Southern Company is a giant energy provider serving about 9 million customers across the southeastern United States. It owns Alabama Power, Georgia Power, and Mississippi Power, which deliver electricity to homes and businesses across three states. It also owns Southern Company Gas, which pipes natural gas to roughly 4.4 million customers in Illinois, Georgia, Virginia, and Tennessee. On top of that, Southern Power sells electricity in bulk to other utilities and large buyers. Almost all of this revenue comes from one simple idea: people and businesses need power every single day, no matter what the economy is doing, and Southern Company charges them for delivering it. The diagram below traces where the money goes.
How Southern Company Makes Money
flowchart TD
A["Retail Electric Customers
4.6M accounts"] -->|"$19.3B/yr"| B["Retail Electric Revenue"]
C["Natural Gas Customers
4.4M accounts"] -->|"$5.0B/yr"| D["Gas Distribution Revenue"]
E["Wholesale Purchasers
Utilities, IPPs, Data Centers"] -->|"$2.9B/yr"| F["Wholesale Electric Revenue"]
B --> G["Total Operating Revenue
$29.6B, 72% margin"]
D --> G
F --> G
G --> H["Operating Cash Flow
$9.8B/yr"]
H --> I["Capital Investment
$15.9B/yr in 2026"]
I --> J["New Generation, Transmission,
Distribution Assets"]
J --> A
J --> C
J --> E
J --> K["Southern Power
Generation Fleet
12,648 MW capacity"]
K -->|"Market-based rates"| F
Five years of financial data tell a story of a business that is growing steadily but spending heavily to get there. Revenue climbed from $23.1 billion in 2021 to $29.6 billion in 2025. Gross margins improved from roughly 60% in 2022, when fuel costs spiked, back up to 74% in 2024 before settling at 72% in 2025. Cash from operations rose sharply, from $6.2 billion in 2021 to $9.8 billion in 2025. Those are signs of a healthier engine.
Revenue 2021 to 2025 ($ billions)
Revenue dipped in 2023 after fuel cost pass-throughs fell, then recovered as rates rose and new customers came online.
But the cash flow picture has a major catch. Free cash flow, which is the money left over after all capital spending, was negative in four of the five years: negative $1.4 billion in 2021, negative $1.6 billion in 2022, negative $1.5 billion in 2023, and negative $2.9 billion in 2025. The one positive year was 2024, at $0.8 billion. That is because the company is constantly building new power plants, transmission lines, and pipelines. It plans to spend $15.9 billion on construction in 2026 alone.
$64.7B
Net debt at end of 2025, up from $49.8B in 2021
All that building has to be paid for somehow. Net debt rose from $49.8 billion in 2021 to $64.7 billion in 2025. This is not unusual for a regulated utility, but it means the company depends heavily on its ability to borrow at reasonable rates and recover those costs through customer bills.
How regulated utilities make money
A regulated utility cannot charge whatever it wants. State regulators review its costs and set rates that allow it to earn a fixed return on the money it has invested. If a regulator approves the investment, the company earns that return for years. If the regulator rejects or cuts the investment, the company absorbs the loss.
The biggest growth story right now is data centers. Georgia Power alone has signed contracts with new data center and large industrial customers covering roughly nine gigawatts of electric load since 2023. These contracts contain minimum bill requirements and termination payments designed to protect the company if a customer leaves early. Service under most contracts begins through 2028. Georgia Power has $19.5 billion in certified construction projects planned through 2030 to serve this demand.
$19.5B
Georgia Power certified construction costs approved by regulators through 2030
2023
milestone
Plant Vogtle finally switches on
After years of construction delays and a bankruptcy of the main contractor, Southern Company completed two new nuclear reactors at Plant Vogtle in Georgia. The first came online in 2023 and the second in 2024. These were the first new nuclear reactors built in the United States in roughly 30 years. The project was backed by an $8.3 billion federal loan. Nuclear now generates 19% to 22% of the company's electricity, and the new units are now included in Georgia Power's regulated rate base, meaning customers pay for them through their bills.
