazowiecka.

According to industry reports, Strzelin processes sugar beet residues, and the gas reaches the grid through a pipeline built by Polska Spółka Gazownictwa. Komorowo uses only agricultural waste, mainly manure and slurry, and planned annual biomethane production is about 20 GWh. At the end of 2025 more than 400 biogas installations were operating in Poland, but the vast majority are biogas plants with cogeneration, not biomethane plants. The list remains short and changes quickly, so check the current status in industry sources.

Sources: globenergia.pl: Biogaz i biometan w Polsce — bilans sektora na koniec 2025 r.; GAZ-SYSTEM

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The cost of the connection depends on the rules set out in regulations and in the connection agreement, and in practice a significant part, especially the injection station and the pipeline to the connection point, is borne by the biomethane plant's investor.

The connection fee is set according to the rules of the Energy Law and the operator's tariff, usually on the basis of the outlays needed to carry out the connection. Biomethane plants are often located far from the gas pipeline, so the connection pipeline can be one of the largest costs of the project. The amendment to the Act on Renewable Energy Sources (ustawa o OZE) of 4 September 2026 (Journal of Laws (Dz.U.) 2026, item 1347, mostly from 1 December 2026) organises the rules for building direct gas pipelines for biogas and biomethane, which may make it easier to reach the grid. Before an investment decision, obtain the connection conditions and a cost estimate from the operator. This is general information, not legal advice.

The investor also bears the cost of its own equipment: the metering station, quality analysers, compression and the reverse-flow installation.

Sources: Ustawa Prawo energetyczne (Dz.U. 1997 nr 54 poz. 348) — ISAP; Urząd Regulacji Energetyki; Ustawa z 4 września 2026 r. o zmianie ustawy o odnawialnych źródłach energii oraz niektórych innych ustaw, Dz.U. 2026 poz. 1347; Ustawa z 10 kwietnia 1997 r. – Prawo energetyczne — Internetowy System Aktów Prawnych; Urząd Regulacji Energetyki

Discussed in the article: Connecting a biomethane plant to the gas grid: conditions, costs and liability

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Danish biogas plants have benefited from stable support for years, and the gas, once upgraded, enters a well-developed gas grid that makes it possible to take biomethane from many plants.

Sources: S&P Global: Denmark hikes proportion of biogas in grid to 25% — grid operator; Energinet — informacje o biometanie w Danii

Discussed in the article: Denmark: biomethane is already nearly a quarter of the gas in the grid. A record at the end of 2021

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Biomethane makes it possible to reduce emissions from heavy-duty and maritime transport without replacing the fleet, because it is interchangeable with natural gas, which powers CNG and LNG vehicles, and with a suitable feedstock it delivers a large life-cycle emission reduction.

The RED III Directive sets the share of renewable energy in transport and a sub-target for advanced biofuels and RFNBO fuels, and biomethane from waste and residues qualifies as an advanced biofuel (Annex IX). For long-haul lorries, city buses or ships, batteries and hydrogen have limits on range and cost, whereas gas vehicles are already on the road. Biomethane can therefore reduce emissions "right away" in existing vehicles. The limitation is the availability of reliably certified gas and competition from other uses.

Sources: Dyrektywa (UE) 2023/2413 (RED III) — EUR-Lex; Rozporządzenie (UE) 2023/1804 (AFIR) — EUR-Lex

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