Data Center Load Arrives, But Five of the Nine Cents Came From Construction Accounting

Results vs. Consensus

Q1 2026 Scorecard

Consensus for adjusted EPS is $1.21 on two independent providers. A third widely syndicated figure of $1.23 is the prior-year adjusted result rather than a forecast, and the 7.3% "surprise" it produces is the year-over-year growth rate. Revenue consensus ranged from $8.07 billion to $8.10 billion, so the beat is 3.7% to 4.0% depending on the provider.

Year-Over-Year Comparisons

The derived rows are computed from the income statement and the non-GAAP reconciliation in the same release. Operating income excluding the repowering charge adds back the pre-tax accelerated depreciation of $154 million in 2026 and $26 million in 2025.

Quarter-Over-Quarter Comparisons

Sequential comparisons for a vertically integrated regulated utility are seasonal artifacts and should be read as such. The fourth quarter carries the year's heaviest non-fuel operations and maintenance spend, planned outages and vegetation management, while the first quarter carries winter heating load. The one sequential line that is not seasonal is interest expense, which fell $117 million from the fourth quarter. That is the first visible benefit of the redemption of junior subordinated notes, the same transaction that produced the one cent of debt-extinguishment cost added back to adjusted earnings this quarter.

Quality of Beat

Segment Performance

Segment revenues do not sum to the consolidated total because intercompany sales, principally Southern Power's wholesale sales into the regulated system, are eliminated in consolidation. Segment net income is as reported and includes the repowering charge at Southern Power. Earnings before income taxes for the consolidated entity were $1,566 million against $1,550 million, an increase of 1.0%.

Traditional Electric Operating Companies

The regulated electric business earned $1,113 million against $1,026 million, an 8.5% increase and the segment that carried the quarter. Alabama Power was the standout, converting 4.0% revenue growth into 13.3% earnings growth, with earnings before income taxes up 14.0%. Georgia Power grew revenue 3.5% and earnings 5.4%, a narrower spread that reflects both the larger construction program and the rate freeze in place there. Mississippi Power posted the fastest revenue growth of the three at 12.4% off the smallest base.

Underneath the segment result, the composition is unusual. Retail electric revenues in aggregate rose only $39 million, all of it in the fuel line, which is a pass-through recovered through separate fuel clauses and carries no margin. Non-fuel retail revenue, the line the regulated return is actually earned on, was $3,384 million in both periods. Every dollar of top-line growth in the electric business came from wholesale, which rose 29.7%, and other electric revenues, which rose 9.5%.

"First quarter weather-normal retail electricity sales to all classes were 2.3% higher than 2025. This represents the highest total retail sales growth that we have seen in the first quarter in recent history." — David P. Poroch, Chief Financial Officer

Assessment: The demand claim is correct and the revenue claim it implies is not yet true. Weather-normal retail sales grew 2.3%, but actual retail kilowatt-hour sales grew 0.4% because the winter was mild, and base rates are frozen. That combination is why a quarter with the best first-quarter volume growth in recent history produced zero growth in non-fuel retail revenue. The load is arriving in advance of the ability to bill for it at a higher rate base, which is the intended sequence but is also the reason the earnings did not follow the volumes this quarter.

Southern Power

Southern Power grew revenue 20.1% to $681 million and reported net income of $4 million against $87 million, a 95.4% decline, with a pre-tax loss of $84 million against pre-tax income of $22 million. The entire swing is the accelerated depreciation associated with repowering certain wind facilities: $154 million pre-tax this quarter against $26 million in the prior-year quarter. Adding back the after-tax charge disclosed in the release, $120 million in 2026 and $20 million in 2025, both net of noncontrolling interest effects, lifts the segment's contribution to roughly $124 million from roughly $107 million, an increase of about 16% and worth the one cent the company's bridge assigns to it.

The forward-looking business at Southern Power is more interesting than the reported number. The company announced 400 megawatts of natural gas turbine uprates at existing Alabama and Georgia facilities, commercial operation projected between 2029 and 2031, adding approximately $700 million to the capital plan, with construction starting this year. A further 300 megawatts of uprates is under evaluation. Contracted capacity sits in the mid-90s percent, and management was explicit that the model has not changed.

"And we have said before, we do not take merchant risk. We are not in the merchant business." — Christopher C. Womack, Chairman, President and Chief Executive Officer

Assessment: The uprate program is the cheapest incremental capacity available to the company and the discipline around counterparty credit is a genuine differentiator against merchant developers competing for the same load. The reported segment result is noise created by an accounting choice; the segment's real problem is that the repowering charge has roughly $335 million of 2026 and $100 million of 2027 still to run, which keeps a widening gap between GAAP and adjusted earnings open for another seven quarters.

Southern Company Gas

The gas utilities grew revenue 19.1% to $2,191 million and net income 6.9% to $447 million, contributing three cents. The gap between those two growth rates is the story: cost of natural gas rose 37.4% to $926 million, so revenue net of gas cost rose 8.6%, not 19.1%. Commodity moves through the top line and out again through purchased gas adjustment mechanisms, and roughly two-thirds of the reported revenue growth in this segment is that pass-through. Customer count grew 0.5% to 4,437 thousand. The segment also absorbed a $2 million estimated loss on Nicor Gas capital investments disallowed by the Illinois Commerce Commission in November 2025, immaterial this quarter but an open item the company flags as possibly recurring.

Assessment: A 19.1% revenue line that produces 6.9% earnings growth is a reminder that headline growth at this segment says more about the gas curve than about the business. The underlying result, high single-digit margin and earnings growth on half a point of customer growth, is a normal good quarter for a rate-regulated gas distributor and is what should be modelled forward. The Illinois disallowance is small but is the one place in the portfolio where a regulator has taken capital away rather than allowed it.

Load and Customer Metrics

Assessment: Three things stand out. Commercial is the growth class, up 4.6% weather-adjusted, and the company attributes that to data centers, whose usage rose 42%. Residential volumes fell 4.1% on weather but grew 0.9% weather-adjusted on 46,000 net customer additions, so the in-migration story is intact but small relative to the commercial ramp. And wholesale, at 12.9%, grew three times as fast as any retail class, which is consistent with the revenue mix and with Southern Power selling more into a tight regional market.

Key Topics & Management Commentary

Overall Management Tone: Assured and heavily scripted, with the prepared remarks organized entirely around load growth, contract structure and financing rather than around the quarter's results. Management answered every question about demand with specifics and every question about earnings composition with framework-level language, which is a reasonable allocation given that the demand narrative is what moves the stock, but it left the flat operating income and the flat non-fuel retail revenue line entirely undiscussed. The one place the posture softened was new nuclear, where a direct question drew enthusiasm for the industry and an explicit refusal to commit the company.

1. Five of the Nine Cents Came From Construction Accounting

Allowance for equity funds used during construction rose to $121 million from $73 million, an increase of 65.8%, and the company's own earnings bridge assigns it five cents of the nine-cent adjusted EPS increase. This item is the equity portion of the regulated return a utility is permitted to accrue on construction work in progress before a plant enters service. It is non-cash, it is recovered later through rates once the asset goes into service, and it scales with the size of the construction balance rather than with anything happening in the operating business.

Southern is deploying an $81 billion capital plan across 2026 to 2030, so a rising construction allowance is the mechanical and entirely expected consequence. The point is not that the accrual is improper. The point is what it says about the composition of the growth: in a quarter where weather-normal retail sales grew at the fastest first-quarter rate in recent history, more than half the adjusted earnings increase came from an accounting return on plant that is not yet serving customers.

Assessment: This is the single most important line in the quarter and it went unmentioned in the prepared remarks and unasked in Q&A. It is not a red flag on its own, but it changes what the 7.3% adjusted EPS growth means. A construction-allowance-driven quarter converts to cash and to sustainable earnings only when those assets enter service and enter rate base, which for the bulk of the 10 gigawatt generation portfolio is 2026 through the early 2030s. Until then, the accrual is a claim on future rate recovery, not a current operating result.

2. Non-Fuel Retail Revenue Did Not Grow

Retail electric revenue excluding fuel was $3,384 million this quarter and $3,384 million a year ago. That is the line on which the regulated electric business earns its authorized return, and it did not move. Two things explain it. Actual retail kilowatt-hour sales rose only 0.4% because the winter was milder than the prior year, costing five cents of EPS. And base rates are frozen: Georgia through 2028 and Alabama through 2029, commitments management made in late 2025 and reiterated on this call as a customer-protection measure.

"That gives us the opportunity for rate stability and freezes in Georgia through 2028 and in Alabama through 2029." — Christopher C. Womack, Chairman, President and Chief Executive Officer

The freeze is presented as a strength, and in political terms it is. The two Georgia Public Service Commission seats up for election this year, and the affordability debate around data centers running through that campaign, are exactly the risk the freeze is designed to neutralize. But a freeze on base rates during a five-year period in which the company intends to spend $81 billion means rate base grows without a corresponding reset in the revenue requirement until the next general rate case.

Assessment: The freeze buys regulatory goodwill at the cost of earned return in the interim, and the flat non-fuel retail revenue line is that cost showing up in the numbers for the first time. The company's answer is that large-load contracts carry their own pricing outside base rates, that riders and fuel clauses handle the rest, and that the construction allowance accrues in the meantime. That is a coherent answer. It is also a description of earnings deferred rather than earnings earned, and it needs the 2029 rate case to land well.

3. The Non-GAAP Wedge Widened From Two Cents to Eleven

GAAP basic EPS was $1.21 in both quarters. Adjusted EPS was $1.32 against $1.23. The eleven-cent gap in the current quarter, against two cents a year ago, is almost entirely the accelerated depreciation associated with repowering certain wind facilities at Southern Power: $154 million pre-tax and $120 million after tax this quarter, against $26 million pre-tax and $20 million after tax last year.

The release is unusually transparent about what remains. Roughly $335 million of additional pre-tax accelerated depreciation is projected in 2026 and $100 million in 2027, with the repowering projects completing through the third quarter of 2027. That is a guided, recurring, multi-year add-back rather than a one-time charge.

The arithmetic underneath is worth stating separately. Reported depreciation and amortization rose $134 million, and $128 million of that increase is the year-over-year change in the repowering charge alone. Excluding it, depreciation rose $6 million, or 0.5%, at a company running an $81 billion capital plan.

Assessment: Adding back depreciation on assets a company has chosen to replace is a defensible non-GAAP treatment and the disclosure is good. But an add-back with seven more quarters to run, sized at roughly $435 million of remaining pre-tax charges, is a structural feature of the earnings presentation rather than an adjustment for an unusual item. The 0.5% underlying depreciation growth is the more curious figure and deserves an explanation the call did not provide.

4. Data Center Usage Rose 42% and Showed Up in the Volume Data

"Data center usage saw material expansion in the quarter, up 42% year over year, primarily due to accelerating usage ramps at large load facilities." — David P. Poroch, Chief Financial Officer

Commercial kilowatt-hour sales rose 4.2% as reported and 4.6% weather-adjusted, the fastest of any retail class, and management attributed the acceleration directly to data centers. Weather-normal retail sales across all three classes rose 2.3%, which the CFO characterized as the highest first-quarter total retail sales growth in recent history. Residential added 46,000 net customers on continued in-migration. Industrial grew 1.5%, with strength called out at multiple steel manufacturers in Alabama.

This is the first quarter in which the large-load thesis is visible in the volume tables rather than only in the contracted-gigawatt disclosures. The 42% growth is off a small base, and total retail volumes still grew only 0.4% on an actual basis, but the direction and the composition are what the investment case requires.

Assessment: Confirmatory for the thesis and the most important operational datapoint in the release. The caveat is timing rather than direction: usage ramps are converting into kilowatt-hours faster than they are converting into non-fuel retail revenue, because of the rate freeze and because minimum-bill structures recover cost rather than generate margin uplift in the early ramp. Expect the volume line to lead the revenue line by several quarters, and do not read 42% usage growth as a near-term earnings driver.

5. The Large-Load Funnel: 11 GW Contracted, 12 GW Late-Stage, 75 GW Pipeline

"The demand for power across our electric service territories has culminated in 23 gigawatts of contracted or late-stage load." — Christopher C. Womack, Chairman, President and Chief Executive Officer

The two Georgia Power projects signed in the prior two months were described as high credit quality hyperscalers. Management also disclosed that roughly half the late-stage 12 gigawatts is expected to convert to executed contracts in the near term, which if it happens takes contracted load toward 17 gigawatts.

Assessment: The conversion rate through the funnel is the number that matters and the company is now disclosing enough to track it. The 75 gigawatt pipeline figure has not moved even as 12 gigawatts advanced a stage, which management framed as replenishment. Treat the pipeline as a marketing figure and the contracted and late-stage numbers as the real disclosure. On that basis the progression from roughly 9 gigawatts to more than 11 in two months is the strongest evidence in the release.

6. Minimum Bills and the "Full Share" Construct

"These bilaterally negotiated agreements are structured so that customers driving incremental demand cover the full share of the cost to serve them, helping to assure this growth benefits all customers." — Christopher C. Womack, Chairman, President and Chief Executive Officer

Management drew a deliberate distinction on the call between "incremental" cost and "full" cost, arguing that Southern's contracts price to the latter. The CFO described the mechanism in terms of what the utility is not exposed to.

"A differentiating factor in our contracts is the minimum bill established within the contract, designed to recover all of the costs introduced into the system, like Chris said. We are not held captive to a variable pricing methodology to recover those costs." — David P. Poroch, Chief Financial Officer

The contracts also carry collateral, cancellation fees and minimum bills, and the CFO noted separately that the collateral requirement in Georgia is what is filtering speculative interest out of the funnel. That is a genuinely differentiated structure against utilities that have signed large-load agreements on variable-volume tariffs and are exposed if the hyperscaler's ramp disappoints.

Assessment: This is the strongest part of the investment case and it is under-discussed relative to the gigawatt counts. If the ramps disappoint, Southern still recovers its cost of service; the shareholder is short an option on the upside rather than long the ramp risk. What the company will not disclose is the level of the minimum bill in dollars or as a share of contracted revenue, so the protection cannot be sized from outside. The structure is credible on management's description and unverifiable on the filings.

7. The $26.5 Billion DOE Loan Package

"Over the approximately 30-year term of the DOE loans, this lower-cost financing is projected to generate cumulative savings of $7 billion for customers." — Christopher C. Womack, Chairman, President and Chief Executive Officer

The $26.5 billion of loan agreements with the Department of Energy, covering Alabama and Georgia, is the largest single financing item in the story and management framed it in customer-savings terms rather than in shareholder terms. The shareholder benefit is stated obliquely: the loans reduce pressure on capital market needs. The CFO put it more directly under questioning, saying the loans take care of capital markets needs for at least the foreseeable future and help with liquidity.

Assessment: Materially de-risks the financing side of an $81 billion plan and is the reason the residual equity need is only $1.8 billion through 2030. The customer-savings framing is the right political posture in an election year in Georgia. The unstated shareholder consequence is that displacing $26.5 billion of utility debt with subsidized 30-year money at the operating companies improves the credit path toward the 17% funds-from-operations-to-debt target without additional equity, which is where the value accrues.

8. Financing: $500 Million of Forward Equity and a 40% Rule of Thumb

"Over the last quarter, we sourced an incremental $500 million of equity through our at-the-market, or ATM, program with forward contracts that settle at our discretion by 2028." — David P. Poroch, Chief Financial Officer

Remaining equity or equity-equivalent need is $1.8 billion through 2030, inclusive of the incremental $700 million of Southern Power capital announced on this call. The company is targeting 17% funds from operations to debt by 2029. And under questioning the CFO gave the forward-looking funding convention explicitly.

"It is a good rule of thumb to continue to expect about 40% of incremental capital to be funded through equity." — David P. Poroch, Chief Financial Officer

Average shares outstanding rose 2.2% year over year, from 1,100 million to 1,124 million, and the company's own bridge charges three cents of the quarter's EPS to that dilution. Against a nine-cent gross increase, share issuance consumed a third of the underlying growth.

Assessment: The 40% convention is the most useful modelling disclosure on the call and it cuts against the upside case. Every incremental gigawatt of company-owned generation that comes out of the Georgia request for proposals carries roughly $2 billion of capital and therefore roughly $800 million of equity. Growth that is 40% equity-funded is growth that dilutes per-share results by construction, which is why the long-term objective is 7% to 8% adjusted EPS growth on a rate base growing considerably faster.

9. The Georgia All-Source RFP and Capital Not Yet in the Plan

Georgia Power initiated the regulatory process for an all-source request for proposals to procure 2 to 6 gigawatts of new dispatchable generation for service in 2032 and 2033, spanning thermal generation, battery storage and renewables. Selection runs through the remainder of 2026, certification through 2027, and spending would begin around 2028. The CFO offered a sizing convention.

"it is probably a decent rule of thumb that maybe a gigawatt of company-owned resources might be $2-plus billion of incremental CapEx in the latter part of the planning horizon and into the next decade." — David P. Poroch, Chief Financial Officer

At that rate, if company-owned resources win a meaningful share of a 2 to 6 gigawatt procurement, the incremental capital is $4 billion to $12 billion above the $81 billion base plan. The chief executive was blunt about the timeline for knowing.

"You are going to have to hold your breath until the end of the year before we get through that process." — Christopher C. Womack, Chairman, President and Chief Executive Officer

Assessment: Real optionality, correctly sized, and appropriately not yet in the plan. But the cash flows land 2032 and beyond, the capital is 40% equity-funded, and the company competes against independent power producers in its own procurement. Discounted back, a $4 billion to $12 billion capital opportunity beginning in 2028 is worth less to a 2026 valuation than the headline gigawatts suggest. This is a reason to own the story over a decade, not a reason to pay 21 times forward earnings today.

10. Southern Power Uprates: The Cheapest Megawatts Available

The company is adding 400 megawatts through natural gas turbine upgrades at existing Alabama and Georgia facilities, commercial operation 2029 through 2031, at approximately $700 million of capital. Construction begins in 2026. A further 300 megawatts is under evaluation, and management said the two together would cover essentially the whole Southern Power fleet's uprate potential. The 400 megawatts is in late-stage contracting discussions and management expects it contracted by the time it is built.

An analyst noted that the implied cost per kilowatt is close to what a new combustion turbine would cost, which the company did not dispute. The counterargument management made is not about price but about counterparty and risk profile: creditworthy load-serving entities, no merchant exposure, and construction at existing sites with existing interconnection.

Assessment: Incrementally positive and correctly disciplined, but small. $700 million against an $81 billion plan is nine-tenths of a percent, and it lands in 2029 through 2031. The more useful signal is what it says about how tight regional capacity is: uprating existing turbines at close to new-build economics is a decision that only makes sense when time to power is the binding constraint.

11. The Dividend: 25 Consecutive Increases

"This action marks our 25th consecutive annual increase, and this will now be 79 consecutive years dating back to 1948 that The Southern Company has paid a dividend that is equal to or greater than the previous year." — Christopher C. Womack, Chairman, President and Chief Executive Officer

The board approved an eight-cent increase to the annual common dividend the week before the call, raising the annualized rate to $3.04 per share. At the $96.70 close that is a 3.1% yield, against 3.3% at the $93.51 pre-print close. Against the FY2026 adjusted EPS guidance midpoint of $4.55, the payout ratio is roughly 67%.

Assessment: The streak reaching 25 years qualifies the shares for a broader set of dividend-growth mandates, which is a real if unquantifiable support for the multiple. The more relevant fact for a new position is that the yield has compressed to 3.1%, which is no longer a distinguishing feature against the sector or against fixed income. A utility bought for income at 3.1% is being bought for growth, and the growth is guided at 7% to 8% with a first quarter in which operating income rose 0.4%.

12. New Nuclear: Enthusiasm Without Commitment

The first question of the call asked whether Southern would join an emerging consortium of utilities and hyperscalers building AP1000 reactors with a possible federal backstop. Southern is the only US utility to have completed a new AP1000 pair, at Vogtle Units 3 and 4, which makes its answer the most informed in the industry and its refusal the most consequential.

"The Southern Company is not at a place to make a commitment about building a new unit." — Christopher C. Womack, Chairman, President and Chief Executive Officer

Management was enthusiastic about the industry-level developments, praised the regulatory steps taken by the administration, and offered to keep sharing the Vogtle experience with others. It declined to say anything about Southern's own participation beyond that.

Assessment: The right answer for shareholders and a meaningful signal for the sector. The company that lived through Vogtle's cost and schedule overruns is not putting its balance sheet back into new nuclear even with hyperscaler cost-sharing and federal support on the table. Read alongside the 10 gigawatts of gas and storage already under construction and a 2 to 6 gigawatt dispatchable request for proposals, the message is that Southern will meet this demand cycle with gas and batteries. That removes a tail risk from the story and also removes an optionality some bulls have been assigning to it.

Guidance & Outlook

The full-year range was not changed despite an adjusted result twelve cents above the company's own first-quarter estimate. That is consistent with how Southern has historically handled a first-quarter beat, and it is also the appropriate posture when five of the nine cents of year-over-year growth came from a construction accrual and when the weather comparison for the balance of the year is unknown.

Implied second-half ramp: First-half 2026 adjusted EPS is tracking to $2.32, the $1.32 actual plus the $1.00 second-quarter estimate, against $2.15 in the first half of 2025, growth of 7.9%. Second-half 2025 adjusted EPS was $2.15. The full-year midpoint of $4.55 therefore implies second-half adjusted EPS of $2.23, growth of 3.7%. The top of the range implies $2.28 and 6.0%; the bottom implies $2.18 and 1.4%.

Street at: Street consensus stood at $4.55 when the range was set in February, precisely at the midpoint, and no revision was invited by this print. The second-quarter estimate of $1.00 is 8.7% above the $0.92 adjusted result in the second quarter of 2025, so the guided deceleration is entirely a second-half phenomenon.

Guidance style: Conservative and pattern-consistent. Southern set the range in February, beat its own internal first-quarter estimate by twelve cents, and left the range alone. On the historical pattern the company lands in the upper half of a range it has not moved, which argues the second-half deceleration embedded in the midpoint is guidance conservatism rather than a forecast. It is worth noting that the phrase management used about being "focused on getting to the top of the range" came in response to a question about the load plan, not the earnings range, and should not be read as an EPS signal.

Analyst Q&A Highlights

Whether Southern Joins the AP1000 Consortium

The first question of the call went straight to new nuclear, citing an emerging consortium of utilities and hyperscalers with a possible federal backstop, and the suggestion that hyperscalers might absorb cost-inflation risk above budget. The company that built the only new AP1000 pair in the United States gave an enthusiastic answer about the industry and a flat refusal about itself, and volunteered to keep sharing the Vogtle experience with others rather than deploy its own balance sheet.

Q: "On new nuclear, there seems to be a consortium that has formed with utilities and hyperscalers, maybe with some backstop by the U.S. government around new AP1000s. It seems like there could be some views that hyperscalers would be willing to take on some of the cost inflation risk above budgeted amounts. ... Can you comment on your view? Is The Southern Company interested? Are you in the consortium?"
— Shahriar Pourreza, Wells Fargo

A: "As you know, I have said before, The Southern Company is not at a place to make a commitment about building a new unit. We are going to continue to share the experiences that we gained from Vogtle Units 3 and 4 here in this country and other places with other companies that are interested in moving forward."
— Christopher C. Womack, Chairman, President and Chief Executive Officer

Assessment: The clearest answer on the call and the most informative. A management team with direct AP1000 construction experience, facing hyperscaler cost-sharing and federal support, is still not willing to commit. That is a judgment about new nuclear economics from the only party in the industry that has actually finished one, and it should carry more weight than any of the enthusiasm expressed elsewhere on the same call. For shareholders it removes a tail risk; for anyone valuing Southern on nuclear optionality, it removes the option.

Whether Load Progress Can Buy Another Rate Stay-Out

A recurring line of questioning probed whether faster-than-planned load conversion changes the regulatory calendar, specifically whether the company would extend the rate stay-outs it committed to in late 2025. Management redirected the question from filing strategy to rate stability, and pointed at contract structure as the mechanism that makes the stay-out affordable. The follow-up asked directly whether load visibility was running ahead of plan.

Q: "When I take a step back, you committed to these stay-outs late last year, and since then you have been making notable progress both on load visibility and usage ramps. ... Are you ahead of plan on the load, and can that crystallize a further stay-out for customers?"
— Nicholas Campanella, Barclays

A: "The focus for us is more about rate stability. As we have structured these contracts with large loads—to make sure they pay their full share, with collateral, cancellation fees, minimum bills, and all the terms we are contracting—that gives us protection and supports our ability to make sure we are protecting existing customers. That gives us the opportunity for rate stability and freezes in Georgia through 2028 and in Alabama through 2029."
— Christopher C. Womack, Chairman, President and Chief Executive Officer

Assessment: The answer to "are you ahead of plan" was "we are in line," which is a more disciplined response than the load disclosures would have permitted. The substantive content is the confirmation that the stay-out logic runs through the large-load contracts: the incremental customer pays full cost, which is what makes freezing base rates for everyone else affordable. The unanswered half is what a further extension would do to earned return, given that non-fuel retail revenue is already flat.

Whether the Cumulative Bill Credits Get Revised Higher

Affordability was the second theme of the call, and one exchange pressed on whether the customer-benefit figure the company has been citing is a floor rather than a snapshot, given that contracted load has kept rising since it was struck. Management declined to pre-empt its regulators but pointed at two live Georgia proceedings as the vehicles.

Q: "You have $8.85 billion of cumulative bill credits you have been talking about. Is there a chance that that number gets revised higher as you see this contracted large load number head higher?"
— Julien Dumoulin-Smith, Jefferies

A: "Julian, we do not get ahead of our regulators, first of all. But clearly, as we continue to deliver these contracts in terms of how they are structured, and as we have signaled—Georgia Power is in the middle of storm recovery proceedings along with fuel recovery processes—those proceedings can provide benefits and lower bills for customers."
— Christopher C. Womack, Chairman, President and Chief Executive Officer

Assessment: A soft yes. The company will not put a number on it before the regulators do, but it named the two proceedings through which the number would move, and it has already filed to lower rates in Georgia in connection with fuel and storm cost recovery. The strategic logic is consistent: give the affordability benefit back visibly and early, in an election year, in exchange for the political license to keep spending.

The Apparent Softening in the Georgia Large-Load Report

The most pointed question of the call flagged an apparent contradiction: the corporate funnel keeps growing, but Georgia Power's own fourth-quarter regulatory filing on large-load economic development showed contracted commitments moving the other way. Management attributed part of it to timing and geographic migration toward Alabama, then the chief financial officer reframed the discrepancy as a feature of the collateral requirement.

Q: "But if I look at the 4Q 2025 Georgia Power large load economic development report, it shows some degree of softening in contracted commitments. Is there something about Georgia versus your other states, like Alabama, where other states are accelerating to offset Georgia?"
— Julien Dumoulin-Smith, Jefferies

A: "Julian, one thing to think about as well are the rules under which we are negotiating these contracts in Georgia and the need for these potential customers to demonstrate their commitment by posting collateral. That is really shaking a lot of the potentials out that are more speculative in nature and leaving Georgia Power to work with a high-quality portfolio of potential customers with which we are choosing to contract. What you are seeing is a refinement of that, not a degradation."
— David P. Poroch, Chief Financial Officer

Assessment: The best answer management gave all quarter, and it is probably right. A collateral requirement that removes speculative interest should show up as a decline in a filing that counts commitments, while the contracted number rises. But the reconciliation is asserted rather than shown, and it is the kind of discrepancy that only resolves with several more quarters of both disclosures moving in the stated directions. The chief executive's separate line that "there is some churn in Georgia" is a more candid framing than the funnel chart conveys.

What Happens When Ramps Exceed the Minimum Bill

A question on affordability mechanics asked what the customer-rate consequence is if hyperscaler ramps run above the contracted minimum bill, and when that conversation happens with regulators. The chief executive first corrected the premise, distinguishing "incremental" cost recovery from "full" cost recovery, before the chief financial officer described the structure in terms of the exposure the utility does not carry.