Now consider the risks. The most immediate is regulatory. State commissions in Alabama, Georgia, Mississippi, Illinois, Virginia, and Tennessee each decide what Southern Company can charge customers. In Illinois, regulators disallowed $127 million of Nicor Gas capital investments in 2023 and excluded another $120 million in 2025. Those decisions meant the company absorbed losses it expected to recover. If regulators keep cutting cost recovery, the math of building expensive infrastructure breaks down.
What a regulatory disallowance means
When a utility spends money building pipes or wires, it expects to recover that cost through future customer bills. A disallowance is when a regulator says no, that cost was not reasonable, and you cannot charge customers for it. The company then must write off that spending as a loss.
Nuclear operations add another layer of risk. Alabama Power and Georgia Power run eight nuclear units that produced 19% to 22% of their power in 2025. If federal regulators impose new safety rules or shut down a unit, the costs could be enormous. The company carries insurance and maintains decommissioning funds, but those may not cover every scenario. Environmental costs add pressure too. The company must close and monitor old coal ash storage sites at its power plants. Estimated cleanup costs for 2026 alone are $653 million across the system, and the final bill is still unknown as regulations keep changing.
There is also a newer and less familiar risk. A new federal law signed on July 4, 2025 materially changed renewable energy tax incentives. Southern Power uses these tax credits to make its solar and wind projects financially attractive to partners. The company says it is still assessing the full impact. Meanwhile, Southern Power depends on long-term power purchase agreements for about 25% of its revenue. If a major contract expires without a replacement, revenues shrink.
Southern Power's investment coverage ratio was 97% through 2030 and 89% through 2035, with an average remaining contract length of about 12 years, suggesting most of its capacity is already locked into paying customers for now.
The Bet
Southern Company is spending tens of billions of dollars building generation, transmission, and pipeline infrastructure on the assumption that a wave of new large customers, especially data centers, will show up, stay, and consume enough electricity to justify the cost. Georgia Power alone has committed to $19.5 billion in certified projects through 2030 to serve this expected demand. If data center growth slows, contracts get cancelled, or regulators refuse to let the company recover those construction costs through customer rates, the company will have taken on massive debt and built capacity that does not earn an adequate return. The entire financial logic depends on regulators and large customers both delivering on their side of the bargain, at the same time.
Open question
Southern Company has a relatively predictable base of residential and commercial customers who need electricity and gas every day. That base is not going away. But the company is now making a much larger and less certain bet on industrial-scale electricity demand from data centers, while carrying $64.7 billion in net debt and spending more than it earns in free cash flow most years. Can Southern Company recover the cost of this massive construction wave through regulated rates before the debt load and uncertain demand growth create a gap too wide to close?
Compiled · 10-K · FY2025
Regulatory Rate Recovery
State utility regulators can delay, reduce, or deny Southern Company's ability to recover its costs through customer rates, including massive infrastructure investments and environmental cleanup expenses. Rising costs combined with customer affordability concerns and political opposition to rate increases could prevent the company from earning a reasonable return on its investments.
Nuclear Operations
Alabama Power and Georgia Power operate eight nuclear units that generated 22 to 36% of their power in 2025. If the Nuclear Regulatory Commission imposes new safety requirements, shuts down a unit, or if a major incident occurs, the companies could face billions in costs that might exceed insurance coverage and decommissioning trust funds.
Environmental Compliance Costs
Southern Company faces significant and uncertain costs to manage coal combustion residue (CCR) at power plants, comply with air and water quality regulations, and potentially handle hazardous waste cleanup at current and former sites. These costs may not be fully recoverable through rates, and estimates could change materially as regulations evolve.
Renewable Energy Tax Incentives
The Inflation Reduction Act imposed a 15% corporate minimum tax that may not be recoverable through regulated rates. The Onshore Backyard Bidding Bill signed July 4, 2025, materially changed federal renewable energy tax incentives and credit transferability, with uncertain impacts still being assessed by the company.
Power Purchase Agreement Risk
Southern Power depends on customers under power purchase agreements for approximately 25% of revenue, and cannot predict if these contracts will be renewed. If a major customer defaults or contracts expire without replacement, the company would have to sell power at lower wholesale prices or halt operations.
10-K Item 1A · Risk Factors
