Power Demand Is Not the Constraint — Permitting Is: Can We Actually Build the Grid Fast Enough?
Power demand in the U.S. is no longer flat. In 2025, electricity generation reached a record 4.43 thousand terawatt-hours, up 2.8% year-on-year, reversing nearly two decades of stagnation. Growth is being driven by the commercial and industrial sectors, particularly data centers and manufacturing, with electricity sales rising across all end markets.
The main issue is whether the infrastructure needed to meet demand can actually be built, connected, and delivered on time.
Across transmission, pipelines, and generation, execution is now the constraint. Permitting delays, interconnection bottlenecks, and regulatory complexity are pushing timelines beyond underwriting assumptions and reshaping how capital is deployed.
Where Projects Are Actually Getting Stuck
The issue is the widening gap between capital deployment and project delivery. Transmission projects are among the most exposed. Multi-state siting requirements, environmental reviews, and local opposition introduce timelines that can stretch years beyond plans. These are not marginal delays, they can exceed original underwriting assumptions by several years, materially impacting IRRs.
Pipeline projects face a similar dynamic, with an added layer of regulatory and legal risk. Federal and state misalignment, alongside an increasingly litigious approval environment, means that even technically viable projects carry a non-trivial probability of delay or cancellation.
Generation is often viewed as more straightforward, but the reality is the constraints have shifted downstream. The key risks along with permitting, but the ability to interconnect.
Interconnection Queues and Grid Upgrades: The Hidden Bottleneck
Interconnection has become one of the least predictable variables in power investing.
More than 2.1 to 2.6 terawatts of generation and storage capacity is currently sitting in U.S. interconnection queues, roughly equivalent to the entire installed grid. Most of these projects will never reach operation. Not because of weak demand, but because of delays, process constraints, and cost uncertainty.
Developers enter queues without clarity on timing, upgrade requirements, or final costs.
For investors, two key risks emerge:
• Timing risk: Delays in reaching commercial operation push out cash flow realization and compress returns
• Cost risk: Uncertain and often escalating grid upgrade costs reduce margin and increase capital intensity
What looks compelling on entry can weaken significantly once interconnection realities are fully reflected in the economics.
Permitting Reform: Necessary but Uncertain
There is broad consensus that the current U.S. permitting framework is not equipped to deliver the scale and speed of infrastructure buildout now required. The core of the issue is fragmentation. Transmission, pipelines, and generation projects must navigate overlapping federal, state, and local processes, each with different timelines, requirements, and points of legal challenge.
Recent efforts to reform the system highlight both the urgency and the difficulty. Measures within the Inflation Reduction Act and Infrastructure Investment and Jobs Act have attempted to accelerate approvals for certain energy projects, while reforms led by Federal Energy Regulatory Commission aim to improve interconnection queue efficiency.
Progress is incremental, however constraints still exist in terms of:
• Jurisdictional overlap: Multi-state transmission projects still require sequential approvals, with no single authority able to coordinate timelines end-to-end
• Litigation risk: Projects that have cleared regulatory review can still face multi-year delays through legal challenges
• Uncertain timelines: Approval processes are rarely fixed, making it difficult to align development schedules with capital deployment assumptions
For investors, this means they are taking on more risk. A project that assumes a three-year development plan can extend to five or seven years with limited visibility on resolution. The more the timeline shifts out, the more the return profile changes.
The Grain Belt Express illustrates this dynamic. Despite strong commercial backing and clear system need, the project faces significant delays with construction now aimed for 2026, pushing its in-service date to at least 2028-2029.
These delays, coupled with the loss of a $4.9 billion federal loan guarantee, have nearly tripled project costs to $7 billion. While it still promises $11.3 billion in consumer savings, the shift to higher-interest private financing and inflationary pressure significantly defers these returns and tightens overall margins.
This project exemplifies the complexities of large-scale, cross-jurisdictional infrastructure.
Current reforms are unlikely to ease near-term capital constraints. While regulatory frameworks play a critical role in ensuring proper oversight, their structure prioritises process over pace, leaving them misaligned with the speed of private capital. This is widening the gap between demand and delivery.
Consequently, capital is flowing toward projects with existing permits and clear approval paths. In this landscape, permitting is no longer a background task, it is the primary factor determining when, or if, returns are realized.
Capital Is Repricing Permitting Risk — And Moving Accordingly
Permitting and interconnection risk are central to underwriting and capital allocation decisions.
The result is a clear reallocation toward opportunities where execution risk is more manageable and timelines are more predictable.
Capital is responding in a few clear ways:
• Premium on permitting visibility: Projects with existing permits, secured grid access, or established rights-of-way are commanding a premium relative to those requiring full greenfield approval
• Preference for brownfield and incremental expansion: Capital is concentrating in assets that build on existing infrastructure, where regulatory pathways are clearer and timelines more controllable
• Shift toward phased deployment: Investors are structuring capital commitments in stages, allowing flexibility to respond to permitting and interconnection developments over time
• Higher return thresholds for exposed projects: Large-scale greenfield developments, particularly in transmission and pipelines, now require additional return to compensate for execution uncertainty
• Focus on execution capability: Operators with a demonstrated ability to navigate permitting and regulatory complexity are seen as more attractive.
The market is more selective. Capital is flowing to grid-adjacent and interconnection-ready assets, while projects dependent on complex permitting face a higher bar. Permitting now determines where capital goes and whether returns are delivered.
These themes will be explored further at the New York Energy Investment Series at Nasdaq on 24 June, including a dedicated panel titled: “Power Demand Is Not the Constraint — Permitting Is: Can We Actually Build the Grid Fast Enough?”
If you are interested in contributing as a speaker on this topic, please contact:
Ben West: ben.west@pragma-energy.com
Amy Miller: amy.miller@pragma-energy.com
