Canada is changing how upstream oil and gas facilities detect and manage methane emissions. Beginning January 1, 2028, key provisions of the federal SOR/2025-280 amendments will take effect, strengthening leak detection and repair (LDAR) requirements while introducing an alternative, performance-based pathway built around continuous emissions monitoring. 

For operators, this creates an important decision: continue with a traditional LDAR approach that requires regular inspections and repairs (Part 1), or evaluate continuous emissions monitoring under Part 2.

What’s changing for LDAR?

The amended regulations strengthen Canada’s requirements for detecting fugitive emissions. Under Part 1, a Type 1 facility must undergo a comprehensive inspection once each quarter, while a Type 2 facility generally requires a comprehensive inspection once per calendar year. The regulations specifically identify a qualifying optical gas-imaging instrument as one of the technologies that can be used to conduct comprehensive inspections. 

This makes Optical Gas Imaging (OGI) particularly relevant for operators preparing their LDAR strategies. Rather than simply detecting the presence of gas at a single measurement point, OGI allows emissions to be visualized, helping operators locate their source and understand the surrounding equipment and operating conditions.

The regulations also introduce requirements for screening inspections and establish repair timelines based on emission rates, increasing the emphasis on both detecting emissions and addressing them in a timely manner. 

A second pathway: continuous monitoring

One of the most significant changes is Part 2, which establishes an optional performance-based compliance pathway using an emission monitoring system. The federal regulatory analysis describes this approach as focusing on emissions outcomes rather than prescribing a specific compliance action. Facilities choosing Part 2 are required to notify the Minister and must satisfy applicable facility-emission-intensity requirements.

Continuous monitoring also goes beyond simply generating an alarm. Under the regulation, an emission monitoring system must operate at all times except during preventive maintenance. For Type 1 facilities, sensors must take readings at least every 15 minutes, and the system must generate an alert when detected emissions exceed the facility emission rate by 1 kg/h or more. 

That shift from periodic observation toward continuous awareness can change how operators approach emissions management.

Where does OGI fit?

OGI can support both periodic LDAR inspections and continuous monitoring strategies. For inspections, it provides a way to visualize otherwise invisible hydrocarbon gas emissions. In a continuous monitoring solution, fixed OGI technology can provide persistent visual information about an emissions event.

For operators exploring that continuous approach, FLIR ADGiLE™ combines OGI technology, intelligent analytics and remote access to provide continuous visibility into emissions events, helping teams move beyond an alert to better understand what is happening. 

Download the white paper to explore Canada’s changing LDAR requirements and the role OGI and continuous monitoring can play in preparing for 2028.

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References

Government of Canada, Canada Gazette. SOR/2025-280: Regulations Amending the Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds 
Environment and Climate Change Canada. CEPA Registry: SOR/2025-280 
Department of Justice Canada. Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds