The projects on a facilities team's execution list for the second half of 2026 were, in most cases, approved against power availability assumptions that the interconnection queue doesn't validate. That isn't a facilities planning error. It's a sequencing problem that originates upstream in the capital approval process and arrives at the facilities function as a hard deadline attached to a timeline that the grid operator doesn't recognize.
The gap between what's been approved and what can actually be delivered on schedule is one of the defining operational realities of the current infrastructure environment. Facilities and energy managers who have spent the past twelve months watching interconnection timelines extend past original project models are not dealing with exceptions. They're dealing with the new baseline. The organizations that adapt their project sequencing around that baseline before the next round of capital is committed are in materially better position than those still planning against queue timelines from two or three years ago.
What Five-Year Interconnection Wait Times Mean for Project Schedules in 2026
Lawrence Berkeley National Laboratory (LBNL), which tracks interconnection queue data across all major U.S. grid operators, reported in its May 2026 data update that over 2,060 gigawatts (GW) of total generation and storage capacity were actively seeking grid connection as of the end of 2025. Projects installed in 2024 took nearly five years from their initial interconnection request to commercial operation, roughly double the timeline for projects built in the early 2000s. The national median wait time for interconnection studies alone exceeded 40 months in 2024, with Northern Virginia and other high-demand corridors running well above that range.
For a facilities team running a project that requires new load interconnection, those figures apply directly. A project approved in mid-2026 with an eighteen-month timeline to operations isn't just optimistic in a congested market. It's a planning document built around queue timelines that regional independent system operators (ISOs) and regional transmission organizations (RTOs) aren't operating on. The grid's schedule and the business plan's schedule are running independently of each other, and facilities teams are typically the first to discover they've diverged, often after equipment procurement decisions have already been made against the project timeline rather than the utility's.
Grid Strategies' November 2025 analysis projected that the U.S. power sector needs to add more than 150 GW of additional capacity within five years to meet current load growth trajectories. The interconnection system responsible for enabling that build-out is the same system producing five-year wait times. That tension is not going to resolve on the schedule most facilities plans assume.
The Gap Between Approved Capital and Available Power in Active Projects
The practical consequence for facilities planning is a category of project risk that rarely appears in project models until it's embedded in the schedule. Capital gets approved. Site work begins. Equipment is ordered against an assumed energization date. Then the utility interconnection timeline arrives, set by queue position, study completion schedules, and transmission upgrade requirements that the facility operator can't control and can't accelerate.
Capacity market pricing in the PJM Interconnection region illustrates what grid scarcity looks like on the supply side. Capacity prices for the 2025 to 2026 delivery year reached approximately $270 per megawatt-day (MW-day) across most of PJM's footprint, compared to roughly $29 per MW-day in the prior delivery year, according to market data tracked by Novogradac. Prices for the 2026 to 2027 delivery year hit the Federal Energy Regulatory Commission (FERC) cap of $329 per MW-day for PJM's entire footprint. The price signal reflects real scarcity in the available supply buffer. Facilities teams ordering equipment and phasing construction against assumed power delivery timelines are absorbing that scarcity as schedule variance rather than as a cost they priced in advance.
An additional pressure point entered the queue in the final weeks of Q2. The One Big Beautiful Bill Act (OBBBA) created a construction-start deadline of July 4, 2026, for wind and solar projects seeking to retain eligibility for production and investment tax credits under transitional provisions. LBNL data shows that Q3 and Q4 of 2025 posted the highest project withdrawal volumes on record as developers in the interconnection queue calculated whether their projects could clear studies and secure agreements in time to qualify. For facilities teams with contracted renewable supply tied to projects that subsequently withdrew, the withdrawal is a delivery risk: a contracted energy source that may not arrive on the schedule the energy cost model assumed.
How Facilities Teams Are Redesigning Project Sequencing Around Queue Reality
The workarounds gaining traction in constrained markets share a common logic: build optionality around the grid connection timeline rather than plan against a single energization date. Behind-the-meter (BTM) generation, including on-site solar, battery storage, or distributed generation, bypasses the interconnection queue entirely for the load it covers. It doesn't satisfy the full load requirement for most facilities, but it reduces the volume of power that needs to arrive from the grid on a fixed schedule. That reduction compresses the consequences of a queue delay on everything else.
Virginia's Senate Bill 508 (SB508), signed by Governor Abigail Spanberger in April 2026, illustrates how states are beginning to create regulatory pathways around the queue. Rather than requiring a new interconnection agreement and the queue position that comes with it, SB508 directs Dominion Energy Virginia and Appalachian Power to assess existing solar interconnection points for unused capacity that storage or additional generation resources can access without a fresh queue application. In a corridor where LBNL data puts median interconnection wait times above 40 months nationally and higher in Northern Virginia specifically, the practical value is meaningful: a project accessing surplus capacity skips the queue, not just a portion of it.
Phased commissioning is a third adaptation, accepting partial energization on whatever timeline the grid can support and building initial operations around that constraint rather than waiting for full load availability. The economics are less efficient than a single commissioning. For projects facing two- or three-year queue timelines, partial operations generate revenue and prove out operational assumptions while the remaining interconnection capacity clears.
What Facilities Leaders Should Be Raising Before the Next Milestone Review
The leverage point for facilities teams is earlier in the process than most organizations currently apply it. By the time equipment procurement is under way, the interconnection timeline is effectively set. What can still change are sequencing assumptions, contingency structure, and commissioning plans, but only if the facilities function has surfaced the gap between the approved project timeline and queue reality before downstream decisions are locked.
Before the next milestone review, the facilities function should be able to answer a few specific things. Where does this project's interconnection application actually sit in the regional queue, and what is the realistic study completion timeline given current backlog? If power delivery arrives six to twelve months late, does the project schedule carry stranded equipment costs, lease obligations, or compliance milestones that create financial exposure? Has the team evaluated BTM alternatives or surplus interconnection capacity as a hedge against the primary timeline slipping?
Facilities teams didn't set the queue conditions they're working inside. What's within their control is whether those conditions enter the project conversation before capital is committed or after it is. The former is a planning decision. The latter is a damage-control exercise, and the options are narrower by the time it starts.
