Air Quality

Coterra conducts annual benchmarking of the company’s atmospheric emission performance to identify opportunities and challenges relating to various emission sources. At the federal level, greenhouse gases (GHGs) are regulated under two programs: Title 40, Part 98, Subpart W of the Code of Federal Regulations (CFR), “Mandatory Greenhouse Gas Reporting,” which mandates annual reporting of GHGs for subject facilities, and 40 CFR Part 60 Subpart OOOOa, “Standards of Performance for Crude Oil and Natural Gas Facilities,” which imposes emission standards, operation standards and control requirements, as well as recordkeeping and reporting requirements for operations resulting in the emissions of both GHGs and volatile organic compounds (VOCs). While Subpart OOOOa regulates how Coterra conducts our operations to reduce emissions and impacts on the ambient air, Subpart W mandates specific procedures for data gathering, integrity review and calculation methodology for annual reporting. In addition to these federal programs¹, Coterra also implements internal processes and procedures to ensure our performance meets or exceeds requirements at all federal, state, and local regulatory levels.

Coterra’s commitment to operational excellence leads to the development of internal guidelines, processes and practices that comply with or exceed regulatory requirements. Coterra performs annual benchmarking of GHG emissions to identify opportunities for emission reduction. For oil and natural gas producers such as Coterra, the two key GHGs that make up the majority of our total emissions are carbon dioxide (CO₂) and methane (CH₄). The EPA and industry measure the impacts of GHGs in units of CO₂ equivalents (CO₂e), which is based on converting methane, nitrous oxides and fluorinated gases to CO₂ using global warming potential factors (GWP)².

The primary contributors to methane emissions are from the estimated methane venting during the pre-separation drill-out process of completion operations and natural gas venting associated with liquid unloading the operating of natural gas pneumatic bleed devices to control surface equipment, as well as the venting associated with liquids unloading. The primary contributor of carbon dioxide emissions is from combustion, such as the combustion of natural gas and diesel fuel to operate compressor stations, drilling rigs, generators and completions equipment. The comprehensive ongoing analysis of our emission profile enables us to track CO₂ and CH₄ emissions by each categorical source to identify equipment and/or emission sources with the most potential for emission reduction. Further, for Marcellus operations, within 180 days of plug drillout following well stimulation, all producing well sites are evaluated for compliance with state mandated emission criteria to demonstrate that they do not exceed exempt thresholds and thereby do not require an individual air permit for significant sources. 

In our efforts to identify and minimize CH₄ emissions, Coterra evaluates industry proven technologies and seeks to implement best management practices. The four categorical sources of methane emissions are:

Methane emissions are entrained in the circulating fluid as the liquid is recirculated to tanks from wellheads during completion operations. In 2019, Coterra strived to refine data accuracy by installing Lower Explosive Limit (LEL) detection monitors to track and record actual emission duration for its Marcellus operations in lieu of applying engineering estimates. These LEL detection monitors track and record actual emission duration during the flowback period from wellheads to facility separators which route nearly 100% of gas to sales. In Coterra’s non-Marcellus operations, vapors are combusted via onside safety flares until pipeline specifications are met, in which vapors are then safely routed to sales. Close monitoring of sales quality gas and associated flaring minimized methane emissions in the Permian and Anadarko basins.

Fugitive emissions are the unintended escape of gas through various components such as flanges, valves, connectors, and pressure relief valves. To help identify and minimize fugitive emissions, Coterra employs the use of optical gas imaging (OGI) cameras for leak-detection inspections on an ongoing basis, . Members of our team are trained and certified Thermographers from the Infrared Training Center. The training provides our operators with not only the operating techniques and basics of thermal science, but also an understanding of the regulatory framework, safety practices, camera techniques, and video image interpretive skills.

Coterra has implemented additional enhanced monitoring practices across its Permian Basin and Anadarko Basin operations. Permian Basin operations undergo semi-annual aerial inspections performed by fixed-wing aircrafts. Coterra has also deployed three centralized, real-time laser monitoring systems across its Permian and Anadarko assets, which provide 24/7 monitoring and detection of emissions.

As part of Coterra’s commitment to support practical and sustainable environmental programs, we are an original member and supporter of API’s “The Environmental Partnership” program launched in December 2017. We participate with a group of our industry’s largest companies to reduce methane and volatile organic compounds (VOCs) in our operations through the sharing of best practices and implementing innovative strategies. Coterra is excited to be an original member of The Environmental Partnership and we look forward to the continued growth in its membership and the resulting benefits for Coterra and all our stakeholders.

Coterra also participates in the EPA Natural Gas STAR program. The Natural Gas STAR program is a voluntary program that encourages oil and natural gas companies to adopt proven, cost-effective technologies and practices that improve operational efficiencies and reduce methane emissions to the atmosphere.