Southern Company reported third-quarter 2026 results on November 5, and the numbers split cleanly into two categories: electricity already being used, and electricity merely promised. The first category is unambiguous. Data-center electricity usage across Southern’s electric utilities rose 59 percent year over year in the quarter, and 52 percent for the first nine months, as customers accelerated their load ramps. The second category is larger and slower. Southern now holds about 21 gigawatts of signed large-load contracts, with another 7 gigawatts in late-stage discussions — but its own ramp schedule does not expect the full 21 gigawatts to be drawing power until the mid-2030s. The gap between those two numbers is the story of this quarter.
The headline quarter was strong, and warm weather did part of the work. Adjusted earnings per share came in at $1.94, up from $1.60 a year earlier and $0.29 above the company’s own estimate; reported earnings were $1.77 per share against $1.55. Operating revenue reached $8.84 billion, up 13 percent. Weather contributed 17 cents per share against normal in the quarter, compared with 3 cents a year ago, and management now expects full-year 2026 adjusted earnings of about $4.70 per share — 10 cents above the top of its original $4.50 to $4.60 guidance range, and 9 percent growth year over year. Year-to-date adjusted earnings stand at $4.40 per share against $3.76.
Strip out the weather and the demand picture is still the strongest in the company’s recent history. Weather-normalized retail electric sales rose 3.5 percent in the quarter and 2.7 percent year to date — the highest growth in recent history, per management. Commercial sales rose 7.3 percent in the quarter, led by data centers. Residential sales were bolstered by customer growth — 45,000 new customers since the third quarter of 2025 — and industrial sales grew across eight of the company’s top ten customer segments.
The contract book: 21 GW signed, 4 GW in a single quarter
The contract book is where the quarter turns from a good three months into a decade-long obligation. Southern’s signed large-load contracts reached about 21 gigawatts across 33 projects, up 4 gigawatts since the second-quarter call — roughly 2 gigawatts each at Alabama Power and Georgia Power. Georgia Power holds the bulk, about 14.5 gigawatts; Alabama Power holds about 5.5 gigawatts and Mississippi Power about 0.5 gigawatts. Another 7 gigawatts sits in late-stage or finalizing discussions, and the prospective pipeline beyond that exceeds 75 gigawatts across more than 100 projects. Eight gigawatts of projects advanced to the next stage during the quarter.
The composition matters as much as the total. Seventeen of the 21 gigawatts were contracted after the second quarter of 2025, under the large-load rules the Georgia Public Service Commission revised in April 2025 in docket 44280, and those newer contracts carry a 17-year weighted-average length, with minimum terms of at least 15 years for data centers. More than 16 gigawatts of contracted projects have begun construction, and 31 of the 33 contracted projects — 94 percent — have broken ground and are under way. This is not a queue of paper reservations. It is, for the most part, construction already in progress.
But a contract is a promise to take service, not service itself, and Southern’s own ramp chart makes the distinction visible. The company’s schedule puts contracted load at roughly 11 gigawatts by 2028 and about 17 gigawatts by 2030, with the full 21 gigawatts arriving only in the mid-2030s. That means roughly half the signed book is still years from drawing power — and so, in most cases, is the generation, transmission, and gas capacity to serve it. The question is not whether the load is real. It is whether the two ramps — the customers’ and the grid’s — arrive in the same years.
What the contracts actually guarantee
Southern’s answer to that question is contractual, and the terms are the most protective in the industry’s current wave of large-load deals. The contracts carry minimum bills negotiated to cover at least 100 percent of the annual incremental costs of serving the customer, decoupled from how much electricity the customer actually uses. Termination payments are tied to the remaining incremental costs of serving the customer over the life of the contract, and collateral requirements are tied to the termination payment and the customer’s creditworthiness. By 2030, Southern expects about $25 billion of collateral to be required from large-load customers, whose average credit rating is AA-.
That structure is the point. A minimum bill that covers the full incremental cost means a customer that signs for capacity pays for it whether or not it uses every megawatt — which is what lets a utility finance generation for load that does not yet exist at full scale. It is the same logic Evergy’s Large Load Power Service tariff applies in Kansas and Missouri, and it is the reason Southern can describe its contracted book as adding certainty to its outlook rather than risk to it. The protection is financial, not physical: it guarantees the money to build the grid, not that the grid will be built on time.
The buildout: an $85 billion plan that could approach $100 billion
The money, in any case, is getting bigger. Southern’s base five-year capital plan stands at $81 billion. Management identified about $4 billion of additional investment beyond that base — generation upgrades, nuclear capacity enhancements, and pipeline expansion — bringing the identified plan to about $85 billion. Additional opportunities, including generation being sought through requests for proposals in Alabama and Georgia, could push the five-year plan toward $100 billion.
The unit economics explain why the number grows so fast. Southern puts the cost of company-owned generation at more than $2 billion for every gigawatt. At that rate, the identified $4 billion increment buys roughly two gigawatts of new generation — against a contract book of 21 gigawatts. The rest of the capacity has to come from somewhere else: uprates, purchases, and the requests for proposals now under way.
What the $4 billion does buy is specific, and mostly fast. About 400 megawatts of gas uprates at four units in Alabama and Georgia, projected in service in 2029 and 2030. About 96 megawatts of nuclear uprates at Vogtle Units 1 and 2 and Hatch Units 1 and 2, projected in service from 2028 through 2031, including a nuclear uprate partnership with Google at Georgia Power. Up to 300 megawatts of additional uprate opportunities on the existing gas fleet through 2030. And the Southeast Connector pipeline expansion at Southern Natural Gas, projected in service in 2030 to 2032. Beyond that, the plan contemplates brownfield gas generation at six existing sites, or greenfield gas outside the Southeast.
