Key Takeaways
- Methane oversight increased in 2025: The British Columbia Energy Regulator requires more frequent leak detection surveys and stricter controls on venting
- Technology has become essential: Operators must deploy advanced leak detection, monitoring devices and low-emission equipment to meet new standards
- Preparation reduces risk: Companies that upgrade systems avoid operational disruption and compliance pressure as regulations evolve
Oil & gas represents nearly 20-25% of methane emissions globally. A sizable portion of that comes through venting, equipment leaks and pneumatic devices. Given the attention methane garners as a potent greenhouse gas, British Columbia has introduced key updates that change how operators must manage methane.
To ensure you stay ahead of this regulation and build a future-proofed strategy we’ve put together the following overview.
British Columbia moves to cut methane emissions from oil and gas operations
The British Columbia Energy Regulator (BCER) introduced major amendments to the Drilling and Production Regulation. These updates took effect January 1, 2025, and targeted the largest operational sources of methane emissions.
The changes focus on three areas: Reducing natural gas venting, increasing leak detection and monitoring and phasing out equipment that vents methane.
Together, these changes introduce new operational expectations for oil and gas operators. Companies must strengthen emissions management practices, improve monitoring capabilities and plan for long-term equipment upgrades.
Meeting these requirements will require coordination beyond environmental compliance teams. Environmental Health and Safety (EHS) and compliance leaders must work closely with operations, engineering and asset management teams to implement effective emissions management strategies. Providing clear emissions data and operational context will help frontline teams make informed decisions and maintain compliance.
Venting limits tighten across drilling and production operations
The updated rules placed restrictions on natural gas venting during routine operations. Key requirements include:
Stronger documentation for venting events: Operators must record the date, location and volume of gas vented during well liquids unloading. Records must show actions taken to minimize venting.
Surface casing vent limits: Starting January 1, 2026, emissions from surface casing vents cannot exceed three cubic meters of natural gas per day.
Compressor seal venting limits: As of January 1, 2025, reciprocating compressors must limit venting to 3 m³ per hour per throw and 0.3 m³ per hour per throw annual fleet average.
These requirements increase accountability and push operators to deploy technologies that capture or reduce vented gas.
Leak detection programs become more frequent and technology-driven
The new regulations significantly expand leak detection and repair (LDAR) requirements.
More frequent inspections
Starting in 2025, several facility types must complete four comprehensive leak detection surveys per year, including gas processing plants, compressor stations, batteries other than satellite batteries, natural gas liquid fractionation facilities and compressor dehydrator facilities operating more than 244 days per year.
Additional requirements include screening surveys for inactive wells starting in 2025 and active wells beginning in 2030.
New monitoring technology
Facilities must install fixed leak monitoring devices by January 1, 2028. Operators may apply for alternative LDAR programs using advanced detection technologies if they demonstrate equal or greater emissions reductions.
These provisions reflect a broader industry shift toward continuous emissions monitoring and real-time detection systems.
Methane-venting equipment faces a long-term phaseout
The regulations also target methane emissions from pneumatic devices and compressors, two common sources of vented gas.
The province will phase out these emissions over the next decade:
These timelines give operators time to modernize equipment while pushing the industry toward lower-emission infrastructure.
What oil and gas operators should do now
The regulatory timeline is already underway.
Operators should prioritize:
- Advanced leak detection strategies that scale across multiple facilities, such as a continuous methane monitoring system (CEMS), to identify and repair emissions quickly
- Equipment optimization and predictive maintenance to prevent failures and extend asset life
- Streamlined emissions data and reporting systems to support regulatory compliance
- Cross-team coordination between operations, environmental and compliance teams
These actions reduce compliance risk while improving operational visibility and environmental performance.
Act early to stay ahead of BC’s methane rules
Across the globe, both regulations and stakeholder expectations are trending toward stricter emissions oversight as technology progresses. Operators that act early reduce regulatory risk, strengthen environmental performance and improve operational efficiency.
A future-proofed strategy is not tied to any one technology. It is about finding the right mix that compliments your asset portfolio, processes and people. If you want to take the next step toward building a robust methane management strategy built to withstand regulatory change, book a strategy call today.
