Why is methane leak detection important for gas distribution companies?

Methane leak detection is important for gas distribution companies because undetected leaks create serious safety risks, cause significant revenue loss through wasted product, and generate methane emissions that contribute to climate change. For gas network operators, detecting and repairing leaks promptly is both a legal obligation and a core operational responsibility. The questions below unpack the key reasons, methods, and regulations that make leak detection a central priority for any gas distribution business.

What happens if a gas distribution company doesn’t detect methane leaks?

If a gas distribution company fails to detect methane leaks, it faces a combination of safety hazards, financial losses, environmental damage, and regulatory penalties. Methane is highly flammable, and accumulations in enclosed spaces can cause explosions. Beyond the immediate danger, undetected leaks mean product loss that directly reduces revenue and increases operational costs over time.

From a regulatory standpoint, the consequences have become significantly more serious in recent years. EU Regulation 2024/1787 on methane emissions introduces fines of up to 20% of annual turnover for non-compliant operators. For large transmission and distribution network operators, that represents enormous financial exposure. Regulators now require documented evidence of systematic Leak Detection and Repair (LDAR) programmes, meaning that failing to detect leaks is no longer just an operational oversight but a legal violation.

There is also a reputational dimension. As energy companies face increasing scrutiny from investors, regulators, and the public over their environmental footprint, poor methane management can damage trust and complicate access to financing or operating licences.

How does methane leak detection work in large pipeline networks?

Methane leak detection in large pipeline networks works by systematically surveying infrastructure using sensors that identify the presence of methane gas above background atmospheric levels. In large networks, this typically involves a combination of walking surveys, vehicle-mounted sensors, and, increasingly, aerial platforms that can cover long distances quickly.

The core principle relies on the fact that methane absorbs light at specific wavelengths. Technologies such as Differential Absorption LIDAR (DIAL) exploit this property by emitting laser pulses at two different wavelengths and measuring the difference in absorption to identify methane concentrations along the survey path. This allows detection without physical contact with the pipeline or ground.

For networks spanning hundreds or thousands of kilometres, speed matters enormously. Ground-based walkers can cover only a few kilometres per day, while vehicle-mounted systems improve on this but are limited by road access. Aerial systems can survey pipeline corridors at speeds of up to 180 km/h, making them particularly well suited to transmission pipelines running through rural or difficult terrain. Survey results are typically delivered through digital platforms, allowing operators to prioritise and act on findings efficiently.

What are the EU Methane Regulation requirements for gas network operators?

EU Regulation 2024/1787 requires gas network operators to implement structured LDAR programmes, report methane emissions transparently, and repair detected leaks within defined timeframes. The regulation applies to transmission, distribution, and storage operators, making it one of the most comprehensive methane rules ever introduced in Europe.

Key obligations under the regulation include:

• Regular LDAR surveys at mandated intervals, with underground equipment subject to Type 2 survey requirements that demand high-sensitivity detection methods
• Leak repair timelines that set deadlines for fixing identified leaks depending on their severity and classification
• Emissions reporting through transparency tools that make methane data accessible to regulators and, in some cases, the public
• Documentation and audit trails demonstrating that surveys were conducted correctly and that findings were acted upon

The regulation significantly shortens inspection intervals compared to previous national standards in many member states, which means operators who previously relied on slower survey methods may now need to adopt faster technologies to stay compliant. Penalties for non-compliance can reach 20% of annual turnover, giving operators a strong financial incentive to invest in capable, approved detection systems.

How often should gas pipelines be inspected for methane leaks?

Under EU Regulation 2024/1787, the required inspection frequency for gas pipelines depends on the type of equipment and the pressure level of the network. For underground equipment on transmission and distribution networks, the regulation has tightened intervals considerably compared to many previous national requirements, in some cases nearly doubling the frequency of required surveys.

While specific intervals vary by equipment category and member state implementation, the general direction of the regulation is clear: more frequent inspections, conducted with higher sensitivity. Operators who previously surveyed their networks every few years may now need annual or more frequent cycles. This shift has significant implications for how operators plan and resource their pipeline inspection services, particularly for those managing thousands of kilometres of infrastructure.