Read that list against the ramp, and the timing tension is plain. The uprates land between 2028 and 2031. The new generation from the Alabama and Georgia requests for proposals is aimed at the early 2030s. The contracted load reaches 11 gigawatts by 2028 and 17 gigawatts by 2030. Uprates and pipeline expansions are the bridge; the question is whether a bridge built of incremental megawatts carries a load that grows by gigawatts a year. Southern projects electric sales growth of about 10 percent from 2026 to 2030 and state-regulated rate-base growth of 9 percent — but those are projections, and the February refresh is where they will be tested.
The peers: AEP has already crossed $100 billion
Southern is not the only utility watching its contract book outrun its construction schedule, and the peer comparison sharpens the picture. American Electric Power reported on October 28 that it had signed 15 gigawatts of new load commitments in the third quarter alone, taking its incremental contracted load to 84 gigawatts by 2031 — of which 35 gigawatts is backed by firm take-or-pay electric service agreements. AEP simultaneously announced a $100 billion five-year capital plan through 2031, with rate base expected to nearly double, from $87 billion in 2026 to $162 billion by 2031. AEP has crossed the line Southern is approaching: its $100 billion is announced, not potential.
Dominion Energy offers the other side of the comparison — what happens when the pipeline is measured honestly. Dominion’s Virginia data-center pipeline stood at about 54.9 gigawatts in September, up 6.3 gigawatts, or 13 percent, from December 2025. But only 12.2 gigawatts of that sits under the firm’s contracts that oblige customers to pay whether or not they use the power; 32.8 gigawatts sits under engineering letters of authorization, where Dominion does detailed engineering work and the customer reimburses the cost. Actual billed data-center peak load was 4.8 gigawatts as of August. In a presentation to PJM in September, Dominion left 19 gigawatts — 59 percent — of its earliest-stage agreements out of its forecast entirely. And in its February filing with Virginia regulators, Dominion described roughly 70 gigawatts of delivery-point requests in its queue, with about 25 gigawatts being processed for connection dates through 2031, against an all-time system peak of 24,678 megawatts.
The three companies, taken together, describe the same market three different ways. AEP counts 84 gigawatts of contracted load and has a $100 billion plan to serve it. Dominion counts 54.9 gigawatts of pipeline and treats most of it as too uncertain to forecast. Southern counts 21 gigawatts signed and 7 gigawatts late-stage, with the money to serve them still partly unidentified. All three books are real and all three are incomplete — and the ramp schedule, not the headline total, is the number that tells you when the power has to be there.
The regulator just changed
There is one more variable in Southern’s outlook, and it arrived two days before the earnings call. On November 3, Georgia voters elected Democrats Peter Hubbard and Shelia Edwards to the Georgia Public Service Commission, giving Democrats a 3-2 majority on the five-member body starting in January — the first time the party has controlled the regulator in about 30 years. The commission regulates Georgia Power, which holds the largest share of Southern’s contract book, and it will rule on the generation requests for proposals, the rate cases, and the cost-allocation questions that decide who pays for the buildout.
Affordability and rising bills were the driving issues in the campaign, and the new majority takes over a utility whose growth now runs through large load. What the change does mean is that the assumptions underneath Southern’s plan — that minimum bills and collateral will keep existing customers whole, that the commission will approve the generation the contracts require — will now be tested by a regulator with a different mandate and a different political base. The old 3-2 Republican majority remains in place through December 31. The February outlook refresh will be the first one presented to a commission that has already changed hands.
The economic development backdrop, meanwhile, keeps strengthening Southern’s hand. Twenty-six companies announced plans to locate or expand in Southern’s territory in the third quarter, representing about $25 billion of announced capital investment — a new quarterly record. Audi announced its first U.S. manufacturing facility, a $4 billion Georgia mega-site designed to produce up to 200,000 vehicles a year with 4,500 jobs. The deck also lists an OpenAI data center at Rincon, Georgia, among the quarter’s announcements.
What to watch
The milestones, in order: the February outlook refresh through 2031, which will show whether the $100 billion figure becomes a plan; the outcomes of the Alabama and Georgia generation requests for proposals, which will show what new capacity actually gets built and when; the conversion of the 7 gigawatts in late-stage discussions into signed contracts; the new Georgia commission’s first decisions on Georgia Power’s filings in 2027; and the in-service dates for the gas and nuclear uprates, the first real test of whether the bridge arrives before the load does.
The financing underneath it all is in good shape, for now. Southern has settled all $5.3 billion of its forward-priced equity, leaving about $2 billion of equity to be addressed through 2030, funded at roughly 40 percent equity for incremental capital. Management reaffirmed its target of a 17 percent funds-from-operations-to-debt ratio by 2029.
The bottom line
Southern’s third quarter delivered the sharpest evidence yet that data-center demand in the Southeast is not a forecast but a fact: usage up 59 percent in the quarter, commercial sales up 7.3 percent, weather-normalized sales growth at the highest level in recent history. The contract book behind it — 21 gigawatts signed, 7 gigawatts late-stage, more than 75 gigawatts prospective — is written so the customers pay for the grid they require.
What the quarter did not deliver is proof that the grid can keep up. The ramp says half the signed book arrives by 2028 and most of it by 2030; the buildout says the new generation arrives in the early 2030s, bridged by uprates and pipeline expansions. Southern’s minimum bills guarantee the money. They do not guarantee the megawatts. The next two years — the February refresh, the requests for proposals, the new Georgia commission — will show whether the Southeast’s buildout pace is a plan or a hope.