US electric transmission infrastructure must shift from a defensive posture to active championing because load growth projections from data centers, manufacturing reshoring, and electrification now exceed the capacity of existing planning frameworks to deliver new lines in time. The current pace of transmission build-out – roughly 1% annually in circuit miles over the past decade – falls far short of the 2-3% annual expansion the National Renewable Energy Laboratory estimates is needed through 2050. Without a fundamental change in how projects are conceived, permitted, and cost-allocated, the grid will become the binding constraint on every other clean energy and economic development goal.
Why Transmission Planning Has Failed to Keep Pace With Demand
The US transmission system was designed for a centralized generation model where large plants served nearby load. That model is collapsing under three simultaneous pressures: data center clusters demanding 100-500 MW each with 99.999% reliability requirements, federal incentives driving domestic manufacturing of batteries, semiconductors, and clean tech, and state clean energy mandates requiring massive renewable integration. The Midwest ISO (MISO) interconnection queue alone holds over 300 GW of generation and storage requests – more than the entire installed capacity of the MISO footprint – while PJM’s queue exceeds 250 GW. Most of these projects cannot interconnect without network upgrades that have no funded pathway.
Regional planning processes have historically optimized for reliability within balancing authority boundaries, not for interregional transfer capability. FERC Order 1000 (2011) attempted to introduce interregional coordination and competitive solicitation, but implementation fragmented across planning regions. The result: only seven interregional transmission projects have been selected through Order 1000 processes in over a decade. Meanwhile, the average time from concept to commercial operation for a high-voltage line now exceeds 10 years – longer than a combined-cycle gas plant or utility-scale solar farm. Permitting alone consumes 3-5 years, with NEPA review, state siting certificates, and federal authorizations (DOE Section 216, FERC backstop) often running sequentially rather than concurrently.
Cost allocation remains the deepest structural barrier. The “beneficiary pays” principle sounds rational but collapses when benefits are diffuse – reduced congestion, improved resilience, access to cheaper generation, decarbonization – and no single entity captures enough value to justify the upfront capital. MISO’s Long Range Transmission Planning (LRTP) Tranche 1 portfolio, approved in 2022, allocates $10.3 billion across 18 projects using a hybrid cost-sharing formula. Yet even this landmark effort covers only a fraction of identified needs, and Tranche 2 remains unresolved. Without a durable federal or multi-state cost allocation framework for interregional lines, developers and utilities rationally defer investment.
How FERC Order 1920 and Load Growth Rewrite the Economics
FERC Order 1920, issued May 2024, represents the most significant transmission rulemaking in a decade. It requires transmission providers to conduct 20-year scenario-based planning that accounts for anticipated load growth, generator retirements, and policy-driven resource shifts – not just historical trends. Crucially, it mandates evaluation of interregional transmission benefits using at least three future scenarios and requires consideration of “right-sizing” lines beyond immediate needs to capture economies of scale. That points to a structural shift: planners can no longer treat load growth as uncertainty to be managed reactively; they must treat it as a baseline planning input.
If this trend holds, the economics of transmission improve materially. A 765 kV line built at 3 GW capacity today costs roughly $2.5-3.5 million per mile; upsizing to 6 GW adds only 20-30% to capital cost while doubling transfer capability. That means the levelized cost of delivered energy across a right-sized interregional line can fall below $10/MWh – competitive with the marginal cost of gas generation in many markets. By comparison, the congestion costs in PJM alone exceeded $2.2 billion in 2023, and MISO’s congestion topped $1.8 billion. Those figures represent pure economic waste that transmission directly addresses.
The data center boom sharpens this calculus. A single 500 MW data center campus with 24/7 clean energy matching requirements may need 1.5-2 GW of renewable capacity across diverse geographies to achieve hourly matching – implying dedicated transmission or firm network upgrades. Hyperscalers are now signing “transmission-enabled” PPAs where they underwrite line development in exchange for priority access. Google’s partnership with NV Energy on the Greenlink West project and Microsoft’s involvement in PJM queue reform signal a new model: large loads as transmission anchor tenants. That could accelerate project timelines by 2-3 years if regulatory frameworks allow direct cost assignment to willing counterparties.
Who This Affects
- Utility planner: Must integrate 20-year scenario planning with explicit load growth forecasts into IRPs and transmission plans by 2026 compliance deadlines; failure to model interregional benefits risks FERC rejection and stranded asset exposure.
- Generation/storage developer: Interconnection queue position alone is insufficient; developers must now track transmission planning cycles, cost allocation proceedings, and “right-sizing” decisions that determine whether their project gets a deliverable path to market.
- Policy analyst: State clean energy targets (e.g., 100% by 2035/2040 in 24 states plus DC) are unachievable without interregional transmission; analysts should quantify the transmission gap in each jurisdiction and model cost-sharing mechanisms across state lines.
- Grid operator: RTOs/ISOs face dual pressure to accelerate queue processing (FERC Order 2023) and implement Order 1920 scenario planning simultaneously; resource adequacy metrics must evolve to reflect transmission-constrained deliverability, not just nameplate capacity.
What to Watch Next
- Order 1920 compliance filings due early 2026: Every transmission provider must submit revised planning tariffs; the specificity of their scenario assumptions, interregional benefit metrics, and right-sizing methodologies will reveal whether the rule drives real change or procedural compliance.
- MISO LRTP Tranche 2 and PJM RTEP 2025 cycle: These planning cycles will test whether new load forecasts (including announced data center campuses) translate into approved transmission portfolios with allocated costs – or whether cost allocation disputes stall another round.
- DOE Section 216 designations and NIETC updates: The Department of Energy’s National Interest Electric Transmission Corridor designations, expected to expand in 2025, could unlock federal backstop permitting for specific routes – watch for the first project to use this authority end-to-end.
- State legislative action on “right of first refusal” (ROFR) and cost allocation: At least 15 states have ROFR laws favoring incumbents; federal preemption bills or multi-state compacts (e.g., the Southwest Regional Transmission Initiative) could reshape who builds and who pays.
Bottom line: Transmission is no longer a passive enabler – it is the active constraint on US economic competitiveness and decarbonization. The entities that treat transmission as a strategic asset class to be originated, financed, and championed – not merely permitted – will capture the value of the energy transition; those that wait for certainty will be constrained by its absence.
Read the full report at Renewable Energy World
Note: facts and figures attributed above to Renewable reflect that outlet's original reporting. Broader context, cross-sector connections, and forward-looking scenarios reflect independent analysis by our editorial team.
About this article: Drafted by Energy Ai with AI-assisted research and writing based on public reporting, then reviewed under our editorial process before publication.
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