Leak detection
As regulatory scrutiny and public pressure intensify, oil and gas operators are being asked to do more than ever to detect and prevent fugitive methane emissions.
At the heart of most compliance regimes sits an acronym familiar to most operators: LDAR, or leak detection and repair.
But as new technologies flood the market and regulators revise their expectations, a fundamental question is emerging.
As currently implemented, are LDAR programmes fit for purpose?
For over a decade, optical gas imaging (OGI) cameras have been the cornerstone of LDAR programmes.
These infrared devices, using either cooled or uncooled sensors, make hydrocarbon plumes visible to technicians scanning valves, flanges, compressors and storage vessels.
But this method comes with key limitations.
OGI is a qualitative tool. It can show that a leak exists but it cannot determine the leak’s volume.
This makes it difficult to prioritise repairs or report emissions accurately.
The process is also labour-intensive, dependent on manual site visits that are vulnerable to human error and weather conditions.
Most critically, OGI is blind to intermittent leaks that occur between inspections — a major blind spot in methane management.
Nonetheless, many regulatory frameworks, including the US EPA’s NSPS OOOOa and Canada’s SOR/2018-66, have long treated OGI-led LDAR as sufficient.
That stance is changing.
Recent methane super-emitter incidents, such as large flaring events in the Permian Basin or blowouts at storage terminals, have prompted regulators to raise the bar.
The updated US EPA methane regulations, finalised in 2024, now require more comprehensive, tiered approaches.
Quarterly OGI or instrument-based inspections for high-bleed components, continuous monitoring for high-priority sites, and stronger requirements for quantification and repair tracking.
In response, operators are turning to hybrid LDAR strategies.
These combine OGI for source localisation with fixed sensors for continuous detection of background anomalies across a facility.
Drones equipped with LiDAR or TDLAS systems are increasingly used for site-wide screening, especially in hard-to-access or high-risk zones.
Smart analytics platforms now tie these systems together, flagging leaks automatically, ranking them by severity, and generating work orders for rapid intervention.
This shift is also reshaping the instrumentation landscape.
Facilities are trialling open-path laser sensors, which can detect methane plumes across downwind corridors, offering early-warning capabilities.
Point sensors using MEMS or NDIR technologies are being paired with AI algorithms that filter out false positives caused by wind or humidity.
Miniaturised spectrometers mounted on UAVs are enabling precise leak localisation, even in partially covered sites such as tank farms and compressor stations.
Despite these innovations, technical hurdles remain.
False positives and negatives caused by ambient methane or cross-interference from ethane still challenge sensor reliability.
Power supply and communication links in remote or ATEX-classified zones can be unstable.
And many facilities face data integration bottlenecks when trying to connect new sensor platforms with legacy SCADA or maintenance systems.
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For facility managers, investing in next-generation LDAR is no longer just about meeting the minimum requirements.
Reputational risk, investor expectations, and even insurance terms increasingly hinge on methane performance.
Public reporting frameworks like OGMP 2.0 and CDP demand granular, auditable data.
As a result, instrumentation decisions are being driven by questions around where continuous monitoring is justified, how quantification can be verified, and whether detection systems can feed directly into digital maintenance workflows for faster repair and documentation.
Calling current LDAR programmes a failure may go too far but many are clearly outdated.
OGI-only regimes are increasingly viewed as reactive, patchy, and inefficient.
As methane monitoring evolves into a matter of compliance, credibility, and competitiveness, LDAR must move beyond its box-ticking origins. It must become a data-rich, risk-informed system with built-in mechanisms for continuous improvement.
Instrumentation vendors, service providers, and facilities now share a common imperative: to build LDAR systems that integrate detection, quantification, and response. And to prove they work reliably in real-world conditions.
The age of annual inspections and thermal cameras is ending.
Methane detection is becoming continuous, quantified, and digitised.
Operators who treat LDAR as a living system, underpinned by smart instrumentation and real-time insight, will be the ones who stay compliant, stay ahead, and stay trusted.
IET 36.3 May
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