British Columbia’s 2025 Methane Regulations: What Oil & Gas Operators Need to Know

In a landmark effort to protect people and communities from the effects of climate change and reduce GHG emissions, the British Columbia Energy Regulator has announced significant amendments to its Drilling and Production Regulation. These changes, set to take effect on January 1, 2025, emphasize reducing methane emissions for oil and gas operators to improve leak detection systems and enhance overall environmental sustainability in the province.

Below, we explore notable amendments to these new regulations and provide proactive strategies for oil & gas operators to achieve compliance.

Stricter Controls on Natural Gas Venting from Drilling and Production Operations

The new regulations focus on curbing natural gas venting, a key source of methane emissions. Venting during activities such as well liquids unloading and surface casing vent flows is now subject to tighter restrictions.

• Venting Limits During Well Liquids Unloading: Operators are required to maintain records detailing the dates, location, and volume of natural gas vented during well liquids unloading. These records must also demonstrate measures taken to minimize venting.
• Surface Casing Vent Emissions: Beginning January 1, 2026, operators will need to ensure that emissions from surface casing vents do not exceed three cubic meters of natural gas per day. Natural gas venting during well operations or surface casing leaks will also be more strictly controlled, with advanced notification required for vent flow control measures.
• Compressor Seal Venting: Beginning January 1, 2025, operators who use a fleet of reciprocating compressors must ensure that the venting of seal gas from each throw does not exceed 3 m3 per hour and the average vent gas rate for the fleet for each calendar year does not exceed 0.3 m3 per hour per throw.

Enhanced Leak Detection and Repair (LDAR) Programs

The new regulations introduce stricter leak detection and repair standards, acknowledging that leaks, particularly methane, can majorly contribute to GHG emissions.

• Increased Inspection Frequency: Starting in 2025, gas processing plants, compressor stations, batteries other than a satellite battery, processing batteries, natural gas liquid fractionation facilities, and compressor dehydrator facilities that are pressurized for more than 244 days in the calendar require four (4) comprehensive surveys per year.
• Active Well Site Inspection Frequency: Beginning January 1, 2030, a well permit holder of an active well, other than a water source well, a water injection well, or a water disposal well, that is pressurized for 91 days or more in a calendar year must carry out at least one comprehensive survey of the well per calendar year.
• Inactive wells: Starting in 2025, the well permit holder of an inactive well other than a water source well, a water injection well, or a water disposal well must carry out at least one screening survey of the well per calendar year.
• Introduction of Alternative LDAR Programs: Companies can now apply for approval of customized LDAR programs that use alternative detection technologies, provided they can demonstrate equal or better methane emissions reduction compared to standard LDAR practices.
• Fixed Leak Monitoring Devices: Starting in 2028, facilities will be required to install fixed leak detection devices to monitor emissions from tanks, pressure relief devices, and other sources prone to leaks. The data from these devices will help operators quickly identify and address leaks, further reducing fugitive emissions.

These enhancements reflect the increasing sophistication and reliance on technology for real-time monitoring of methane emissions, ensuring faster response times and more effective leak management.

Transition Away from Pneumatic Devices and Compressors that Vent Methane

Pneumatic devices and compressors used in oil and gas operations are traditionally known for venting natural gas, particularly methane, during their operations. The new regulations take a phased approach to eliminating this practice.

• Pneumatic Devices: By 2035, pneumatic devices that vent natural gas will be prohibited unless they meet stringent requirements. Beginning in 2028, any facility modifications will trigger compliance with new venting standards, significantly limiting methane emissions from these devices.
• Compressors: Similar provisions apply to compressors. The plan is to phase out methane venting by 2035. In 2025, new facilities and major modifications must implement technology to prevent natural gas venting from compressor seals.

So, what does this mean for Oil & Gas operators?

The updated regulations mark a critical step forward for British Columbia’s energy industry in its efforts to reduce methane emissions and mitigate climate change. For oil and gas operators, these amendments mean significant changes in managing emissions, monitoring leaks, and maintaining equipment.

With the 2025 deadline fast approaching, operators must begin preparations now to ensure they are ready to meet the new standards. In doing so, they will play a key role in reducing one of the most potent greenhouse gases—methane—from the atmosphere.

Key Dates to Remember:

• January 1, 2025: Changes to site inspection frequencies
• January 1, 2025: New pneumatic devices and venting standards occur.
• January 1, 2026: Limit on surface casing vent emissions begins.
• January 1, 2028: Facilities must install fixed leak monitoring devices.
• January 1, 2035: Full phase-out of pneumatic devices and compressors that vent natural gas.

Proactive Strategies for Oil & Gas Operators

To help oil and gas operators adapt to new standards effectively, it is advisable to implement advanced leak management strategies that accurately identify and mitigate leaks, thereby reducing emissions and operational risks. Emphasizing equipment optimization and predictive maintenance enhances reliability, prevents failures, and prolongs asset life. Operators should consider adopting scalable technology that can be customized for individual sites or expanded across multiple locations. Streamlining data collection and compliance reporting facilitates adherence to regulatory requirements while improving transparency. Additionally, fostering collaboration across teams is essential for effectively executing emissions management strategies, ensuring all stakeholders are equipped with actionable insights.

Prepare Your Operations for BC’s 2025 Methane Regulations

With significant changes on the horizon, now is the time to evaluate your operations, upgrade your systems, and align your strategies with British Columbia’s new methane reduction standards. By taking proactive steps, you can ensure compliance, enhance environmental performance, and stay ahead of regulatory requirements.

Explore how these changes could impact your operations and discover actionable insights to prepare for the 2025 deadline.

Contact Us to Learn More and Take Action Today