Practically speaking, more frequent inspections mean that survey speed becomes a competitive factor. A method that takes weeks to cover a large network may not be viable if the regulatory window requires completion within a tighter timeframe. This is one reason why aerial survey methods have gained traction among large network operators looking to maintain compliance without proportionally scaling up inspection costs.

What’s the difference between ground-based and airborne methane detection?

The key difference between ground-based and airborne methane detection is speed and coverage. Ground-based methods, including walking surveys and vehicle-mounted sensors, are thorough but slow. Airborne systems can survey pipeline corridors far more quickly, covering large distances in a fraction of the time, making them better suited to large transmission networks.

Ground-based detection

Ground-based LDAR typically involves technicians walking pipeline routes with handheld detectors or driving vehicle-mounted systems along accessible roads. These methods are well established and effective for urban distribution networks where pipelines run under streets and inspectors can access the route easily. However, coverage rates are limited, and remote or rural sections of transmission pipelines can be difficult or impossible to reach by road.

Airborne detection

Airborne methane detection uses helicopter or fixed-wing platforms equipped with laser-based sensors to survey pipeline corridors from above. Systems based on the DIAL method can detect leaks at very low concentrations, even at survey speeds of up to 180 km/h and altitudes of 100 to 150 metres. This makes aerial surveys practical for long-distance transmission pipelines crossing varied terrain. The trade-off is that airborne systems are generally less suited to dense urban distribution networks where low-altitude flight is not practical.

For most large gas network operators, the most effective approach combines both methods: airborne surveys for transmission lines and longer rural distribution routes, supplemented by ground-based surveys in urban areas. The EU Methane Regulation’s Type 2 requirements for underground equipment specifically call for high-sensitivity detection, which airborne laser systems are well positioned to meet.

How can gas distribution companies reduce methane emissions efficiently?

Gas distribution companies can reduce methane emissions efficiently by combining high-speed detection surveys with systematic repair programmes, prioritising the highest-emitting leaks first, and using digital tools to track and verify repair outcomes. Efficiency comes from both finding leaks faster and fixing the most significant ones without delay.

Practical steps that support efficient emissions reduction include:

• Adopting aerial survey technology for large-scale network coverage, reducing the time and cost of identifying leaks across extensive pipeline systems
• Prioritising repairs by leak rate so that high-volume emissions are addressed before smaller ones, maximising the environmental benefit per repair action
• Using integrated digital platforms that connect survey data directly to maintenance workflows, reducing the lag between detection and repair
• Maintaining accurate asset records to ensure no sections of the network are missed during inspection cycles
• Tracking emissions over time to measure the impact of repair programmes and demonstrate progress to regulators

Efficiency also means choosing detection methods that match the scale of the network. For operators managing hundreds or thousands of kilometres of pipeline, investing in fast, sensitive survey technology pays for itself by reducing personnel time and the logistical cost of slower ground-based methods, while delivering the high-sensitivity data required under current regulations.

How ADLARES helps gas distribution companies with methane leak detection

We at ADLARES have been providing airborne gas leak detection services since 2008, and to date we have surveyed over 250,000 km of gas pipelines across Europe. Our CHARM® technology is the world’s only DVGW-approved airborne gas remote detection system, purpose-built to meet the demands of large-scale gas network operators.

Here is what working with us delivers for gas distribution companies:

• High-sensitivity detection capable of registering leakage rates from 150 litres per hour, meeting EU Methane Regulation Type 2 requirements for underground equipment
• Survey speeds of up to 180 km/h, enabling rapid coverage of large transmission and distribution networks within tight regulatory timeframes
• DVGW-approved methodology, giving operators confidence that results will be accepted by regulators and auditors
• Secure Web GIS delivery platform, providing accessible, actionable results on desktop and mobile so your teams can verify and act on gas indications without delay
• Proven European track record across 43 transmission system operators and regional distribution networks in 25 countries

If your organisation is working to meet LDAR obligations under EU Regulation 2024/1787 or looking to upgrade your pipeline inspection approach, we would be glad to discuss how CHARM® can support your programme. Get in touch with our team to find out more about what we can do for your network.