Beyond the headlines: What DOE's FERC directive really means for your project

Update, October 29, 2026: FERC did not issue a single national rule. On June 18, 2026, it issued show-cause orders under Section 206 of the Federal Power Act to all six FERC-jurisdictional grid operators (PJM, MISO, SPP, CAISO, ISO-NE, and NYISO), directing each to justify its current large load interconnection rules or propose tariff changes. Responses were due in mid-August, with up to 90 more days available on request, and stakeholder comments followed in September. ERCOT is outside FERC jurisdiction, and Texas is handling large loads on its own track (see our take on the Texas audit). The analysis below reflects DOE's original October 2025 proposal.

The Department of Energy (DOE) utilized a rare provision of the DOE Act to propose that FERC assert jurisdiction over transmission-level large load interconnections (greater than 20 MW) and establish national guardrails. At the time of writing, this was an Advanced Notice of Proposed Rulemaking, and DOE asked FERC to take final action by April 30, 2026. If adopted as proposed, utility studies for curtailable loads could be completed within 60 days, and processes would be standardized. However, utilities and states are likely to litigate over jurisdiction and cost allocation.

What just happened

On October 23, Energy Secretary Chris Wright invoked Section 403 of the DOE Organization Act to propose an Advanced Notice of Proposed Rulemaking (ANOPR) directing FERC to start a rulemaking on large load interconnections (>20 MW) and take final action by April 30, 2026. This marks only the third time this authority has been used in recent years, signaling the administration's urgency to "win the AI race" by cutting through state and utility bottlenecks that have stalled grid connections. This is the first step in what could be a lengthy regulatory process, including comment periods, potential revisions, and near-certain litigation. 

The proposed regulatory earthquake

DOE argues FERC has jurisdiction when loads interconnect directly to transmission facilities. The proposal outlines 14 principles, including standardized study processes, expedited utility studies for curtailable/dispatchable loads (aiming for a 60-day completion), and 100% network upgrade cost responsibility by load. Expect fierce challenges from utilities and states over jurisdictional boundaries. Utilities could fight to preserve their gatekeeper status, leading to protracted legal battles even if FERC moves forward. The final cost allocation framework, study timelines, and jurisdictional boundaries could look different from DOE's initial proposal.

Data Center lens: speed vs. certainty trade-offs

For hyperscalers and data center developers, this proposal presents a double-edged sword that trades speed for capital exposure.

Upside: Standardization could collapse the current 3-5+ year state-by-state utility negotiations into a predictable federal framework. DOE proposes an expedited study path (asking if 60 days is feasible for curtailable/dispatchable loads), potentially revolutionary if you're willing to give grid operators dispatch rights over your facility.

Downside: While the DOE proposes 100% network upgrade responsibility for loads, it also seeks comments on crediting mechanisms, leaving the final cost allocation uncertain. And "hybrid" interconnections (co-locating with generation) now face new study requirements that utilities already view skeptically. Add to that the risk of FERC issuing restrictive colocation rules that could limit behind-the-meter arrangements or impose additional reliability requirements. 

Bottom line: There will be faster queue movement, but potentially higher upfront capital exposure and regulatory uncertainty around colocation structures.

The critical challenge is validation timing. Even with expedited 60-day utility studies, developers need answers before entering the study and queue phase and paying study deposits that can reach six figures in some cases. Site selection moves swiftly, competitors are evaluating the same locations, and every week of delay means losing ground. Speed in technical validation separates winning projects from those stuck in analysis paralysis. Mapping the interconnection pathway for a specific point of interconnection before filing is where that starts.

Renewable energy developer lens: competitive threat meets opportunity

This creates both a threat and an unprecedented opportunity for renewable developers and powered land brokers.

Threat: Large loads will now compete in the same interconnection queues as generation projects, potentially displacing renewables or forcing shared network upgrade costs. If loads receive expedited 60-day utility studies while generation languishes in multi-year cluster studies, that competitive imbalance could reshape market dynamics overnight. Renewable projects that took years to position suddenly face displacement by data center loads that can move through the queue faster.

Opportunity: But the "hybrid" facility framework flips that threat into opportunity. The ANOPR explicitly incentivizes co-location of renewables + storage with data centers. A 600 MW solar + BESS paired with a 500 MW data center that requests only 100 MW of injection rights could dramatically reduce network upgrades compared to standalone development. This creates an opportunity for new co-located development in constrained zones where transmission limitations have blocked standalone projects. Note that existing generators seeking to convert to hybrid must first complete reliability studies and any required network upgrades.

The equation is simple: massive new grid demand + curtailable loads = urgent need for dispatchable generation

This creates a resource race based on execution velocity and reliability. Strategic renewable developers packaging integrated solutions (renewables + storage + load following) must prove feasibility at data center decision speed to win. The window is narrow. Natural gas has firm capacity advantages but it also has a backlog of 36 months. The 60-day expedited path for curtailable resources unlocks a major opportunity for renewables, enabling them to compete directly with gas by demonstrating accelerated construction timelines and comparable reliability.

The bottom line: speed is imperative

While the final form of these regulatory reforms is not yet set and could take years to implement, site selection operates in months. Even if utilities eventually offer 60-day studies for curtailable loads, developers need answers before paying study fees and deposits that can reach six figures. This timing mismatch creates an asymmetric advantage: developers who can independently validate interconnection feasibility can move at deal velocity, while competitors wait for regulatory clarity.

The core bottleneck isn't policy; it's the speed of technical validation. Data center developers need interconnection answers in days, not months, to commit capital to sites. Renewable developers need to prove hybrid configurations work before data centers select other firm load partners. Both need validation measured in days, not months. 

Until now, power flow studies conducted by consultants and internal teams have taken an average of 3 months to complete. Paces Power Flow Studies deliver the same standard and utilize utility-grade methodology, but are now completed in as little as 5 days. This enables developers to screen sites, quantify network upgrades, and make go/no-go decisions faster. For how power validation fits into site selection, see the power development funnel.

This regulatory shift creates massive new grid demand that will be met by either renewables or gas, depending on which can demonstrate speed and reliability first. The speed of technical validation will determine which developers capture the AI infrastructure opportunity.

Frequently Asked Questions

What did DOE ask FERC to do on large load interconnection?

In October 2025 the Energy Secretary used Section 403 of the DOE Organization Act to propose that FERC standardize interconnection for transmission-level loads over 20 MW, including faster studies for curtailable loads, load responsibility for network upgrades, and a path for co-located hybrid facilities.

Did FERC issue a single national large load rule?

No. On June 18, 2026, FERC issued show-cause orders to the six FERC-jurisdictional grid operators (PJM, MISO, SPP, CAISO, ISO-NE and NYISO), directing each to justify its current large load interconnection rules or propose tariff changes, rather than issuing one uniform national rule.