In short: Reducing methane emissions has moved from a voluntary reporting exercise to a hard regulatory expectation, and the measurement standard has shifted from periodic surveys to continuous monitoring. Continuous monitoring means dozens of fixed sensors, mobile detection units and connected workers all streaming data across sprawling, often elderly terminal sites — and that is a connectivity problem before it is anything else. Private 5G is the layer that makes always-on methane detection workable at sites like St Fergus, Bacton and Mossmorran.
Key Takeaways
- The standard has moved from quarterly surveys to continuous monitoring — OGMP 2.0 Level 5 reporting and the NSTA's zero-routine-flaring-by-2030 target reward measurement that never stops, not an annual walk-round with a sniffer
- Continuous detection is a dense sensor problem — fixed optical-gas-imaging cameras, point sensors, drones and connected workers across a square kilometre of process plant generate far more data than a legacy terminal network can carry
- Private 5G turns detection into action — sub-second alerting from sensor to control room, located to the specific flange or valve, is the difference between a leak caught in minutes and one found at the next survey
In a nutshell
Methane stopped being a footnote
For most of the North Sea's productive life, methane emissions were treated as an unavoidable by-product of producing and processing gas — flared, vented, or leaked from fittings, and reported, if at all, on the basis of generic emission factors rather than measurement. That position is no longer tenable. Methane is roughly eighty times more potent than carbon dioxide as a greenhouse gas over a twenty-year horizon, and it has become the single most scrutinised number in the upstream and midstream sector.
In the UK, the regulatory and reporting pressure now comes from several directions at once. The North Sea Transition Authority (NSTA) has set an expectation of zero routine flaring and venting by 2030, with operators required to justify and licence any flaring that does occur. Internationally, the Oil and Gas Methane Partnership 2.0 (OGMP 2.0) sets a five-level reporting framework, where the highest levels — Level 4 and Level 5 — require operators to move from estimated, factor-based numbers to source-level measurement reconciled against site-level measurement. The European Union's methane regulation, which reaches UK gas exports through the import provisions, adds a further measurement-and-reporting obligation that will bite over the coming years.
The common thread is measurement. It is no longer enough to estimate emissions from a spreadsheet of components; operators are expected to measure what is actually leaking, where, and for how long. That is a fundamentally different exercise from the annual leak-detection-and-repair (LDAR) survey, and it is one that the existing terminal infrastructure was never built to support.
Why the old survey model falls short
The traditional LDAR model is a person with an optical gas imaging (OGI) camera or a flame-ionisation detector walking a defined route around the plant, typically once or twice a year, photographing each component and logging any leaks for repair. It works, in the sense that it finds leaks, but it has two structural weaknesses that the new standards expose.
Firstly, it is a snapshot. A flange that begins weeping the day after the annual survey can leak for the best part of a year before anyone notices. Studies of measured emissions consistently find that a small number of large, intermittent "super-emitter" events dominate the total — and these are precisely the events a periodic survey is most likely to miss, because they may not be happening on the day the surveyor walks past.
Secondly, it is labour-bound and therefore expensive to scale. Increasing survey frequency means proportionally more skilled surveyor time, and the marginal cost rises faster than the marginal benefit. You cannot get to continuous coverage by simply doing the annual survey more often.
Continuous monitoring inverts the model. Instead of one mobile sensor visiting every point occasionally, you fix many sensors in place and let them watch continuously, supplemented by mobile and aerial sweeps for the gaps. That changes the economics in the right direction — but it creates a connectivity requirement that the terminals do not currently meet.
A square kilometre of process plant, and no network
UK gas reception and processing terminals are large, dispersed, hazardous sites. St Fergus in Aberdeenshire takes gas from multiple North Sea fields. Bacton on the Norfolk coast is a national gas hub and a likely anchor for future hydrogen and carbon-capture work. Mossmorran in Fife processes natural gas liquids. These are not compact facilities — process units, storage, flare stacks, jetties and pipeline reception areas can be spread across a square kilometre or more, much of it in hazardous (ATEX/DSEAR) zones where equipment must be intrinsically safe.
Connectivity across these sites has historically been a patchwork: wired SCADA to the fixed process instrumentation, some Wi-Fi around the control building and workshops, two-way radio for the operators, and not much else outdoors. Public mobile coverage at a remote coastal terminal is often marginal. None of this is adequate for a continuous-monitoring deployment that wants to place a fixed sensor on every significant emission source and have it report reliably, in real time, from anywhere on the plot.
