GHG Monitoring: Methods and Importance for Emission Reduction

In the US, GHG reporting is mandatory for many upstream oil & gas operators under EPA's Greenhouse Gas Reporting Program and the methane rule (40 CFR Part 60 Subpart OOOOb). Publicly traded producers also face SASB and TCFD disclosure expectations, and several states require emissions inventory submissions for continuous-monitoring pathways.

No. CO2 is one of several greenhouse gases, not a synonym for GHG. Methane (CH4) is the primary focus of upstream oil & gas monitoring because it is the main component of natural gas and the gas targeted by EPA Subpart OOOOb and OGMP 2.0 reporting requirements, which is why continuous fugitive methane detection is prioritized.

Upstream methane and VOC emissions are measured using Optical Gas Imaging with Long-Wave Infrared cameras, which visualize gas plumes for AI-based volumetric quantification. This is combined with acoustic and video sensor fusion to validate true fugitive events before quantifying leak rate, duration, and volume for regulatory-defensible reporting.

Continuous multi-sensor monitoring captures emission events as they occur rather than relying on a single quarterly snapshot, producing defensible-accuracy data suitable for EPA and state-agency submissions. This approach also defines leak duration and volume, information quarterly LDAR inspections cannot provide.

Field installation, commissioning, and AI Site Learning kickoff typically take approximately 2 days per site to establish a normal operational baseline. The system then relearns automatically if site configuration changes, minimizing false alarms once fully operational.

Yes. Multi-sensor GHG monitoring platforms typically offer SCADA integration through a published, read-only API, allowing emissions and alert data to flow into existing operator dashboards and historian systems without compromising cybersecurity standards.