ConocoPhillips pulls oil, natural gas, and liquefied natural gas out of the ground in 14 countries and sells them directly into global commodity markets. The company owns no refineries and runs no gas stations. It makes money only one way: produce hydrocarbons, sell them at whatever the market will pay that day. Its biggest operations are in the Lower 48 states of America, where fields in Texas, New Mexico, and North Dakota together produced 1,484 thousand barrels of oil equivalent per day in 2025. Alaska, Canada, Norway, Qatar, Australia, and several other countries round out a portfolio that spans short-cycle shale wells drilled and completed in months all the way to decades-long LNG projects. The diagram below traces where the money goes.
How ConocoPhillips Makes Money
flowchart TD
A["Global Oil & Gas Fields
2,375 MBOED"] --> B["Crude Oil, Natural Gas,
NGLs, Bitumen, LNG"]
B --> C["Commodity Sales
$58.9B revenue"]
C --> D["Operating Cash Flow
$19.8B"]
D --> E["Capital Investment
$18.1B annually"]
E --> A
D --> F["Shareholder Returns
Dividends & Buybacks"]
B --> G["Shared Infrastructure
Pipelines, Processing"]
G --> B
A --> H["Exploration Programs
New Reserves"]
H --> A
Five years of financial data tell a story shaped almost entirely by oil prices. Revenue nearly doubled from $45.8 billion in 2021 to $78.5 billion in 2022 when crude prices surged after Russia invaded Ukraine. Then prices cooled. Revenue fell back to $56.1 billion in 2023 and $54.7 billion in 2024 before ticking up to $58.9 billion in 2025 after the Marathon Oil acquisition added volume. The pattern is consistent: volumes matter, but price is the dominant lever. In 2025, the average Brent crude price dropped 14 percent compared to 2024, which is why earnings fell even as production rose 20 percent to 2,375 thousand barrels of oil equivalent per day.
Annual Revenue 2021 to 2025 ($ Billions)
Revenue swings of this magnitude are driven mainly by commodity price cycles, not by changes in the underlying business.
One thing that has stayed remarkably steady through all that price volatility is the gross margin. It held between 56 and 64 percent across all five years. That consistency reflects the company's deliberate focus on what it calls low cost of supply assets, meaning fields where it can still generate a 10 percent after-tax return even when prices are low. Operating cash flow tells a similar story of resilience. It came in at $17.0 billion in 2021, peaked at $28.3 billion in 2022, and has held in the $19.8 to $20.1 billion range for the past three years despite weaker prices.
$19.8B
Operating cash flow in 2025, even as crude oil prices fell 14% year over year
The company has been spending heavily to grow. In November 2024, it completed a $22.5 billion purchase of Marathon Oil, its largest acquisition in years. That deal pushed net debt from $13.3 billion in 2023 to $18.7 billion in 2024 and $16.9 billion in 2025 as integration work proceeded. Management says it achieved more than $1 billion of synergies on a run-rate basis within the first year of owning Marathon Oil, and it is targeting a further $1 billion in cost reductions and margin improvements by the end of 2026. To help pay down debt and sharpen the portfolio, the company set a $5 billion asset-sale target by year-end 2026 and had already completed $3.2 billion of those dispositions by the end of 2025.
2024
milestone
Marathon Oil acquisition closes
ConocoPhillips paid $22.5 billion to acquire Marathon Oil in November 2024, adding significant Lower 48 acreage and international assets. The deal lifted total production by roughly 20 percent in 2025 and pushed net debt to $18.7 billion, but management reported more than $1 billion in run-rate synergies within the first year.
Even while digesting that acquisition, the company returned $9.0 billion to shareholders in 2025. That included $4.0 billion in ordinary dividends and $5.0 billion in share repurchases. Since 2016, it has repurchased $39.3 billion of its own shares. The company targets returning more than 30 percent of operating cash flow to shareholders each year. In 2025, the actual figure was 46 percent. That is a meaningful commitment to return capital, but it also means less cash available to fund new growth if prices fall sharply.
$9.0B
Returned to shareholders in 2025, equal to 46% of operating cash flow
What is LNG?
LNG stands for liquefied natural gas. Natural gas is cooled to extremely low temperatures until it turns into a liquid, which makes it much easier to load onto ships and transport to countries that have no pipeline connection. Once it arrives, it is warmed back into gas and used for heating, electricity generation, or industry. ConocoPhillips owns stakes in LNG facilities in Australia, Qatar, Equatorial Guinea, and has a 30 percent interest in a project being built on the U.S. Gulf Coast.
Looking forward, the company is building a growing LNG business as a second engine alongside its existing oil and gas production. It has secured 10.2 million tonnes per year of commercial LNG offtake agreements in North America, with deliveries starting between 2026 and 2031. New LNG capacity in Qatar is expected to start up in the second half of 2026. The Willow project in Alaska, a large new oil development approved in 2023, is under active construction and targets first oil in early 2029. These are long-cycle projects: they require years of construction spending before they generate any cash.
What does reserve replacement mean?
