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1 [1] (February 13, 2025)

handle is hein.crs/govesmj0001 and id is 1 raw text is: Cogesoa Reeac Service U Updated February 13, 2025 Advances in Satellite Methane Emissions Measurement This In Focus discusses the role of evolving satellite technologies, their ability to monitor methane and identify large-scale emissions events, and how data from these detection technologies fit into federal methane rules and programs. Interest in detecting methane and observing and locating emissions events stems in large part from efforts to reduce the release of greenhouse gases (GHGs). In particular, advances in remote sensing of methane from satellites may improve monitoring and detection of methane emissions from oil, coal, and natural gas operations. Congress may consider the use of satellite methane emissions information in U.S. programs. Background on Methane Emissions Methane has a global warming potential 27-30 times greater than carbon dioxide over a 100-year period. It is second only to carbon dioxide in contributions to global temperature increases from human emissions of GHGs. Fossil-fuel-related industries are among the sectors that emit methane into the atmosphere. Some stakeholders support reducing methane emissions as part of efforts to mitigate climate change and to improve public health. Regulation of methane emissions has been opposed by other stakeholders for reasons of cost, among others. Fugitive emissions are generally described as unintended leaks from pressure containment systems, which can include leaks from valves or flanges, in fossil fuel facilities. Fugitive emissions also include methane that escapes to the atmosphere from incomplete combustion during flaring (the burning of excess gas). Regulatory and Policy Context Under the authority of Section 111 of the Clean Air Act (CAA), the U.S. Environmental Protection Agency (EPA) promulgated more stringent standards for methane emissions from oil and natural gas facilities. Specifically, it published a rule that finalized revisions to the new source performance standards (NSPS) and emission guidelines (EG). The rule requires states to submit and implement plans to establish performance standards that limit GHG emissions from existing oil and natural gas facilities (89 Federal Register 16820, March 8, 2024). One set of actions in the 2024 rule is lessening fugitive emissions by constraining them from large emissions sources known as super-emitters. The rule established standards for methane release events greater than 100 kilograms per hour, known as super-emitter events. The rule also established the Methane Super Emitter Program to allow certified third parties to submit data on methane release events to the EPA Super Emitter Portal (as defined in the final rule). Under this program, certified third-party submitters may only use EPA-approved technology, which includes (1) satellite detection of methane emissions, (2) remote-sensing equipment located on aircraft, or (3) mobile monitoring platforms. This rule adds to previous actions on methane emissions. In accordance with CAA Section 111, the Crude Oil and Natural Gas source category was first listed as a source category subject to performance standards in 1979. EPA's 2016 rule expanded the emission sources covered by the 2012 rule and added performance standards for methane emissions. Satellite measurement of methane emissions can contribute to meeting U.S. treaty obligations under the United Nations Framework Convention on Climate Change (UNFCCC). This includes an annual Greenhouse Gas Inventory that includes methane. On January 20, 2025, President Trump issued an executive order directing the withdrawal of the United States from agreements under the UNFCCC. Methane Emissions Estimation Methods Comprehensive measurement and estimation of methane emissions is difficult, and the measurement technologies continue to evolve. Methane emissions estimation methods are often placed in two general categories. One type of methods, sometimes referred to as bottom up (BU), extrapolates measurements from individual natural gas facility components to estimate total emissions for industrial facilities. BU methods rely on averaging numerous leak test measurements of these components to develop emissions factors. These emissions factors are used to estimate emissions for facilities based on the number and types of components and the levels of production. However, because emissions factors are based primarily on leakage measured under normal conditions, they may not fully account for super-emitter events and may understate total emissions. The second type of methods, referred to as top down (TD), provide empirical measurements of methane at specific locations, rather than estimates based on emissions factors. They use either ground-based instruments or those on aircraft or satellites to estimate methane emissions. The downsides of TD are its relative cost and coverage limitations. At present, satellite- and aircraft-based measurements cost more than the BU strategy described above. Also, some TD methods (e.g., orbiting satellites) typically occur at infrequent intervals and may miss detection of sporadic emissions events. As remote detection technologies mature, costs may drop. Increasing satellite sampling frequency offers an opportunity to improve accuracy and precision. Satellite Measurement of Emissions Remote measurement of methane using satellite-based sensors typically detects the abundance of methane by measuring the methane-specific pattern of light absorption. Since the launch of the Greenhouse Gases Observing https://crsreport

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