EOG Resources pulls crude oil, natural gas, and natural gas liquids out of the ground and sells them to refiners and other buyers at whatever price the market offers that day. The company drills its own wells, mostly in the United States, across fields like the Delaware Basin in New Mexico and Texas, the Eagle Ford play in South Texas, and now the Utica play in Ohio. It does not refine oil into gasoline or sell fuel at a pump. EOG makes money purely by producing as much as it can, as cheaply as it can, and hoping the commodity price is high enough to cover costs and leave a profit. The diagram below traces where the money goes.
How EOG Resources Makes Money
flowchart TD
A["Proved Reserves
5,514 MMBoe"] --> B["Drilling & Well
Completions"]
B --> C["Oil & Gas Production
449.8 MMBoe/yr"]
C --> D["Three Revenue Streams
22.6B total"]
D --> E["Crude Oil Sales
12.5B"]
D --> F["Natural Gas Sales
2.8B"]
D --> G["NGLs & Gathering
7.3B"]
E --> H["Operating Cash Flow
10.0B"]
F --> H
G --> H
H --> I["Reserve Replacement
& Development"]
I --> A
H --> J["Debt Reduction
4.6B net debt"]
C --> K["Sales Commitments
Future volumes locked"]
K --> H
Five years of financial data tell a clear story about how this business behaves. Revenue swung from $19.7 billion in 2021 to a peak of $29.5 billion in 2022 when oil and gas prices spiked, then fell back to roughly $22 to $23 billion in 2023, 2024, and 2025 as prices cooled. That swing was not caused by EOG doing anything differently. It was caused almost entirely by commodity prices moving up and then down. Production actually kept growing the whole time.
EOG Annual Revenue (2021 to 2025)
Revenue in billions of dollars. The 2022 spike reflects high oil and gas prices, not a permanent change in the business.
What did not swing nearly as much was the cash the business actually generated from operations. Operating cash flow stayed between $8.8 billion and $12.1 billion across all five years, even when revenue dropped sharply from 2022 to 2023. That is a sign that EOG's cost structure is lean enough to hold up through a price downturn. The company says it focuses on being a low-cost producer, and the cash flow numbers support that claim.
$12.1B
Operating cash flow in 2024, the highest in the five-year period, showing the business generated substantial cash even after 2022's price peak had passed.
The balance sheet shifted meaningfully in 2025. For three of the prior four years, EOG carried more cash than debt, meaning net debt was negative. That changed in 2025, when net debt rose to $4.6 billion. The reason was a single large move: EOG spent $5.7 billion in August 2025 to acquire Encino Acquisition Partners, which added 675,000 acres in the Utica play in Ohio. To pay for it, EOG issued several rounds of senior notes totaling billions of dollars in new borrowing. The company also paid $2.2 billion in dividends and $2.6 billion in share repurchases during 2025, all while investing in that acquisition.
2025
milestone
Encino Acquisition Reshapes the Balance Sheet
EOG paid $5.7 billion for Encino Acquisition Partners in August 2025, adding 675,000 core net acres in Ohio's Utica play. The deal was funded largely by new debt, pushing net debt from negative $1.8 billion at the end of 2024 to positive $4.6 billion at the end of 2025. This was the largest single capital deployment in the five-year period and signals EOG is betting on natural gas growth in the Appalachian region.
The Encino deal also dramatically increased natural gas production. Total natural gas deliveries jumped 30 percent in 2025 compared to 2024, and the Utica play was a primary driver. Natural gas revenue rose 80 percent in 2025, helped by both higher prices and that higher volume. This matters because oil has historically been EOG's main earner, but the mix is shifting. Crude oil and liquids made up 84 percent of production revenue in 2025, down from 91 percent in 2024, as gas grew faster.
What Are Natural Gas Liquids?
Natural gas liquids, or NGLs, are hydrocarbons that come out of the ground mixed with natural gas but can be separated into products like ethane, propane, and butane. They are sold separately from both crude oil and natural gas. EOG produced 288,000 barrels of NGLs per day in 2025, up 17 percent from 2024.
EOG's proved reserves also grew substantially in 2025. Total net proved reserves reached 5,514 million barrels of oil equivalent at year end, an increase of 766 million barrels of oil equivalent from 2024. Most of that increase came from natural gas reserves added through the Encino acquisition. About 99 percent of all proved reserves are in the United States. That concentration in one country reduces geopolitical risk but also means EOG is fully exposed to U.S. regulatory changes.
The risks EOG faces are well documented and serious. The biggest one is the simplest: oil and gas prices are set by global markets, and EOG controls none of them. When prices fall, cash flow shrinks and the company may have to write down the value of its reserves. EOG already recorded $709 million in impairments of proved properties in 2025, up from $295 million in 2024, driven by write-downs in the Barnett Shale and Woodford Oil Window plays. That is a real cost of owning assets whose value depends on prices that change daily.
