Occidental Petroleum Showcases Cash, Debt Wins in Call

Occidental Petroleum Corp. ((OXY)) has held its Q1 earnings call. Read on for the main highlights of the call.

Occidental Petroleum’s latest earnings call struck a clearly upbeat tone, with management stressing strong operations, sharply higher free cash flow, and rapid balance-sheet repair. While they acknowledged several temporary headwinds, including regional disruptions and project timing issues, executives argued these are transitory against a backdrop of improving costs, rising reserves, and disciplined capital allocation.

Production Beat Underscores Operational Strength

Occidental reported about 1.43 million barrels of oil equivalent per day in Q1 2026, topping the high end of guidance and beating the midpoint by roughly 21,000 barrels per day. Domestic production was the standout, running about 33,000 barrels per day above the midpoint, helped by strong new well performance and high facility uptime.

Free Cash Flow Surges Despite Flat Oil Prices

The company generated around $1.7 billion in free cash flow before working capital in the quarter and ended Q1 with more than $3.8 billion of unrestricted cash. Free cash flow from continuing operations climbed about 52% year over year even though oil prices were broadly similar, underscoring improved capital efficiency and portfolio quality.

Deleveraging Rapidly Reshapes the Balance Sheet

Occidental has cut principal debt to $13.3 billion, down from roughly $20.8 billion at the end of last year’s third quarter, a paydown of $7.5 billion since December. This aggressive deleveraging pushed the annual interest run-rate down to about $845 million, roughly $550 million lower than 2025, with a clear near-term goal to trim principal debt to $10 billion.

Cost Savings and Efficiency Gains Support Margins

Management highlighted $2.0 billion in annual cost savings delivered since 2023 and is targeting another $500 million of oil and gas savings in 2026. Domestic lease operating expense came in at $7.85 per barrel of oil equivalent, around 5% better than guidance, and the company still sees roughly 7% improvement in new well costs this year.

Midstream Outperformance Drives Guidance Upgrade

The midstream segment handily beat expectations, with adjusted earnings roughly $400 million above the midpoint of guidance in Q1. On the back of this strength, Occidental raised the midpoint of full-year midstream guidance to $1.1 billion, an increase of about $800 million versus its prior outlook.

Decade-Long Transformation of Production and Reserves

Since 2015, Occidental has transformed from roughly 150,000 barrels of oil equivalent per day of production to more than 1.4 million. Over the same period, proved reserves nearly doubled to 4.6 billion barrels of oil equivalent and total resources rose to about 16.5 billion, giving the company a runway of more than 30 years and a target to push base decline below 20% by decade end.

Top-Tier Wells and Reliable Base Operations

The company reiterated its standing as a top performer in unconventional wells, noting that in 2025 its new wells delivered at least 10% better six-month oil per lateral foot than the industry average across all basins. Offshore, Gulf of America operations posted record topside uptime of 98% in Q1, supporting consistent output and cash flow.

Exploration Wins and Project Milestones

Occidental announced the Bandit discovery in the Gulf of America, its third discovery in the region in three years, reinforcing its offshore exploration track record. Construction of Stratos Phase 2 is complete and Phase 1 commissioning ran as expected on process units, with management emphasizing that a non-process issue under review is not expected to alter the 2026 capital range.

Disciplined Hedging and Capital Allocation Strategy

To safeguard cash flows, the company put on modest costless collars in February covering 100,000 barrels per day for March through December 2026, with a $55 floor and a volume-weighted ceiling around $76 WTI. Capital priorities remain firmly anchored on cutting principal debt to $10 billion, after which management plans to reassess options including dividend adjustments, preferred redemptions, reinvestment, and selective buybacks.

Middle East Disruptions Temper International Volumes

Operational constraints in the Middle East that began in mid-March weighed on international production and affected production-sharing contract barrels amid higher oil prices. While management expects conditions to normalize before the end of the second quarter, the company trimmed the midpoint of full-year production guidance to 1.44 million barrels of oil equivalent per day.

EOR Portfolio Optimization Lowers Near-Term Volumes

Occidental executed transactions to consolidate working interest in core operated enhanced oil recovery floods while selling scattered noncore fields. These moves are expected to be free cash flow accretive but modestly reduce EOR output, which stands at about 100,000 barrels per day, and therefore slightly weigh on near-term reported volumes.

Stratos Commissioning Issue Adds Timing Uncertainty

After Phase 1 commissioning, the company identified a non-process component issue that is unrelated to the core Stratos technology. Management is still determining the repair schedule and potential operational impact but stressed that, at this stage, they do not expect the issue to affect the 2026 capital spending range, even if project timing ultimately shifts.

Working Capital and One-Offs Skew Quarterly Cash Timing

First-quarter cash flow was affected by higher working capital use, largely from receivables tied to stronger March oil prices and normal seasonal outflows such as semiannual interest, property taxes, and compensation. Reported GAAP results were also influenced by a gain related to an asset sale, offset by derivative losses and premiums tied to early debt retirement.

Sulfur Sales and Logistics Hit by Regional Conflict

Within midstream, sulfur sales were pressured by logistics disruptions linked to the conflict in the Middle East, weighing on segment revenues. Management expects activity to normalize in the second half of the year, but they acknowledged that timing and duration of the recovery remain uncertain and dependent on the broader regional situation.

Permian and Service Cost Inflation Risks

Service providers have signaled potential price increases for rigs, frac spreads, and consumables, raising the specter of cost inflation in the Permian and elsewhere. Occidental still expects to hold 2026 capital within the $5.5 billion to $5.9 billion range and maintain its planned 7% new well cost improvement, but flagged service costs as a key variable to watch.

Seasonal Dip Expected in Gulf of America Volumes

The company guided to a modest decline in Gulf of America production in the second quarter due to planned maintenance and the onset of the tropical weather season. Management expects solid domestic onshore performance to partly offset this seasonal offshore dip, smoothing overall company volumes through midyear.

Guidance and Outlook Emphasize Cash, Costs, and Debt

Occidental reaffirmed its 2026 capital budget of $5.5 billion to $5.9 billion, with spending weighted toward the second quarter, and set full-year production guidance at a midpoint of 1.44 million barrels of oil equivalent per day. The company targets more than $1.2 billion of incremental free cash flow versus 2025, underpinned by lower lease operating costs, a reduced interest burden, higher midstream earnings, and continued progress on its goal to cut base declines below 20%.

Occidental’s call painted a picture of a company leaning into operational strength and financial discipline while navigating manageable short-term headwinds. For investors, the key themes were outsized free cash flow growth, rapid deleveraging, and rising midstream contributions, all wrapped in a cautious but confident outlook on costs, capital, and long-lived resource depth.