GE Vernova: Selling Time to the AI Power Crunch

Picture a company with funding secured, land purchased and tens of thousands of accelerators arriving within months, yet with no electricity to run them. A grid connection could take five years, a large transformer more than two, and the biggest turbines are largely spoken for toward the end of the decade. While billions in hardware wait idle, each passing month erodes its edge, a bind Microsoft chief Satya Nadella echoed in late 2025 when he pointed to a shortage of finished powered buildings rather than chips.

Software and chips move on a calendar measured in months while power infrastructure moves on one measured in steel, copper and permits . GE Vernova, the General Electric energy spinout listed in April 2024, lives in the gap between those two clocks by effectively selling time . Its shares rose from around $140 at the spinout to near $950 by late September 2026, so the open question is how much durable value it can capture and how much is already priced in.

How the grid connection queue became the bottleneck

Electricity travels from generation through high-voltage transmission and substations down to distribution, and giant campuses usually connect near transmission voltage with their own substation. Building a new plant alone does not solve access, because a typical large United States project waited more than five years in connection queues during 2025. Large transformers separately needed more than two years from order to delivery, which makes grid access as scarce as generation itself.

AI loads strain this chain through density, with a classic server rack near 10 kW against more than 100 kW for an AI rack , compounded into gigawatt-scale campuses. One gigawatt running flat out approximates a year of power for about 800,000 American homes, or roughly 650,000 at steadier 80 percent loading. With tens of billions committed to accelerators, owners simply cannot accept a five-year wait for firm power .

One workaround is building generation behind the meter, exemplified by the Homer City conversion of a former coal site in Pennsylvania into a 4.5 GW gas-fired campus. According to Business Wire, the Homer City campus pairs seven GE Vernova turbines with a 4.5 GW data-center build backed by a large utility partner. Gas offers the fastest 24-7 power at that scale, though solar plus batteries supply cheaper energy per unit and most new American capacity without carrying an always-on load alone.

The power portfolio spans large combined-cycle turbines above 600 MW in both 60 Hz and 50 Hz versions, plus smaller aeroderivative units derived from jet engines. Bridge power matters too, with a developer order for 29 aeroderivative machines equal to about one gigawatt of faster supply. On the nuclear side, Canada's nuclear regulator authorised Ontario Power Generation to construct one BWRX-300 small modular reactor at the Darlington new nuclear site, a first unit of about 300 MW now moving forward.

Turbines, services and grid hardware as one business

Scale shows up in the installed base, with roughly 7,000 gas turbines in service and company equipment linked to about one quarter of world electricity output. Services generate about two-thirds of Power revenue as of the second quarter of 2026, converting past turbine sales into long maintenance annuities. In grid hardware, coverage in Transformer Technology describes GE Vernova finalizing the roughly $5.3B buyout of the ProlecGE transformer venture in February 2026, opening a much larger North American market with a backlog near $45B.

Wind remains the drag, loss-making for three consecutive years with no new offshore orders, even as gas and grid units carry the story. Management disclosure puts direct data-center exposure near 20 percent of gas-turbine contracts, a figure echoed when GasTurbineWorld reported GE Vernova seeing continued strong gas turbine demand tied to data centers and grid growth. Electrification booked more than $5B of data-center orders in the first half of 2026, about 40 percent of segment orders, against roughly 12 percent of total company orders , so indirect pull through utilities is clearly larger.

History counsels caution because General Electric overbuilt power capacity twice and later wrote down about $22B of goodwill before leaving the Dow after a century. Scott Strazik, who took over the gas business at the end of 2018 and now leads the company, shrank output toward 25 to 30 GW a year and removed about $1B of fixed costs . Lean factories are highly profitable at full use, leaving the cycle question of whether current demand is durable or another peak.

The machine itself explains the scarcity, compressing air, mixing it with fuel in a combustor and driving turbine blades at 3,600 revolutions per minute on the American grid. First-row blades sit in gas above 2,600 degrees Fahrenheit, using single-crystal casting, internal cooling channels and ceramic coatings borrowed from aerospace practice . Casting suppliers for those blades and vanes form a narrow choke that cannot expand overnight.

Pricing power, capacity plans and what backlog really means

Pricing already reflects tightness, with first-half 2026 turbine equipment orders priced more than 20 percent per kilowatt above late 2025 levels. Full combined-cycle plant costs moved from below $800 per kilowatt in 2022 toward roughly $2,000 to $3,000 today, while industry capacity is seen rising from 67 toward 102 GW a year by 2030. Orders jumped from about 58 GW in 2024 to near 100 GW in 2025, and transformer makers have announced more than $1B of new North American capacity for 2027 to 2028.

Not every announced gigawatt is equal, since a firm order is signed with penalties and enters backlog while a slot reservation is only a deposit and does not. Reporting by UtilityDive earlier described an 80-GW turbine backlog stretching into 2029, before the company later cited about 53 GW of firm turbine orders plus 63 GW of reservations. Deposits often run 20 to 25 percent and are typically non-refundable , so firm coverage alone equals two to two and a half years of output and four and a half to six with reservations.

Cash advances, margins and the bull-bear balance

Follow the customer cash from reservation to firm order, factory build with progressive revenue recognition, then decades of service annuities under long-term agreements covering about 1,800 turbines. Customer advances show the strain and the trust, with contract liabilities rising from about $15B at end-2023 to near $40B by June 2026. Growth in advances outpaced reported free cash flow in both 2025 and the first half of 2026, so cash excluding advances would look far weaker and second-half cash is guided substantially lower.

Profit guidance frames the debate, with Power margins seen at 17 to 19 percent and Electrification at 18 to 20 percent for 2026 while wind still guides a loss near $400M for the year. Analysis published by StockTitan on the second-quarter filing documents the raised outlook that underpins the current valuation debate among shareholders. The bull case cites broader-than-AI demand, scarcity already converted into backlog, service annuities and a second grid engine, against cycle risk, a coming capacity wave and deposit-funded cash, with the 28 October 2026 report as the next checkpoint.