Q: "Can you talk about the fact that you are pricing these so minimum bills cover the incremental cost to serve? To the extent the ramps exceed minimum bills and come close to what is projected by hyperscalers, what does that mean for customer rates, and what is the timeline to discuss that with regulators?"
— Stephen D'Ambrisi, RBC

A: "A differentiating factor in our contracts is the minimum bill established within the contract, designed to recover all of the costs introduced into the system, like Chris said. We are not held captive to a variable pricing methodology to recover those costs."
— David P. Poroch, Chief Financial Officer

Assessment: The correction from "incremental" to "full" is the whole argument and management made it deliberately, twice. If it holds contractually, the shareholder is not exposed to a ramp shortfall and existing customers are not cross-subsidizing. It is the most valuable structural claim in the story and the least verifiable from outside, because neither the minimum-bill level nor its share of contracted revenue is disclosed anywhere.

Timing of the RFP Outcome and the Capital Plan Update

Questions on the Georgia all-source procurement focused on when investors get a number rather than on the merits of the process. The answer was a full calendar: selection through the remainder of 2026, certification through 2027, spending from roughly 2028, plant in service 2032 and 2033.

Q: "What would be the timing of when the process is completed and when you would have visibility into the company-owned resources, and therefore when we might see the CapEx update? You said it could be substantial incremental investment."
— Andrew Weisel, Scotiabank

A: "We will go through the selection process through the rest of this year, and that will lead to a certification process that will take us pretty much through 2027. To the extent that we work through that process and any of our proposals are selected, that would lead toward initiating spend probably in 2028, with deliveries in 2032–2033."
— David P. Poroch, Chief Financial Officer

Assessment: A clear and appropriately unglamorous answer that puts the next hard capital-plan datapoint at year-end 2026 at the earliest. Paired with the two-billion-per-gigawatt convention offered in the same exchange, the analyst can now size the optionality without waiting: 2 to 6 gigawatts of procurement, an unknown company-owned share, roughly $2 billion of capital per gigawatt won. The discipline in refusing to pre-announce a share is welcome and also means the optionality stays unpriceable for another three quarters.

How the Incremental Capital Gets Funded

A follow-up connected the newly announced Southern Power capital to the equity plan and asked whether a further tranche of uprates would require more equity. The answer produced the most directly usable modelling disclosure of the call.

Q: "And then it looks like an incremental $300 million of equity relates to the $700 million from the Southern Power gas upgrade. What would be the timing of that? ... And if you move forward with the additional 300 megawatts, would that require additional equity, or is that included?"
— Andrew Weisel, Scotiabank

A: "On the Southern Power upgrades, yes, we are continuing along with that sort of 40% equity proportion as we grow those capital opportunities. ... It is a good rule of thumb to continue to expect about 40% of incremental capital to be funded through equity."
— David P. Poroch, Chief Financial Officer

Assessment: The single most useful number an analyst got. Forty percent equity funding on all incremental capital is the arithmetic reason a rate base compounding at a high single-digit to low double-digit rate produces a 7% to 8% earnings-per-share objective. It also means every upside scenario in this story, the request-for-proposal wins, the further uprates, the additional contracted gigawatts, arrives pre-diluted. Share count already rose 2.2% year over year and cost three cents this quarter.

Turbine and Labor Availability Against the Build Schedule

With 10 gigawatts under construction and another procurement opening, the question of whether the equipment and the workforce exist drew a notably unpolished answer, in contrast to the scripted confidence elsewhere on the call.

Q: "Wondering if you could speak to the supply chain and where you stand currently in terms of access to some of the tight areas like turbines and labor—what you are seeing there?"
— David Arcaro, Morgan Stanley

A: "In this current market, it is not anything you can take for granted. The headline would be we are very well positioned, but we cannot sleep on it. ... As we look at RFPs, we do have the turbines identified to support those RFPs."
— Christopher C. Womack, Chairman, President and Chief Executive Officer

Assessment: The most honest sentence on the call. Turbines are identified for the procurement in flight, which is the specific commitment that matters, and management referenced 10,000 peak on-site laborers during Vogtle as the basis for its labor relationships. The candour about tightness is worth more than the reassurance, and it is the correct frame for a company whose entire investment case rests on delivering plant on a schedule set by hyperscaler ramps.

The Georgia Public Service Commission Elections

Two Georgia Public Service Commission seats are up this year, and the campaign is running on data centers and affordability, precisely the two variables the investment case depends on. The question asked for a read on candidate positioning and on the local temperature around development. The answer was almost entirely institutional.

Q: "Then on Georgia, there are two seats up on the PSC for election this year. Could you provide your latest thoughts on the setup in terms of the focus areas of the candidates you have heard thus far, and any views on the latest temperature in Georgia around affordability and development?"
— Carly Davenport, Goldman Sachs

A: "As you know, the primary election is in May. If there are runoffs, they will be June 16. ... We feel comfortable and confident that because of the work we do across our communities, and our employees live and work there, and the commitments we have to the state, we will continue to have a constructive regulatory environment no matter how these elections turn out."
— Christopher C. Womack, Chairman, President and Chief Executive Officer

Assessment: A non-answer, delivered confidently. The company gave the election calendar and a century of institutional history and said nothing about what the candidates actually propose or what a less constructive commission would mean for the $81 billion plan. This is the largest unquantified risk in the story and it received the least specific answer of the call. The rate freeze through 2028 is the real mitigant and management knows it, which is presumably why the answer leaned on relationships rather than on the freeze.

