NextEra Energy's "Federal Hub" Model Starts Paying Fees on 16.5 GW of Gas Projects Without Capital, While Virginia Becomes the Merger's Main Obstacle
Q3 2026 earnings call, October 21, 2026: adjusted EPS up 9.7%, 2026 guidance tracking to the high end of $3.92 to $4.02
NextEra Energy reported third quarter adjusted EPS growth of 9.7% and 9.5% year-to-date. Management left 2026 guidance of $3.92 to $4.02 unchanged and said it is targeting the high end, even after assuming El Niño will hold fourth quarter wind output to 90% to 95% of the long-term average. The longer-term framework is also unchanged: 8%-plus adjusted EPS growth through 2032 and the same target for 2032 through 2035, off a 2025 base of $3.71. CFO Mike Dunne said the combination with Dominion Energy would lift that growth rate to 9%-plus, and pointed analysts to the S-4 for the details. The more important news was how the Energy Resources growth story is changing in structure and in the risk it carries.
Federal hubs: fee income on 16.5 GW with no capital at risk
The most consequential new disclosure was the economics of the "federal hubs" model. NextEra has signed definitive agreements to develop, construct and operate three projects across Texas and Pennsylvania totaling about 16.5 GW. These have secured $5.7 billion of initial funding this year. Energy Resources earns fees on a predetermined schedule for development and construction and for the first 20 years of operations, and it contributes no capital.
Management said each hub generates roughly 50% of the adjusted EPS NextEra would earn if it owned the project over the first 20 years of operation. On that equivalent basis, the three hubs are about equal to the top end of the company's 4 GW to 8 GW natural gas development expectation for 2032. The model therefore delivers the upper end of the gas target with a much lighter balance sheet. NextEra also has the option to build and own battery storage at these sites, which it sizes at 6 GW to 11 GW. That would be a 15% to 30% upside to its storage development expectations.
Near-term contribution will be small. Dunne said that in 2026 and 2027 investors should expect "a relatively modest payment that is based on the development activities," growing through 2032, when operating fees begin and run through 2052. Initial contributions are already visible in the quarter. Federal hubs are now included in the new investments category, which added $0.09 per share, and they will move to existing energy assets after 12 months of fees. The first payments came earlier than they would have under conventional contracting, which prompted Wolfe Research's Steve Fleishman to ask about rebasing the outlook. Management did not take the bait and pointed to the S-4 and the 9%-plus combined growth rate.
Timing and execution are the risks. NextEra expects to serve meaningful load as early as 2028 and 2029 through behind-the-meter generation, then ramp to full campus requirements from 2030 through 2032. Permits and approvals are still being secured, and construction and PPA solicitation are running in parallel. Beyond the hubs, NextEra has more than 20 GW of large-load projects advanced, over 18 GW of them gas-fired. It is also pursuing a pipeline of 30 potential hubs, which it expects to reach 40 by year-end. It plans to build and own up to 2 GW of gas and up to 2.6 GW of storage at the Paducah site in Kentucky.
Capital-light gas eases funding pressure, but management will not cut the recycling range
Barclays' Nick Campanella asked whether capital-light hubs reduce the need for asset sales. Dunne did not concede that point. The $7 billion to $12 billion capital recycling range was built on historical instances where buyers valued assets more than NextEra did. He said the base plan does not rely on recycling to meet equity needs, and "I would expect us to look to hold on to more of that unless there's an opportunistic opportunity." Equity needs through 2032 were reiterated at $12 billion to $17 billion. Management highlighted diversified funding across Europe, Australia, Canada and the U.S., tax equity relationships, and growing interest from large asset managers.
Rate exposure appears contained. NextEra has more than $48 billion of forward-starting hedges at an average rate of about 4% and an average tenor of about 9 years. A 50 basis point move in rates affects 2028 EPS by only $0.01 to $0.03, or less than 1%.
Virginia: intervenor testimony turns the Dominion deal into a political fight
The Dominion merger is where the call was most defensive. Fleishman noted that the Virginia governor's office and SCC staff filed positions this week with what he called "pretty onerous conditions," including ring-fencing proposals. CEO John Ketchum said the company is still digesting the testimony and will file a rebuttal in a couple of weeks, ahead of hearings in mid-November. He framed the case around affordability, jobs and clean energy. He cited nearly $2 billion of residential bill credits, now extended from 2 to 4 years, a $100 million increase to the EnergyShare assistance program, a $5 billion supplier program, 1,000 new Virginia jobs including 400 covered by supplier letters of intent, and a co-headquarters tower in Richmond.
