The U.S. Environmental Protection Agency (EPA) issued new guidance on July 1, 2026, granting power plant developers and industrial facility operators significantly more flexibility in how they manage emissions offsets for new projects. This policy shift allows the issuance of a Nonattainment New Source Review (NNSR) permit before a developer has specifically identified or secured the required emission reduction credits, provided the permit carries a strict prohibition against commencing operations until those offsets are fully in place.
By moving the requirement to finalize emissions credits from the pre-permitting phase to the pre-operational phase, the agency is effectively unblocking early-stage construction for major energy infrastructure. This technical adjustment targets projects located in “nonattainment” areas—geographic regions that currently fail to meet National Ambient Air Quality Standards (NAAQS) for specific pollutants like ozone or nitrogen oxides. While the underlying legal obligation to offset new pollution remains intact, the timing change offers critical breathing room for engineers and developers.
The decision arrives at a pivotal moment for the American power sector, which is currently grappling with a surge in electricity demand driven by industrial electrification and data centre expansion. For developers of gas-fired generation and large-scale manufacturing facilities, the guidance addresses a long-standing “chicken-and-egg” problem: the difficulty of purchasing expensive emissions credits before having a guaranteed construction permit in hand.
How the EPA guidance affects power project emissions offsets and permitting
The core of the July 1 guidance lies in the reinterpretation of the Clean Air Act (CAA) regarding the “enforceability” of pollution controls. Previously, the EPA generally favoured a sequence where developers had to quantify and secure their emissions credits before a state or local authority would grant them an NNSR permit. This requirement often acted as an expensive gatekeeper, forcing companies to sink millions of dollars into credits for a project that might still face other regulatory hurdles.
The new memorandum clarifies that the CAA does not mandate this level of specificity at the time of permit issuance. Instead, a federally enforceable commitment to obtain the necessary credits before startup, paired with an explicit permit condition barring operations until they are secured, is sufficient to satisfy the law. This creates a parallel path where physical construction and credit procurement can happen simultaneously.
Senior project engineer Robynn Andracsek, PE, of T. Baker Smith, described the move as a common-sense policy shift that reduces bureaucracy without removing any Clean Air Act protections. For engineering firms, this change allows manufacturers to pivot to more agile management systems by decoupling permit issuance from immediate credit acquisition, allowing capital-intensive projects to break ground sooner while credits are still being arranged.
Technical requirements of Nonattainment New Source Review
New or modified major stationary sources in nonattainment areas must follow two primary tracks. First, they must implement the Lowest Achievable Emission Rate (LAER), representing the most stringent control technology found in practice. Second, for every ton of pollutant the plant emits, it must find a corresponding reduction from an existing source in the same area to ensure no net increase in pollution.
Finding these offsets often involves securing credits from shuttered factories or paying existing facilities to install advanced scrubbers. Because these credits are finite and locally restricted, tying a construction permit to an immediate purchase can stifle industrial growth. This shift is particularly relevant as the African IoT sector and global industrial connectivity demand larger, more reliable power footprints for facility expansions.
Phased construction and the benefit for modular energy projects
The EPA memorandum also clarifies rules for projects built in multiple phases. Large-scale power developments, particularly those involving several gas turbines or large-scale onsite power arrays, are rarely built all at once. The agency stated that permit applicants do not necessarily have to secure offsets for an entire phased facility upfront. Instead, a permit could require sufficient credits before each individual phase begins operating.
This provision is critical for multi-phase generation and onsite power projects designed to bring capacity online incrementally. It allows developers to scale their environmental obligations alongside their physical infrastructure. By aligning environmental compliance with the actual start of operations for each phase, the EPA reduces the upfront financial risk that has historically sunk large-scale energy projects in heavily regulated air basins.
Such modular flexibility enables companies to manage capital more effectively. For instance, as the cobot market expands and industrial automation requires precise power scaling, developers can now ensure their environmental permitting matches their phased rollout of automated production lines.
Regulatory context and the ongoing debate over Clean Air Act enforcement
This guidance operates within a volatile regulatory landscape. In May 2024, the EPA finalized a suite of rules targeting carbon, mercury, and wastewater from power plants. Under these rules, all new baseload natural gas plants must reduce carbon emissions by 90% by 2032. Furthermore, new natural gas plants must meet a 90% capture standard starting in 2035 or operate below a 40% capacity factor.
The current EPA leadership has proposed significant reversals to these policies. Administrator Lee Zeldin announced proposals on June 11, 2025, to repeal all greenhouse gas emissions standards for the power sector under Section 111 of the Clean Air Act. Zeldin stated that affordable, reliable electricity is a “natural byproduct of national energy dominance” and argued that previous administrations sought to “suffocate” the economy to protect the environment.
The EPA estimates that repealing these greenhouse gas standards could save the power sector $19 billion in regulatory costs over two decades. This proposed repeal also targets the 2024 amendments to the Mercury and Air Toxics Standards (MATS), which had required coal-fired plants to lower toxic metal emissions by 67%. For developers, the July 1 guidance on offsets provides another layer of administrative streamlining amidst these broader policy shifts.
Risk management and the shifting burden for project developers
It is important to note that the EPA has not removed the offset hurdle; it has merely moved it. Developers who use this flexibility assume a new kind of risk. By breaking ground before securing offsets, a company bets that suitable credits will be available and affordable by the time the plant is ready to operate. If a developer completes a project only to find that the local offset market has dried up, the facility will sit idle under the enforceable conditions of its permit.
This shifts the burden from a regulatory delay to a market risk. While larger utilities might shutter older plants to create their own credits, independent power producers must navigate a potentially volatile market. Engineering and procurement contracts may now require specific clauses for “mechanical completion” versus “permission to operate,” accounting for potential delays in credit availability.
The July 1 memorandum remains guidance rather than a legally binding rule, meaning state, local, and Tribal permitting authorities still hold discretion. However, the federal lead provides a clear signal that the agency prioritises reducing administrative bottlenecks. As the industry faces accelerating electricity demand, these adjustments to the Clean Air Act’s implementation may determine which projects successfully transition from blueprints to operational facilities.