What They're NOT Saying

1. Why non-fuel retail revenue was flat. The line the regulated return is earned on was $3,384 million in both quarters, and neither the prepared remarks nor a single question addressed it. In a quarter whose entire narrative was demand growth, the revenue line that captures demand growth at regulated margin did not move.
2. The construction allowance doing more than half the work. Five of the nine cents came from allowance for equity funds used during construction, on the company's own bridge. It was not mentioned in the prepared remarks and drew no questions. A reader of the call transcript alone would not learn where the earnings growth came from.
3. Why underlying depreciation rose 0.5%. Excluding the repowering charge, depreciation and amortization rose $6 million on a base of $1,260 million, at a company deploying roughly $16 billion a year. The Form 10-Q filed the same morning decomposes it: $127 million of accelerated depreciation on the Southern Power wind repowering projects and $102 million from additional plant in service, less $98 million from the extension of Georgia Power's 2022 rate plan. At the regulated utilities, in other words, essentially all of the depreciation on newly in-service plant was offset by a rate-plan accounting benefit. That decomposition appeared in neither the release nor the call.
4. The level of the minimum bill. The contract structure is the strongest argument in the story and is described only qualitatively. No dollar level, no percentage of contracted revenue, no disclosure of what fraction of the 11 gigawatts is protected at what floor. The claim cannot be tested.
5. Earned return on equity at the operating companies. With base rates frozen through 2028 in Georgia and 2029 in Alabama while the rate base grows, the earned return path is the central financial question and was neither disclosed nor asked about.
6. How 75 gigawatts stays 75 gigawatts. Twelve gigawatts advanced a stage in roughly two months and the prospective pipeline is still described as "well over 75 gigawatts." Either it is replenishing at exactly the rate it converts, or the number is not measured with the precision its repetition implies.
7. What a different Georgia commission would mean. Two seats are up in an election being fought on data centers and affordability. The answer covered the primary date, the runoff date and a hundred years of history, and no scenario.
8. Any full-year guidance revision. The company beat its own first-quarter estimate by twelve cents and left a range set in February untouched, without addressing whether the beat was timing, weather-related recovery, or a genuine step-up.

Market Reaction

• Pre-print setup: Closed at $93.51 on 29 April, up 7.2% year to date against 4.2% for the S&P 500, up 1.8% over the trailing twelve months and down 3.1% over the trailing thirty days, inside a 52-week closing range of $84.08 to $99.72.
• Reaction session (30 April, before-open print): Opened at $94.50, up 1.1%; traded between $94.21 and $96.71; closed at $96.70, up 3.4% or $3.19. The stock finished within a penny of the session high, so the gain built through the day and into the 1:00 p.m. call rather than gapping at the open.
• Volume: 8.3 million shares against a 4.5 million thirty-day average, 1.8 times normal.
• Level: The $96.70 close remains 3.0% below the 52-week closing high of $99.72.
• Peer reaction: The entire sector rallied. The utilities sector exchange-traded fund rose 2.6%, Xcel Energy 5.2%, NextEra 3.9%, Dominion 3.2%, Duke 2.4% and American Electric Power 2.0%, against 1.0% for the S&P 500.

The most important thing about the move is how little of it belongs to Southern. On a session when the utilities sector rose 2.6% and two large-cap peers that did not report rose more than Southern did, the idiosyncratic component of a 3.4% gain is roughly 85 basis points. This was a sector day, driven by whatever repriced the group, and the print rode it. Treating the close as a verdict on the quarter would be reading a market signal that is not there.

What the intraday shape does say is that the incremental buying came after the 1:00 p.m. call rather than off the morning release. Opening up 1.1% and closing up 3.4%, within a penny of the high, is the profile of a market that found the contracted-gigawatt disclosures and the Department of Energy loan framing more compelling than the headline beat. That is consistent with how this stock has traded: the quarterly print is a formality and the load funnel is the security.

The pre-print setup matters for the rating. Southern entered the quarter up 7.2% year to date but up only 1.8% over twelve months and down 3.1% over the prior month, mid-range in its 52-week band. This was not a stock priced for perfection going in. It is closer to one now, at 21.3 times the guidance midpoint with a 3.1% yield, and the re-rating happened on a day when the whole group re-rated.

Street Perspective

Debate: Does the Load Convert Into Earnings, or Into Rate Base the Company Cannot Yet Earn On?

Bull view: The sequence is working exactly as designed. Contracted load reached 11 gigawatts with 12 more in late-stage discussion, data center usage grew 42%, and weather-normal retail sales posted the best first quarter in recent history. The construction allowance accruing today is a claim on rate base that converts to cash earnings as each tranche of the 10 gigawatt generation portfolio enters service through 2026 and 2027. Meanwhile the rate freeze is a competitive weapon: it buys regulatory and political permission to keep spending in the one jurisdiction where affordability politics could otherwise stop the plan.

Bear view: Non-fuel retail revenue was flat and consolidated operating income grew 0.4%. Five of the nine cents of adjusted growth was a non-cash construction accrual, three cents was eaten by share issuance, and the residual operating contribution is a rounding error. A company can accrue an allowance on work in progress for years while earned return at the operating companies drifts below authorized, and nobody outside sees it, because Southern does not disclose earned return by subsidiary and no analyst asked. The freeze runs to 2028 and 2029, so the correction, if there is one, is not visible until a general rate case that is three years away.

Our take: The bulls have the mechanism right and the bears have the disclosure gap right, which is why this is a Hold rather than either extreme. The sequence the bulls describe is genuinely how a regulated build cycle works, and Southern is executing it in the best load environment any US utility has. But the market is paying 21 times forward earnings for a company whose highest-quality revenue line did not grow and whose earned-return trajectory is unobservable until 2029. That is a lot of trust extended on a disclosure the company chooses not to make.

