DC Circuit Upholds FERC Order 2023, Clearing Legal Hurdle for 2,600 GW of Grid Interconnections

The common misconception regarding the United States energy transition is that it is currently stalled by a lack of capital, a shortage of proposed projects, or insufficient technological maturity. The evidence across regional power markets shows otherwise: there is no shortage of generation waiting to be built. The actual, mechanical bottleneck choking the deployment of new power is the administrative queue required to plug those completed project proposals into the physical grid. For years, the regulatory framework governing how new power plants connect to the transmission system has functioned like a single-lane toll booth for a multi-lane highway, resulting in a system where projects wait an average of five years just to receive their interconnection studies.

On July 31, 2026, the United States Court of Appeals for the District of Columbia Circuit cleared the most significant legal hurdle to dismantling that bottleneck. In a unanimous per curiam decision, a three-judge panel consisting of Judges Millett, Walker, and Childs upheld the Federal Energy Regulatory Commission's landmark Order 2023 in its entirety. The ruling denied twenty-one consolidated petitions for review brought by a fractured coalition of transmission providers, grid operators, and clean energy developers, all of whom had challenged different mechanisms within the sweeping regulatory overhaul.[1][4][7]

The court's decision preserves a comprehensive, nationwide restructuring of how new power generation secures access to the transmission system. At stake in the litigation is a staggering administrative backlog: at the end of 2023, roughly 2,600 gigawatts of proposed generation and storage capacity were sitting in interconnection queues across the country. Order 2023 was designed specifically to address this decades-long traffic jam, which FERC determined had rendered the existing wholesale energy markets unjust and unreasonable by artificially restricting new market entrants.[7][8]

To put the scale of that 2,600-gigawatt backlog into perspective, the interconnection queue currently holds more than twice the installed generation capacity of the entire United States, which stands near 1,200 gigawatts. Approximately 95 percent of the backlogged capacity consists of zero-carbon resources, primarily solar photovoltaic, wind power, and battery energy storage projects. While grid operators acknowledge that a large portion of these proposals are speculative and will never be built, the sheer volume of applications had entirely overwhelmed the legacy administrative processes designed in the early 2000s.[6]

Under the incumbent "first-come, first-served" serial study approach established by FERC Order 2003, regional grid operators were required to evaluate projects sequentially. This framework created a cascading failure mechanism: developers would submit speculative interconnection requests early to secure a place in line, wait years for a study, and then withdraw when network upgrade costs proved too high. Because the studies were sequential, a single withdrawal at the front of the queue forced transmission providers to restudy every subsequent project in the line, paralyzing the entire system.[5][7]

FERC Order 2023 replaces this sequential bottleneck with a "first-ready, first-served" cluster study process. Transmission providers are now mandated to group interconnection requests geographically and evaluate them simultaneously within defined study windows. This cluster approach not only accelerates the timeline for assessing grid impacts but also allows grid operators to spread the costs of necessary network upgrades across multiple developers in the cluster, rather than saddling a single project with the entire financial burden of a regional transmission upgrade.[5][8]

To prevent the new cluster studies from being overwhelmed by the same speculative proposals that broke the serial system, the rule introduces strict commercial readiness requirements and financial disciplines. Developers must now post substantially larger financial deposits scaled to the size and stage of their project. Furthermore, Order 2023 imposes tiered withdrawal fines that increase in severity as a project advances through the queue. Historically, FERC found that developers ultimately withdrew more than 70 percent of the interconnection requests filed between 2000 and 2017.[6][7]

The most fiercely contested element of the new regulatory regime—and the primary focus of the transmission providers' litigation—was the imposition of firm, enforceable deadlines on the grid operators themselves. Under the previous framework, transmission providers were only held to a "reasonable efforts" standard for completing interconnection studies. This standard effectively allowed utilities and regional transmission organizations to miss study targets for years without facing any financial or regulatory consequences, shifting the entire schedule risk onto the project developers.[6][8]

Order 2023 eliminates the reasonable efforts standard, replacing it with firm study deadlines backed by automatic late fees. Under the upheld fee schedule, a delayed cluster study will cost the transmission provider $1,000 per business day, while delayed facilities studies—the final stage before an interconnection agreement is signed—incur penalties of $2,500 per business day. To prevent these penalties from becoming infinite liabilities, FERC capped the total late fees on any single study at 100 percent of the developer's initial study deposit.[6]

In the consolidated case, Advanced Energy United v. FERC, transmission providers argued that these late fees violated the due process clause of the Fifth Amendment and constituted an unconstitutional taking. They contended that delays are often caused by factors outside their control, such as late data from developers. Conversely, clean energy trade groups argued that the withdrawal penalties applied to developers were overly punitive, particularly when projects are forced to withdraw late in the process due to unanticipated cost spikes.[4][5]

The D.C. Circuit rejected all of these arguments, ruling that FERC acted clearly within its statutory authority under Section 206 of the Federal Power Act. The court noted that the study-delay fees function as a valid ratemaking remedy to correct unjust practices, and that the framework provides adequate procedural safeguards for transmission providers to appeal the late fees on a case-by-case basis. The panel concluded that FERC reasonably balanced competing interests and prioritized systemic certainty over individual flexibility.[1][4]

With the legal cloud lifted, grid operators across the country must now proceed with implementing the compliance filings they submitted over the past year. The transition to the cluster study model will not drain the 2,600-gigawatt queue overnight, and the ultimate success of the rule will depend on how efficiently regional operators execute the new framework. However, the court's affirmation establishes the durable structural mechanics required to finally move viable energy projects from the drawing board to the physical grid.[3][7]