Every barrel of oil a company pumps out of the ground reduces its underground stockpile of proved reserves. Reserve replacement measures how well the company is refilling that stockpile through new discoveries, acquisitions, or improved recovery techniques. A reserve replacement rate below 100 percent means the company is drawing down its reserves faster than it is replacing them, which is a warning sign for the long-term health of the business.
Reserve replacement came in at 80 percent in 2025. That number was dragged down by the planned sale of non-core assets, which removed reserves from the books. Strip out those asset sales and the organic reserve replacement rate was 99 percent, meaning the company almost exactly replaced what it produced through drilling and development. Over three years, the total reserve replacement was 145 percent. At year-end 2025, total proved reserves stood at 7,637 million barrels of oil equivalent, down slightly from 7,812 million at year-end 2024 but up from 6,758 million at year-end 2023.
There are several documented risks that can pressure this business. The most direct is price. In 2025 alone, crude oil ranged from $80 to $55 per barrel according to the company's own filings. That is a $25-per-barrel swing in a single year, and the company holds no price hedges. Climate regulation is also an increasing cost. New emissions rules, carbon taxes, and methane regulations are expanding worldwide, and new laws in New York and Vermont now hold energy companies financially responsible for climate-related damages. Similar laws may spread to other states. Legal costs from climate-related lawsuits are expected to be substantial, even if the company believes those claims have no merit. A temporary U.S. pause on new LNG export approvals in January 2024, lifted in January 2025, showed how quickly policy can disrupt a business that has committed to deliver specific LNG volumes through 2042.
In 2025 a class action lawsuit was filed alleging ConocoPhillips caused higher home insurance premiums through climate-related losses. The company said it believes the claim is meritless, but legal costs are expected regardless of outcome.
$10.2B
Net debt 2022 (after prior asset sales)
$18.7B
Net debt 2024 (after Marathon Oil acquisition)
The Marathon Oil deal nearly doubled net debt. Getting that number back down depends on sustained cash flow and the planned $5 billion in asset dispositions.
$122B
Total assets at December 31, 2025, reflecting the scale of the post-Marathon Oil business
The Bet
ConocoPhillips is built on the premise that global demand for oil, natural gas, and LNG stays high enough, for long enough, to justify the billions being committed right now to Willow in Alaska, new LNG trains in Qatar, and the Port Arthur LNG project on the U.S. Gulf Coast. These are 20-to-25-year projects that will not generate meaningful cash for years. If oil prices stay persistently low, or if climate policy accelerates faster than the industry expects, the cash engine that funds both those long-cycle investments and the $9 billion annual return to shareholders shrinks before the new capacity is ready to replace it. The whole logic of the portfolio assumes the window for high-return fossil fuel investment stays open long enough for these projects to pay back their construction costs many times over.
Open question
ConocoPhillips has built one of the largest purely exploration-and-production businesses in the world, with operations across 14 countries, a growing LNG footprint, and a track record of returning enormous amounts of cash to shareholders even through price downturns. But the business is entirely exposed to commodity prices it cannot control, it is adding new long-cycle projects that will not produce cash for years, and it faces growing legal and regulatory pressure tied to climate change. Can ConocoPhillips generate enough cash through the inevitable oil price cycles to fund Willow, the Qatar LNG expansions, and the Port Arthur project while continuing to pay down acquisition debt and returning more than 30 percent of operating cash flow to shareholders every year, before the regulatory and legal environment tightens enough to change the economics of the whole model?
Compiled · 10-K · FY2025
Commodity Price Volatility
Oil, natural gas, and other products the company sells have prices that swing widely based on world events and supply and demand. When prices stay low for long periods, the company makes less money, may have to cut spending on new projects, and could write down the value of existing assets. In 2025 alone, crude oil prices ranged from $80 to $55 per barrel.
Reserve Depletion and Development Risk
As the company pumps oil and gas from the ground, its reserves shrink. If it cannot find and develop new resources through exploration or acquisitions, the business will decline. Success depends on navigating political approvals, managing complex capital-intensive projects, and optimizing mature fields.
Climate Regulation and Emissions Compliance
New laws limiting greenhouse gas emissions, carbon taxes, and methane regulations are increasing worldwide. The company has set emissions reduction targets but faces uncertainty in achieving them due to technology gaps, high costs, and the need to purchase emissions credits. New York and Vermont passed laws holding energy companies liable for climate change impacts, and similar laws may spread to other states.
LNG Export Restrictions
In January 2024, the U.S. temporarily paused new approvals for liquefied natural gas exports due to environmental concerns. Though lifted in January 2025, the pause and ongoing regulatory approval difficulties could materially harm the company's global LNG business.
Climate-Related Litigation
Since 2017, cities, counties, and governments have sued oil and gas companies including ConocoPhillips seeking damages for climate change impacts. In 2025, a class action was filed alleging the company caused increased home insurance premiums due to climate losses. The company expects to incur substantial legal costs defending these lawsuits, though it believes they are meritless.
10-K Item 1A · Risk Factors