Debate: Is 21 Times Forward the Right Multiple for a Regulated Utility With a Data Center Overlay?

Bull view: This is not a normal regulated utility. Twenty-three gigawatts of contracted or late-stage load, a 75 gigawatt prospective pipeline, vertically integrated generation and transmission in three constructive states, and contracts that transfer cost risk to investment-grade hyperscalers is a growth asset wearing a utility's regulatory protection. An $81 billion plan with $4 billion to $12 billion of visible upside from the Georgia procurement, financed partly with $26.5 billion of subsidized 30-year federal money, deserves a premium to the sector and gets one for good reason.

Bear view: Twenty-one times the guidance midpoint against a 5.8% guided earnings increase for 2026 and a 7% to 8% long-term objective produces a price-to-growth relationship worse than the market's, with a 3.1% yield that no longer differentiates the shares. Every dollar of the upside is 40% equity-funded and lands in 2029 through 2033. And the growth that is supposed to justify the multiple showed up this quarter as a construction accrual and a tax rate.

Our take: The bears have this one on arithmetic and the bulls have it on franchise quality. Southern is the best-positioned large-load asset in the sector and should trade at a premium. It already does. At $96.70 the expected twelve-month total return is roughly 6% to 7% on our numbers, price appreciation to a fair value near $100 plus the yield, which is market-like rather than compelling. The multiple is defensible; it is not an entry point.

Debate: Is the Adjusted Earnings Bridge Good Enough to Support a 7% to 8% Objective?

Bull view: The composition of a single quarter is noise. Weather cost five cents and will not repeat symmetrically; retail sales added six; cost control added two on 2.1% non-fuel operations and maintenance growth against 8.0% revenue growth, which is real operating discipline. The construction allowance is not a distortion, it is the accounting representation of a genuine regulated return on genuine capital, and it converts. Southern has delivered inside its objective for years and just raised the dividend for a twenty-fifth consecutive year.

Bear view: The bridge shows a company whose operating core contributed roughly nothing after weather. The non-GAAP wedge went from two cents to eleven and the company has guided to $435 million of additional pre-tax add-backs across the next seven quarters. Interest expense grew 9%, share count grew 2.2%, and both continue. Strip the construction allowance and the tax rate and the quarter is flat, which is what the GAAP line already says.

Our take: Split. The cost control is real and underrated, and the weather headwind is genuinely non-recurring. But an earnings bridge in which the largest single positive is a non-cash accrual on plant not yet in service, in the strongest volume quarter in years, is a bridge that will need the next several quarters to look different. The 7% to 8% objective is achievable given the rate base trajectory. Whether it is achievable with earnings quality that improves rather than degrades is the open question, and one quarter is not enough to answer it.

Model Update

Valuation framework: Applying 20 to 21 times to a FY2027 adjusted EPS estimate of roughly $4.88, which assumes growth at the low end of the 7% to 8% objective off our $4.57 FY2026 figure, produces a fair-value range of approximately $98 to $102 with a midpoint near $100. Against the $96.70 close that implies roughly 3.4% of price return plus a 3.1% dividend yield, for a total return in the mid-single digits over twelve months. That is market-like for a franchise we regard as best-in-class, which is precisely the tension the Hold expresses.

What would change the rating. Two consecutive quarters in which non-fuel retail electric revenue grows and the construction allowance falls below a quarter of the year-over-year earnings increase would demonstrate that the load is converting into earned return rather than accruing against it, and would take us to Outperform even at this multiple. So would a Georgia procurement outcome that adds materially to the plan on terms disclosed before the end of 2026. Conversely, a Georgia commission outcome that reopens the rate freeze, or a second and third quarter in which operating income stays flat while the non-GAAP wedge widens further, would move us toward Underperform quickly at 21 times.

Thesis Scorecard

This is our first coverage of Southern Company, so the table below establishes the thesis rather than grading a standing one. Each pillar is stated as we intend to track it, with the status tag reflecting where this quarter's evidence leaves it at initiation.

Overall: Thesis established. The franchise, the contract structure and the financing are stronger than the sector's, and the load is arriving on schedule. The earnings composition is weaker than the headline and the disclosures that would settle the question are the ones the company does not make. Four bull pillars on track, two bear points emerging, one contained, one materializing.

Action: Hold. This is a franchise worth owning through the build cycle and a price that already reflects most of it. We would move to Outperform on evidence that non-fuel retail revenue is growing and the construction allowance is receding as a share of the earnings increase, or on a pullback toward the mid-$80s, which would restore a yield near 3.6% and a multiple near 19 times. We would not chase it at 21 times on a quarter in which operating income grew 0.4%.

Bottom Line

Southern Company printed the demand quarter its investment case requires. Data center usage rose 42%, weather-normal retail sales grew at the fastest first-quarter rate in recent memory, contracted large load passed 11 gigawatts, and management put $26.5 billion of subsidized federal financing and a 25th consecutive dividend increase behind it. Everything the story needs to be true is visibly true.

What the story does not yet show is the money. Consolidated operating income grew 0.4% on 8.0% revenue growth, GAAP earnings per share were identical in both years, non-fuel retail electric revenue was unchanged to the dollar, and more than half the adjusted increase came from an accounting return on plant that is not yet serving anyone. That is not a failure. It is what the front half of a regulated build cycle looks like when the company has also frozen its base rates, and the return arrives later by design. But it means the 7.3% adjusted growth is a forecast about 2029 dressed as a result from 2026.

We are initiating at Hold with a fair value near $100. The asset is the best of its kind and the contract structure is genuinely differentiated. At 21.3 times the guidance midpoint with a 3.1% yield, on a day the whole sector rose 2.6%, the market has already agreed with us about the asset and has not yet priced the four-year gap between the load and the return.