Duke Energy delivers electricity and natural gas to roughly 8.7 million electric customers and 1.8 million gas customers across six states: North Carolina, South Carolina, Florida, Ohio, Indiana, and Kentucky. The company owns about 55,713 megawatts of generation capacity and operates through two main segments: Electric Utilities and Infrastructure, which is the large core business, and Gas Utilities and Infrastructure, which covers natural gas pipelines and local distribution. Customers pay regulated rates set by state commissions, not by market competition. Duke Energy earns money by investing in power plants and grid equipment, then recovering those costs plus a government-approved profit through the bills customers pay each month. The diagram below traces where the money goes.
How Duke Energy Makes Money
flowchart TD
A["Retail Customers
8.7M electric
1.8M gas"] -->|"Usage charges"| B["Electric & Gas
Revenue
$32.2B"]
C["Generation Assets
55,713 MW capacity
77.5% owned fuel"] -->|"Power generation"| D["Fuel & Operating
Costs"]
B -->|"59.6% margin"| E["Regulated Utility
Margins"]
D -->|"Fuel: coal, gas,
nuclear"| E
E -->|"$12.3B operating
cash flow"| F["Reinvestment in
Generation & Pipes"]
F -->|"Expand capacity
replace aging assets"| C
B -->|"Wholesale sales
22.5% of revenue"| G["Wholesale Contracts
& Auctions"]
G -->|"Bulk power sales"| E
F -->|"Pipeline expansion
and transmission"| H["Infrastructure
Assets & FERC
Approvals"]
H -->|"Rate recovery"| B
I["State Rate Cases
FERC approval"| -->|"Set allowed ROE
9.5% to 10.95%"| E
Five years of financial data tell a consistent story: revenue is growing steadily, costs are heavy, and the company is constantly spending more than it earns in free cash. Revenue climbed from $24.6 billion in 2021 to $32.2 billion in 2025. That is real growth. But free cash flow has been negative in four of those five years, reaching as low as negative $5.4 billion in 2022. The company spends enormous sums building and upgrading infrastructure, and those bills arrive before regulators approve the rate increases that pay for them.
Duke Energy Revenue (2021 to 2025)
Annual revenue in billions of dollars. Source: XBRL filings.
The gross margin tells a more nuanced story. It fell sharply from about 58% in 2021 to about 48% in 2022, likely reflecting fuel cost spikes that year. It has since recovered, climbing back to about 60% in 2025. That recovery suggests Duke Energy has been getting better at passing higher costs through to customers via the rate-setting process. Operating cash flow also improved substantially, rising from $8.3 billion in 2021 to $12.3 billion in both 2024 and 2025. The cash engine is getting stronger even as the spending stays high.
Net debt has grown by nearly $23 billion in four years as Duke Energy funds its capital program with borrowed money.
The debt load is the most important number to keep watching. Net debt rose from $66.8 billion in 2021 to $89.6 billion in 2025. Duke Energy plans to deploy between $200 billion and $220 billion of capital into its regulated businesses over the next decade. That level of spending cannot be funded from cash alone. To reduce some pressure, Duke Energy agreed in August 2025 to accept $6 billion from Brookfield Super-Core Infrastructure Partners in exchange for an eventual 19.7% indirect stake in Duke Energy Florida. The company also agreed in July 2025 to sell Piedmont's Tennessee gas business to Spire Inc. for $2.48 billion. Both deals are designed to fund the capital plan without issuing as much new debt or stock.
How Regulated Utilities Make Money
Duke Energy cannot freely set its own prices. State commissions in each territory review its costs and approve what rates customers pay. The approved rate includes the cost of running the business plus a fixed percentage return on the money Duke Energy has invested in infrastructure. This means the more Duke Energy invests in approved assets, the more profit it is allowed to earn. But there is a lag: Duke Energy spends the money first, then waits for regulators to approve new rates that recover it.
That regulatory lag is also where the main risks live. State commissions in North Carolina, South Carolina, Florida, Ohio, Tennessee, Indiana, and Kentucky each control what Duke Energy can charge. If any commission denies a cost recovery request or takes longer than expected to approve new rates, Duke Energy absorbs those costs. The company currently has a pending North Carolina rate case seeking a $1.002 billion revenue increase for Duke Energy Carolinas and a $729 million increase for Duke Energy Progress, with new rates proposed to take effect in January 2027. There is no guarantee regulators approve the full amounts requested.
$1.73B
Combined revenue increase requested in pending North Carolina rate cases for Duke Energy Carolinas and Duke Energy Progress
Environmental costs add another layer of uncertainty. In April 2024, the EPA issued new rules on greenhouse gas emissions and coal ash management that could force early retirement of power plants and require major cleanup spending. Duke Energy is participating in legal challenges to these rules. Even if the rules are softened, the company still manages large amounts of coal ash at active and retired sites, and the final cleanup cost could be significantly higher than current estimates. Regulators may or may not allow Duke Energy to recover all of those costs from customers.
