The Energy Transition Has a Speed Advantage That Cost Models Miss

As electricity demand accelerates—driven by data centers, electrification, new industrial loads and cooling—the time needed to bring new capacity online has become a critical factor alongside cost. The International Energy Agency projects global data-center consumption will more than double to roughly 945 TWh by 2030, a scale comparable to a large national power market. A plant that is economical in 2035 cannot serve a customer seeking connection in 2028, so planners and buyers increasingly value technologies that can be delivered quickly.

Solar and wind benefit from a structural speed advantage that conventional cost comparisons often overlook. Lazard’s 2025 assumptions put construction for utility-scale solar at about 15 months, onshore wind at 18 months and offshore wind at 24 months; distributed rooftop systems can be installed in days once approvals and equipment are in place. By contrast, new combined-cycle gas plants are modeled at around two years, coal at five to five-and-a-half years and nuclear at seven years, with full development timelines often longer when planning and permitting are included.

That modularity also changes investment risk. Renewables are assembled from many manufactured units that can be installed in parallel and brought online in phases, allowing earlier revenue and more flexibility if demand forecasts shift. Large thermal plants and nuclear projects lack similar phaseability; a half-built coal or nuclear plant cannot generate revenue while incomplete. Shorter build cycles reduce exposure to interest-rate changes, inflation and regulatory shifts, which can materially affect project economics.

The traditional rapid-response role of gas is under strain because turbine supply and related project inputs are now congested. Siemens Energy reported shipping 6 GW of turbines in fiscal Q3 2026 but ending the period with a 69-GW backlog; GE Vernova disclosed a 116-GW backlog and slot reservations in Q2 2026, up from 100 GW three months earlier and with reservations into 2031. Reuters has reported combined-cycle costs more than doubled to over $2,400 per kilowatt in parts of the market, with turbine lead times exceeding five years. These bottlenecks encompass not only equipment but engineering, financing, permitting, fuel connections and grid access.

The speed advantage of renewables does not eliminate the need for firm, dispatchable capacity, storage, transmission upgrades or demand flexibility. One gigawatt of solar is not equivalent to one gigawatt of gas or nuclear because of differences in availability and timing. The IEA notes more than 2,500 GW of renewables, storage and large-load projects are stalled in queues worldwide, and new transmission can take five to 15 years. Still, the pragmatic comparison is between the fastest practical portfolio—renewables plus storage, existing firm plants and demand-side measures—and waiting for a single slower-to-deliver asset. Reflecting that reality, the IEA expects renewables to provide nearly half the additional electricity consumed by data centers through 2035, citing short lead times, competitiveness and suitability for corporate power-purchase agreements.