Ketchum did not rule out concessions. "In the rebuttal process and through the hearings themselves, there's always opportunities for compromise on certain specific issues," he said, while standing behind the filing. Asked about Virginia's "do no harm" standard, he said "I like our chances under that standard," then added that the outcome is "not for me to decide. That's for the SCC to decide." That is a measured answer given the governor's office position. No settlement was signaled, and management offered no detail on North Carolina or South Carolina commitments beyond saying it will share specifics later.
Shareholders of both companies approved the deal on September 3. Procedural schedules call for Virginia and South Carolina hearings in November and December and final orders in January 2027. North Carolina expert hearings begin in February 2027. Management still expects closing in the second half of 2027. The hearing calendar is compressed, and a contested Virginia record raises the odds of conditions that could dilute the stated 9%-plus growth case.
Backlog, storage and solar pricing
Energy Resources added 3.7 GW to its backlog in the quarter, including 2.4 GW of storage. This was the fourth straight quarter above 3.5 GW. The backlog is now about 36.7 GW after 1.8 GW of in-service projects. Management said it has achieved more than two-thirds of the midpoint of its 2026 through 2029 development expectations, and Dunne said only 17.6 GW remain to be added to reach that midpoint. Storage is running ahead of other products. Brian Bolster of Energy Resources said customers are prioritizing capacity right now, and he expects "a shift in the coming quarters back towards more energy than capacity."
Goldman Sachs' Carly Davenport noted lower solar backlog in certain years and asked about cost pressure from rates, Section 232 and equipment constraints. Management did not quantify any cost inflation or pass-through percentage. Ketchum said solar remains "a very compelling product offering" and highlighted NextEra's supply chain advantage. Dunne said PPA pricing locks in interest rates at signing and that tax credits and power scarcity support pass-through. Bolster made a more pointed competitive argument: "We were never the low-cost bidder in the market. And so actually, this is helping us because I think others are feeling a lot more pressure because their margins were skinnier." That is a credible point, but it is an assertion rather than data.
Recontracting remains favorable. NextEra signed a 20-year PPA for about 1 GW of Point Beach, which is subject to Wisconsin PSC approval and leaves the plant fully contracted into the 2050s. Renewable recontracting year-to-date is about 1,400 MW at an average premium of roughly $20 per MWh to recent realized pricing, and the total including other assets is nearly 2,400 MW. Dunne reiterated that Point Beach contributes about $0.21 per share on average once existing contracts roll off in 2031 to 2033. Bolster corrected an analyst who described this as an upgrade: it is a recontracting of existing capacity.
Transmission and nuclear
Regulated and invested capital, together with secured capex across electric and gas transmission, is up roughly 25% since December 2025 to about $12.7 billion. This includes MISO's selection of NextEra for two 765 kV projects in Illinois and a $1.2 billion, 97-mile gas pipeline joint venture with Chesapeake Utilities in South Florida. Management maintained its 20% to 25% rate base CAGR target for 2025 through 2032. Dunne said the upside is most likely in gas transmission, driven by bring-your-own-generation demand, though he cautioned that expectations are "already quite high." Bolster put the scale in context, saying the segment is growing "a small utility into like a $50 billion utility."
Duane Arnold remains on track to restart no later than Q1 2029, supported by a DOE loan of up to $1.9 billion that closed in the quarter. On new nuclear, management was cautious. NextEra has 6 GW of SMR co-location potential at existing sites but will require risk-sharing structures that cap its exposure. Bolster said the company has a bias toward SMRs but would consider large-scale reactors if the customer strongly prefers them and protections are adequate.
FPL: strong returns, a hurricane test and an unsigned large-load deal
FPL earnings rose $0.06 per share, driven by 9.2% growth in regulatory capital employed. Weather-normalized retail sales rose 1.4%. Trailing regulatory ROE is about 11.8%, and full-year capex is about $12 billion. FPL reversed $172 million of the rate stabilization mechanism, leaving roughly $1.5 billion after tax.
Hurricane Isaias, a Category 2 storm, hit Northwest Florida. FPL restored more than 97% of affected customers by Tuesday. Forensic review showed no hardened pole failed, underground lines performed about 14 times better than overhead lines, and smart grid technology avoided roughly 140,000 outages. Ketchum was careful to say these investments "do not make the grid hurricane-proof."
On large load, FPL raised its 2032 expectation from 6 GW to 8 GW and still expects to announce a deal by year-end. President Scott Bores said the first couple of gigawatts need little beyond battery storage given the existing gas and nuclear fleet. He declined to give a size, and Barclays' attempt to learn whether the deal would be a few hundred megawatts or close to 1 GW went unanswered. Bores also noted the deals are "multibillion-dollar" and complex, and that the company is building community support before announcing them. This was a notable comment because it suggests local opposition is a factor in timing. The deal is promised, but the announcement is not yet certain to arrive on schedule.