What Coal Ash Risk Means
When coal burns to make electricity, it leaves behind a residue called coal ash. Duke Energy stores this material in large basins near power plants. Federal and state rules now require these basins to be properly closed and the surrounding groundwater to be cleaned up. The cost to do this work is uncertain and potentially very large. If regulators decide some of those costs were not handled carefully, they can refuse to let Duke Energy charge customers for them.
Nuclear operations are both an asset and a source of risk. Duke Energy operates 11 nuclear reactors across six stations. Nuclear fuel is the cheapest source of electricity Duke Energy uses, at 0.58 cents per kilowatt-hour in 2025 compared to 3.95 cents for natural gas. But the reactors need license renewals from the Nuclear Regulatory Commission to keep running. In March 2025, the Oconee plant received a renewal allowing it to operate until 2054. Robinson's renewal application was filed in April 2025, extending it through 2050 if approved. Losing any of these renewals would remove a low-cost, carbon-free power source that Duke Energy's net-zero plan depends on.
0.58¢
Cost per kilowatt-hour to generate nuclear electricity in 2025, versus 3.95¢ for natural gas and 4.19¢ for coal
2025
milestone
Duke Energy Raises $8.48 Billion Through Asset Deals
Duke Energy agreed to sell Piedmont's Tennessee gas business for $2.48 billion and to accept a $6 billion investment for a 19.7% stake in Duke Energy Florida. Together these deals replace debt and stock issuance that would otherwise have been needed to fund a $200 to $220 billion capital plan. Whether both transactions close as planned is not yet confirmed.
There is also an operational risk the 2022 Christmas Eve blackouts made concrete. On December 24, 2022, Duke Energy cut power to customers for the first time in company history after a winter storm caused demand to spike beyond what the system could handle. Equipment failures and software problems both contributed. The Federal Energy Regulatory Commission opened an investigation. Since then, Duke Energy has invested in self-healing grid technology that the company says avoided approximately 2.2 million customer outages in 2025. But aging infrastructure combined with more frequent extreme weather remains an ongoing pressure.
Duke Energy paid a cash dividend on its common stock for the 99th consecutive year in 2025. That streak is a point of pride for the company and a signal of how seriously management treats dividend continuity. But it also means the dividend is an obligation that competes with capital spending and debt service for every dollar of cash the business generates.
The Bet
Duke Energy is spending $200 to $220 billion over the next decade on the assumption that electricity demand in its service territories will grow significantly and keep growing, driven by data centers, artificial intelligence infrastructure, manufacturing reshoring, and ongoing electrification of homes and transportation. If that demand growth arrives on the scale and timeline the company expects, the capital spending earns a regulated return and revenue keeps climbing. If demand growth disappoints, or if regulators in any major state decide the pace of spending is too aggressive and deny full cost recovery, the math on that debt load becomes much harder to manage.
Open question
Duke Energy controls essential infrastructure that millions of people cannot do without, earns a government-approved return on its investments, and operates in states that have been passing legislation to modernize how utilities recover costs. At the same time, it carries $89.6 billion in net debt, spends more than it generates in free cash almost every year, and depends on regulators in seven states to approve billions of dollars in rate increases while simultaneously managing coal ash cleanup, nuclear license renewals, and the risks of extreme weather. Can Duke Energy's regulated territories actually absorb $200 to $220 billion in new capital spending without regulators pushing back hard on customer rate increases, or will the gap between what Duke Energy needs to spend and what customers can afford to pay become the defining constraint on this business?
Compiled · 10-K · FY2025
Regulatory, Rate Recovery
State utility commissions in North Carolina, South Carolina, Florida, Ohio, Tennessee, Indiana and Kentucky set the rates Duke Energy can charge customers. If regulators deny cost recovery or delay it, Duke Energy cannot pass expenses to customers and earnings will suffer materially.
Environmental, EPA Rules
New EPA rules issued in April 2024 impose strict limits on greenhouse gas emissions, air toxins, and wastewater from coal and natural gas plants. Compliance requires major capital spending and may force early retirement of power plants, with no guarantee regulators will allow Duke Energy to recover these costs from customers.
Nuclear, License Renewal
Duke Energy operates 11 nuclear reactors at six stations and is seeking 20-year license extensions from the NRC. Failure to get approval would block Duke Energy's ability to meet its goal of net-zero carbon emissions by 2050 and eliminate a crucial low-cost power source.
Operational, Coal Ash (CCR)
Duke Energy manages large amounts of coal ash at retired and active plants under strict 2015 and 2024 federal rules. As closure and cleanup work progresses, the scope and cost could be much larger than estimated, creating material increases in expenses with uncertain cost recovery through rates.
Operational, Supply Chain and Inflation
Disruptions in supply chains, rising inflation, tariffs, and potential export controls on materials used in power infrastructure may increase project costs, delay construction, and prevent Duke Energy from recovering these higher costs under existing regulatory mechanisms.
10-K Item 1A · Risk Factors
