Shift Toward State-Level Regulation and Market Fragmentation
In a scenario where the EPA's role is diminished, state governments would likely become the primary drivers of emissions policy in the power sector. States like California, New York, and Washington already have comprehensive climate policies and emissions reduction mandates. Regional initiatives, such as the Regional Greenhouse Gas Initiative (RGGI), could also gain importance.
This transition to state-led regulation would create a patchwork of rules across the country. For utilities and businesses operating in multiple jurisdictions, this increases complexity. They would need to navigate varying emissions limits, reporting standards, and compliance costs. This regulatory fragmentation could challenge efforts to maintain consistent energy and sustainability strategies across a national footprint.
Corporate energy procurement teams may need to reevaluate their approaches based on regional emissions factors and incentive programs. Additionally, Independent System Operators (ISOs) and Regional Transmission Organizations (RTOs) may play a larger role in grid planning and emissions forecasting, filling in some of the oversight gap left by the federal government.
Implications for Scope 2 Emissions and Corporate Energy Strategy
Scope 2 emissions, defined as indirect emissions from purchased electricity, are directly influenced by the carbon intensity of the grid. A revocation of the Endangerment Finding could alter the pace and direction of grid decarbonization. This would impact location-based Scope 2 emissions accounting, which depends on average grid emissions in a given region.
In the absence of federal emissions regulations, utilities may adjust their investment strategies. Some may continue with decarbonization plans due to state requirements or shareholder expectations, while others may slow or reverse their clean energy transitions. As a result, corporate buyers may face more uncertainty about future emissions factors and electricity pricing.
To mitigate these risks, businesses may need to rely more heavily on market-based mechanisms, such as renewable energy certificates (RECs), power purchase agreements (PPAs), and utility green tariff programs. These tools allow companies to assert more control over their electricity emissions profile, regardless of regional grid trends.
Transparency and data access will also be crucial. Companies should monitor Integrated Resource Plans (IRPs), emissions forecasts from ISOs and RTOs, and utility decarbonization commitments to stay informed about changes in grid composition. According to the U.S. Department of Energy, utilities are increasingly incorporating decarbonization and clean energy targets into their IRPs, reflecting both state policy drivers and rising customer demand for low-carbon electricity. These signals can guide energy sourcing decisions and help maintain credible Scope 2 reduction pathways.
Conclusion
The potential revocation of the Endangerment Finding would represent a significant shift in federal climate policy, especially regarding power sector emissions. Without EPA oversight, the regulatory landscape would likely become more fragmented and state-driven. For utilities and corporate energy buyers, this would increase the complexity of compliance, planning, and emissions management.
Scope 2 emissions strategies may become more reliant on voluntary and market-based instruments as companies seek to maintain progress in a less regulated environment. Tracking grid emissions trends, utility investment plans, and regional policy developments will be essential.
As federal authority over carbon regulation becomes uncertain, stakeholders across the power sector will need to adapt. Flexibility, vigilance, and a strong understanding of regional energy dynamics will be key to navigating this evolving landscape.
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