For financial institutions financing, investing in or valuing power-intensive projects, the rules governing large-load interconnections are becoming a material consideration for project timing, capital requirements and portfolio strategy.
Electricity demand from data centers, advanced manufacturing and other large industrial users is growing faster than many transmission systems were designed to handle. On June 18, 2026, the Federal Energy Regulatory Commission (FERC) issued show-cause orders directing all six regional grid operators to justify or reform their tariff rules for large-load interconnections within 60 days and file resource adequacy reports within 30 days.
These are not final rules. They open six parallel regional proceedings, and outcomes will likely vary by market. But the direction is unmistakable: FERC wants large-load projects to connect more efficiently, bear an appropriate share of the costs they create and demonstrate a credible relationship between new demand and available supply.
For lenders and investors, that means regulatory decisions could directly affect development timelines, financing needs, asset valuations and long-term portfolio strategy.
What FERC’s Large-Load Order Means for Energy Investors
FERC is not simply trying to make it easier for more large loads to connect to the grid. It is attempting to establish clearer terms for how those projects enter the system, who bears the associated costs and how new electricity demand will be matched with reliable supply.
For energy lenders and investors, that means interconnection is moving out of the technical appendix and into the center of the investment decision. Regional differences will matter — lenders and investors should expect different requirements, risks and opportunities across the country as each grid operator responds to the order.
The projects most likely to attract capital will not necessarily be those with the largest announced demand. They will be the projects that can demonstrate a credible, flexible and financeable path to power.
What These Changes Mean Together
FERC’s proceedings point toward a new model for large-load development, a model that demands more from projects before they can access the grid. Going forward, developers will increasingly be expected to demonstrate greater commercial readiness, clearer responsibility for grid costs, a realistic source of generation, operational flexibility where applicable and meaningful coordination between load, generation and transmission timelines.
For financial institutions, this redefines what project bankability means. Strong demand signals are not enough. A financeable project needs credible answers to five specific questions and those answers will vary across the six regional markets affected by the FERC order.
Here Are the Five Changes Investors Need to Understand
1. Faster and More Disciplined Study Processes
FERC is directing regional grid operators to overhaul how large-load transmission applications are submitted, evaluated and studied including consideration of alternative transmission technologies that could expand grid capacity more efficiently.
According to Enverus Intelligence® Research (EIR), the goal is to create a process that can distinguish credible developments from speculative, duplicative, or commercially unready requests. Projects that are genuinely ready may move through faster; less mature applications could lose their place in queue or face higher requirements.
Why this matters for financial services
A utility interconnection application or a proposed energization date should not be treated as evidence that power will actually be available. Before committing capital, lenders and investors should evaluate:
- Whether the developer controls the site and has made meaningful financial commitments
- Which interconnection studies have been completed — and which are still outstanding
- What network upgrades are required and whether the proposed timeline accounts for them
- Whether the load request reflects a realistic development schedule, not just an option
The core financial question:
Is this a real project with an executable path to power — or an attractive development story that hasn’t been stress-tested against grid realities?
2. Stronger Protection Against Cost Shifting
FERC is focused on bringing transparency to transmission and network upgrade costs by ensuring those costs are borne by the projects that trigger them, not shifted to utilities and existing ratepayers.
A new data center or industrial facility can require substantial grid investment. If that project is delayed, downsized or cancelled, the infrastructure built to serve it may still need to be paid for. FERC wants clearer accountability for those outcomes.
ENVERUS INTELLIGENCE RESEARCH®
EIR notes that utilities stand to gain significantly from the volume of transmission buildout this reform will drive. EIR specifically identifies AEP, Oncor and NextEra Energy (NEE) as well-positioned to capitalize — all three are concentrated in PJM and ERCOT, where EIR forecasts the highest load growth. Source: ”Setting Terms | FERC Rewires Large-Load Interconnection,” EIR, June 22, 2026.
