ConocoPhillips finds oil and natural gas underground, pulls it to the surface, and sells it to customers around the world. That is essentially the whole business. The company operates in 14 countries, running wells in Alaska, Texas, Canada, Norway, Qatar, Australia, Malaysia, Libya, China, and Equatorial Guinea. It produces crude oil, natural gas, a heavier form of oil called bitumen from Canadian oil sands, and liquefied natural gas (LNG), which is natural gas cooled into liquid form so it can be shipped on tankers. Every barrel or unit of gas it sells gets consumed by the buyer, so revenue rises and falls almost entirely with global commodity prices. The diagram below traces where the money goes.
The Marathon Oil deal reshaped the company's size almost overnight. Total production in 2025 reached 2,375 thousand barrels of oil equivalent per day, up 20 percent from 2024. Revenue jumped from $45.8 billion in 2021 to a peak of $78.5 billion in 2022, then settled back as oil prices fell. By 2025, revenue was $58.9 billion. That pattern tells the core story: the business got bigger through acquisitions, but the actual money it earns in any given year still depends heavily on what oil and gas fetch on the open market.
Cash from operations has stayed remarkably steady even as revenue swung widely. The company generated $17.0 billion in operating cash in 2021, $28.3 billion in 2022, and has remained in the $19 to $20 billion range every year since. That consistency reflects the company's focus on keeping its cost base low enough to stay profitable even when prices drop. Gross margin has actually improved slightly over the period, moving from around 60 percent in 2021 to over 63 percent in 2024, before settling at about 62 percent in 2025.
Free cash flow tells a more complicated story. It came in at $11.7 billion in 2021, rose to $18.2 billion in 2022, then fell steadily to $8.7 billion in 2023, $8.0 billion in 2024, and $7.2 billion in 2025. The decline reflects rising capital spending as the company funds the Willow project in Alaska, expands LNG positions in Qatar and on the U.S. Gulf Coast, and integrates Marathon Oil assets. The company spent $12.6 billion on capital expenditures and investments in 2025 alone. More spending on future projects is real and necessary, but it does compress the cash available today.
Net debt has also grown. It stood at $14.9 billion in 2021, fell to $10.2 billion in 2022 when high oil prices flooded the company with cash, then climbed back to $18.7 billion in 2024 after the Marathon Oil purchase added substantial debt. By end of 2025, net debt had declined slightly to $16.9 billion. The company has maintained an A credit rating and returned $9.0 billion to shareholders in 2025 through dividends and share repurchases, representing 46 percent of operating cash flow. Since 2016, it has repurchased $39.3 billion of its own shares.
Several specific risks sit inside this business and are worth naming directly. The most significant is commodity price volatility. Brent crude averaged $69.06 per barrel in 2025, down 14 percent from $80.76 in 2024. That single price move shrank Alaska's earnings from $1.326 billion to $730 million, even though production barely changed. The company's own filing states that profitability, reserves, and the ability to pay dividends are all directly influenced by these price swings.
Reserve replacement is a second risk. In 2025, ConocoPhillips replaced only 80 percent of what it produced, meaning its proved reserve count shrank on a net basis. Lower oil prices caused some reserves to be written down, and the company sold off noncore assets in the Lower 48 that held reserves. Organic reserve replacement, which strips out asset sales and purchases, was 99 percent. Over the last three years combined, total reserve replacement was 145 percent. So the long-run trend looks healthier than the single-year number, but any extended period of low prices or failed exploration would erode that buffer.
A third risk is legal and regulatory. New laws in New York and Vermont now hold oil companies financially responsible for state climate-related damages. ConocoPhillips also faces lawsuits from cities, counties, and states seeking money for alleged climate change harm. The company cannot estimate the total potential liability from these cases. Separately, the U.S. government paused approvals for new LNG export projects in January 2024. That pause ended in January 2025, but any future restrictions would directly limit the company's ability to grow its LNG business, which it has been building aggressively through deals in Qatar, Australia, Equatorial Guinea, and the planned Port Arthur LNG facility on the U.S. Gulf Coast.
The Willow project in Alaska adds a fourth dimension of risk. ConocoPhillips took the final investment decision on Willow in late 2023. It involves three drill sites, a processing facility, and pipeline construction on the North Slope. As of end 2025, the project was approaching 50 percent completion, with the processing facility on track for transport to the North Slope in 2027. First oil is not expected until early 2029. That is a long runway of capital spending before any cash comes back. Large construction projects in remote Arctic environments carry real schedule and cost risk.
The whole financial structure leans on a single underlying assumption that connects every part of the story: that global demand for oil and gas stays high enough, for long enough, to justify the billions being committed to projects that will not produce cash for years. ConocoPhillips is spending heavily today on Willow, on LNG expansions in Qatar and the U.S. Gulf Coast, and on integrating Marathon Oil, all while oil prices in 2025 were 14 percent below 2024 levels and free cash flow has been falling every year since 2022.