$843M
Total impairments recorded in 2025, more than double the $391 million recorded in 2024, reflecting declining commodity prices hitting the value of certain oil and gas assets.
Climate and environmental regulation is a second documented threat. New rules on greenhouse gas emissions, hydraulic fracturing, and drilling permits on federal lands could increase costs or limit where EOG can drill. The regulatory picture is currently shifting in multiple directions. Some methane charges have been delayed or repealed at the federal level, while new reporting requirements and state-level rules continue to evolve. EOG cannot predict what rules will look like in five years, and neither can anyone else.
What Is Hydraulic Fracturing?
Hydraulic fracturing, often called fracking, is a drilling technique where water, sand, and chemicals are pumped into a rock formation at high pressure to crack it open and release oil or gas. Most of EOG's U.S. production depends on this method. Restrictions on fracking would directly limit how much EOG can produce from its existing acreage.
A third risk is reserve replacement. Oil and gas wells naturally produce less over time. EOG must keep drilling new wells or making acquisitions just to maintain current production levels. If drilling costs rise, if access to federal lands is restricted, or if the company drills too many dry holes, production falls and so does cash flow. EOG completed 641 net wells in the United States in 2025 and plans to complete approximately 585 in 2026, a slight reduction in pace.
There is also an active legal threat. In January 2024, a group of gasoline buyers filed a lawsuit claiming that EOG and seven other oil companies illegally coordinated to limit shale oil production, which the plaintiffs say kept gasoline prices artificially high. EOG denies this. The lawsuit is unresolved. If it succeeds, it could expose EOG to financial penalties and reputational damage.
EOG committed to return at least 70 percent of annual operating cash flow minus capital spending to shareholders through dividends and buybacks, starting with fiscal year 2024. During 2025, dividends alone totaled $2.2 billion, and the quarterly dividend was raised from $0.975 to $1.02 per share mid-year.
-$1.8B
Net Debt at End of 2024
$4.6B
Net Debt at End of 2025
The Encino acquisition and new debt issuances flipped EOG from a net cash position to meaningful net debt in a single year.
That shift from net cash to net debt is the central financial tension right now. EOG spent heavily to grow, took on new obligations, and simultaneously kept returning billions to shareholders. Whether that combination holds together depends on one thing more than anything else.
The Bet
EOG can grow production volume fast enough, and keep its cost per barrel low enough, that even if oil prices stay at or below 2025 levels, the cash generated is sufficient to service the new debt from the Encino acquisition, maintain the shareholder return commitment, and fund ongoing drilling across the Delaware Basin, Eagle Ford, and Utica simultaneously. If oil prices fall further or the Utica wells underperform expectations, EOG faces a choice between cutting returns to shareholders, slowing drilling, or taking on even more debt. All three outcomes would represent a meaningful change from the story the company has told over the past five years.
Open question
EOG produced more oil and gas in 2025 than in any prior year in this data set, but earned less net income than in 2024. It now carries more debt than it has in years, has committed to returning 70 percent of free cash flow to shareholders, and just added a large new gas-focused asset in Ohio at a time when natural gas prices are recovering but uncertain. Can EOG's low-cost production model generate enough cash across all three major plays to honor its shareholder commitments and pay down the Encino debt, even if crude oil stays below $70 per barrel?
Compiled · 10-K · FY2025
Commodity Price Volatility
EOG's cash flows, production levels, and financial condition depend heavily on crude oil and natural gas prices, which fluctuate based on supply, demand, geopolitical events, and global economic conditions. Sustained price declines can force the company to write down the value of reserves, shut down uneconomical wells, and reduce or eliminate dividend payments to shareholders.
Capital and Financing Access
EOG requires substantial capital spending for drilling and operations. If commodity prices fall, credit markets tighten, or financial institutions reduce lending to oil and gas companies due to climate concerns, the company may struggle to obtain financing or face much higher borrowing costs, limiting its ability to execute its business strategy.
Climate and Environmental Regulation
New federal, state, and international regulations on greenhouse gas emissions, hydraulic fracturing, and drilling permits could increase EOG's operating costs, delay projects, reduce demand for oil and gas, or restrict where the company can drill. The SEC's climate disclosure rules and similar state mandates also require costly new reporting.
Reserve and Production Decline
Natural gas and oil reserves decline as they are produced. If EOG cannot find or acquire enough new reserves through successful drilling or property acquisitions, production will fall, reducing future cash flows and shareholder returns. Bans or restrictions on leasing and drilling make this replacement challenge more difficult.
Operational and Infrastructure Constraints
EOG depends on third-party pipeline, processing, and transportation infrastructure to sell its production. Supply chain disruptions, lack of available capacity, or mechanical failures at critical facilities can interrupt production and sales. Water shortages or restrictions can also halt drilling and completion operations.
10-K Item 1A · Risk Factors