Why this matters for financial services
Large-load developments will increasingly require meaningful financial commitments earlier in the project lifecycle. Depending on how regional rules evolve, exposure could include:
- Study deposits and scoping fees
- Network upgrade contributions and construction cost-sharing obligations
- Letters of credit and parent company guarantees
- Minimum payment requirements and obligations tied to requested capacity
- Costs associated with a delayed or reduced load ramp
These requirements will affect project leverage, liquidity, contingency reserves and the amount of sponsor equity required before operations begin. Transmission costs are becoming a material line item in the project capital structure.
3. Greater Support for Co-location and Behind-the-Meter Generation
FERC is directing regional markets to develop clearer treatment of co-located projects — arrangements that pair a large electricity user with generation located on or near the same site. Under the new order, these projects receive an explicit regulatory tailwind: they are positioned to become the preferred pathway for connection requests.
ENVERUS INTELLIGENCE RESEARCH®
EIR views co-location as the emerging blueprint for large-load development. According to EIR, co-located projects — already a major and growing trend — now receive regulatory validation, paving the way for projects that pair load with supply to become the desired model. EIR tracks co-located data center campuses across all major grid regions and expects this structure to increasingly define how hyperscalers and industrial users access power. Source: “Setting Terms | FERC Rewires Large-Load Interconnection,” EIR, June 22, 2026.
That said, co-location changes the nature of the risk it doesn’t eliminate it. The entire power solution still requires rigorous diligence.
Why this matters for financial services
For gas-fired behind-the-meter generation, diligence should cover pipeline proximity, available transportation capacity, fuel price exposure, equipment availability, air permitting, operating reliability, backup power and grid import/export restrictions.
For renewable and storage combinations, the analysis should address intermittency, storage duration, grid backup requirements and contractual alignment with the facility’s actual operating profile.
Co-location also opens new investment opportunities across generation, storage, microgrids, gas infrastructure and related energy services.
4. New Service Options for Flexible Large Loads
FERC is asking grid operators to consider new transmission-service options for large loads that can reduce or interrupt consumption when the grid is constrained. Projects with genuine operational flexibility may be able to connect faster, or at lower cost, because they don’t require the grid to serve their full maximum demand under every condition.
This is particularly relevant for projects supported by on-site generation, battery storage, staged load growth, demand-management technology, or curtailable operations.
Why this matters for financial services
Load flexibility can be a real source of project value — but only when it is technically credible and commercially structured. Before underwriting that value, investors should ask:
- How often can the project be curtailed and for how long?
- Who controls the curtailment decision — the utility, the operator, or an automated system?
- Does the project have backup supply that maintains operations during interruptions?
- Are tenant or customer contracts compatible with service interruptions?
- What happens to revenue during a curtailment event?
The core financial question:
Can the project reduce its grid demand without undermining the revenue and operating assumptions that support the investment thesis?
5. Better Coordination Between Large Loads and Nearby Generation
The final reform area addresses how new generating facilities should be studied when they are intended to serve electrically proximate or co-located large loads. Historically, load development, generation interconnection and transmission planning have moved through separate processes on different timelines — a separation that is increasingly untenable when a large-load project depends on new generation arriving at roughly the same time.
Why this matters for financial services
Investors can no longer evaluate the load and its proposed power supply as independent projects. The two must be underwritten together. Key questions include:
- Does the generation project have its own credible interconnection path?
- Are transmission upgrades required for both the load and the generation?
- Can the generation legally and physically serve the load as proposed?
- How do delays in one project affect the economics of the other?
- Who bears the risk if the load and generation timelines don’t align?
This is especially important for projects promising accelerated access to power through a generation asset that hasn’t yet been constructed or interconnected. As EIR puts it, a proposed power source is only valuable when it can actually be delivered on the timeline embedded in the financial model.
About Enverus Intelligence® | Research, Inc. (EIR)
Enverus Intelligence® | Research, Inc. (EIR) is a subsidiary of Enverus that publishes energy-sector research focused on the oil, natural gas, power and renewable industries. EIR publishes reports including asset and company valuations, resource assessments, technical evaluations, and macro-economic forecasts and helps make intelligent connections for energy industry participants, service companies, and capital providers worldwide. See additional disclosures here.