Wi-Fi struggles here for the reasons it struggles in most heavy-industrial outdoor settings: range is short, coverage across a large open site needs an impractical number of access points and backhaul runs, and the unlicensed band is congested and uncontrolled. Running fresh fibre and conduit to hundreds of new sensor positions across a live, hazardous, decades-old terminal is slow and eye-wateringly expensive — every cable route through a hazardous zone is an engineering project in its own right.
This is the gap a private 5G network fills. A single managed network, planned to cover the whole plot with a handful of carefully sited radios, gives every fixed sensor, mobile detector, drone and connected worker a reliable, secure, real-time path back to the control room — without trenching a cable to each one.
What continuous detection actually looks like on private 5G
A modern continuous-monitoring deployment is a layered system, and each layer wants the network.
The base layer is fixed point sensors and optical gas imaging cameras positioned at the highest-risk sources — compressor seals, large flanges, relief valves, loading arms. Continuous OGI cameras in particular generate meaningful video data, and their value depends on getting that data to an analytics engine quickly enough to alert while the leak is still happening. A point sensor reporting a few bytes a second is trivial; fifty OGI cameras streaming for anomaly detection is not, and that aggregate load is exactly what a private 5G cell is built to carry.
The second layer is mobility. Drones flying programmed sweeps with methane-sensing payloads can cover the areas fixed sensors miss, and they need a wireless uplink for both control and the sensor feed. Vehicle-mounted detectors doing perimeter and inter-unit runs do the same. Both depend on continuous coverage across the whole site rather than islands of Wi-Fi.
The third layer is people. The connected worker — a technician with a personal gas monitor, a tablet showing the live emissions map, and a body-worn camera for remote expert support — is now central to both safety and emissions work. When a sensor flags a source, the nearest technician can be routed to it, see the history, and confirm and repair the leak, all on the same network. Lone-worker safety and gas-detection alerting ride the same infrastructure.
Tying it together is location. The point of continuous monitoring under OGMP 2.0 is source-level attribution — not "the site emitted X" but "this specific component emitted X for this period". That requires every alert to carry a precise location and a chain back to the asset register. A deterministic, low-latency network makes that real-time correlation possible; a best-effort one does not.
The economics: caught in minutes, not at the next survey
The case for the investment rests on a straightforward proposition: a leak found in minutes costs far less than the same leak found at the next survey. The cost shows up in three ways.
The most direct is product. Vented and leaked methane is saleable gas going to atmosphere. At a large terminal, sustained leaks and avoidable flaring add up to a material volume of lost product over a year — gas the operator has paid to produce and process and then loses for nothing.
The second is regulatory and reputational. Under the NSTA regime, flaring and venting must be justified and consented; persistent unexplained emissions are a licensing risk. Under OGMP 2.0 and the EU import rules, the quality of an operator's reported numbers increasingly affects market access and the gold-standard reporting status that buyers and investors look for. Demonstrably continuous, measured monitoring is what underpins a credible Level 5 report.
The third is the carbon price. As emissions are progressively brought inside carbon pricing and border-adjustment mechanisms, every tonne of methane not lost is a cost avoided — and that calculus only gets stronger over the asset's remaining life.
Against those returns, the cost of a private 5G layer is modest and, importantly, it is reusable. The same network that carries methane detection also carries the connected-worker safety systems, the drone inspections, the predictive-maintenance sensors on rotating equipment, and the digital-twin data feeds. It is infrastructure, not a single-purpose gadget.
Built for what these terminals become next
There is a longer-term reason to put a proper network into these sites now: most of them are not winding down, they are being repurposed. Bacton is positioned for hydrogen and carbon capture. St Fergus sits at the landfall for the Acorn CCS project. The terminals that today process North Sea gas are, in many cases, the industrial anchors for the energy transition's next phase — and hydrogen production, CO2 reception and the associated monitoring obligations will only intensify the demand for dense, reliable, real-time connectivity across the plot.
Ultimately however, the immediate driver is simpler and already here. The measurement bar has been raised, the survey-once-a-year model cannot meet it, and continuous monitoring is unworkable without a network that can carry it. Private 5G is not the headline of a methane programme — the sensors and the analytics are — but it is the layer without which the rest does not function. We see it as the quiet enabler: the thing that turns a wall of detectors into a control room that knows, within seconds, exactly which valve to send someone to close.