Oxy delivered strong Q2 results with record midstream income and production beats, leading to the highest quarterly FCF in four years. Management outlined a clear, bottoms-up plan to deliver over $4 billion in incremental sustainable cash flow by 2030, emphasizing cost efficiency, reduced sustaining capital, and balance sheet strength, all while signaling continued discipline on capital allocation. Record quarterly free cash flow of ~$3 billion, with adjusted EPS of $2.40, and principal debt reduced to $11.8 billion, aided by $1.5 billion in repayment during the quarter.
Oxy delivered strong Q2 results with record midstream income and production beats, leading to the highest quarterly FCF in four years. Management outlined a clear, bottoms-up plan to deliver over $4 billion in incremental sustainable cash flow by 2030, emphasizing cost efficiency, reduced sustaining capital, and balance sheet strength, all while signaling continued discipline on capital allocation. Record quarterly free cash flow of ~$3 billion, with adjusted EPS of $2.40, and principal debt reduced to $11.8 billion, aided by $1.5 billion in repayment during the quarter.
Oxy delivered strong Q2 results with record midstream income and production beats, leading to the highest quarterly FCF in four years. Management outlined a clear, bottoms-up plan to deliver over $4 billion in incremental sustainable cash flow by 2030, emphasizing cost…
Record quarterly free cash flow of ~$3 billion, with adjusted EPS of $2.40, and principal debt reduced to $11.8 billion, aided by $1.5 billion in repayment during the quarter.
Production of 1.43 million BOE/d exceeded guidance, driven by strong Permian and Gulf of America performance, despite Middle East disruptions. Q3 guidance is 1.4-1.44 million BOE/d.
Management outlined a long-term plan to increase annual sustainable cash flow by $4 billion by 2030, with ~85% of the improvement expected even at lower prices, anchored by lower sustained capex of $4.5 billion and a reduced decline rate.
Management discussed applying AI as an operational efficiency tool across the business, with plans to improve workforce efficiency through simplification and technology deployment, but provided no specific AI revenue or monetization details.
Management is decidedly optimistic about the company's trajectory, driven by a plan to enhance sustainable cash flow by $4 billion by 2030 through cost efficiency, lower sustaining capital, and continued debt reduction, all while forecasting production outperformance and operational strength.
Management confirmed 2026 capital guidance of $5.5-$5.9 billion and set 2027 starting point at $5.9 billion, with spending weighted to H1. By 2030 they expect sustaining capital to drop to $4.5 billion due to lower decline and better well costs, with mid-cycle projects funded that reduce sustaining capital over time.
Management expressed strong confidence in the company's efficiency gains, cash flow growth plan, and ability to deliver durable value, while acknowledging macro volatility and Middle East disruptions.
Reduces near-term production and adds operational uncertainty, impacting volumes and potentially logistics costs.
“lower international volumes due to Middle East disruptions”
Delays low-carbon venture capex rolloff and potential revenue from carbon capture operations.
“we expect full plant commissioning to begin around the end of the year as we transition to operations in 2027”
Adds variability to midstream earnings and could reduce quarterly cash flows.
“we see a significant volatility with respect to freight costs. And that could potentially impact our third quarter realization and also some potential delay or disruption to our sales.”
“Based on the efficiencies we have seen so far in Permian, the plan is to drop three rigs in Q4, but we're actually expecting to have 15 more wells online in Permian.”
“That spread has actually become even more narrower because there's almost three BCF of capacity that has already come online and potentially another two BCF coming online by the end of the fourth quarter.”
“For the full year, we are maintaining domestic lease operating expense guidance of $8.10 per BOE with efficiency gains and disciplined cost management helping to offset increasing CO2 cost pressure related to higher oil prices.”
| Показатель | Период | Диапазон | Середина | Статус |
|---|---|---|---|---|
| Capex | FY2027 | $5.9B | $5.9B | GUIDED |
| Capex | FY2030 | $4.5B | $4.5B | GUIDED |
| Free cash flow | FY2030 | $4B | $4B | GUIDED |
Oxy plans to drop three Permian rigs in Q4 but still expects 15 more wells online, illustrating a structural improvement in capital efficiency that could pressure service costs. — Every well drilled with fewer rigs is a negative leading indicator for onshore drilling and frack service demand, potentially capping price increases for service providers.
Yeah, thanks so much, guys. And a really great disclosure, Richard and Sunil. The first question is just on sustainable cost savings beyond reduction in interest expenses. Can you talk about how you're going to approach taking cost out of the business in a way that is sustainable?
Yeah, Neil, just want to... Richard mentioned about the efficiency and we have seen so far in 26, so a data point around that. Based on the efficiencies we have seen so far in Permian, the plan is to drop three rigs in Q4, but we're actually expecting to have 15 more wells online in Permian. And from a production point of view, once we adjust for the transaction we did in Permian EOR, the full year guidance is actually 7,000 more than the original guidance that we had given in 2016. in the fourth quarter call. So it again comes back to doing more with less. So this is just another indication of the continued and the relentless focus on operating efficiency.
Oxy expects higher oil prices to increase its CO2 costs in the Permian, as the cost of CO2 is now indexed to the price of oil, creating a direct linkage between commodity prices and operating costs. — Oxy's own CO2 costs being tied to oil prices is an interesting reveal of the CO2 supply economics in the Permian, suggesting that as oil prices rise, industrial CO2 suppliers can demand higher prices, a dynamic that could benefit major CO2 emitters with supply in the region.
… For the full year, we are raising total company production guidance. A stronger outlook for new well and base performance across our domestic assets is expected to offset marginally lower international volumes. For domestic lease operating expense, we expect third quarter costs to be $8.75 per BOE, reflecting the planned shift in maintenance activity and weather contingency in the Gulf of America. For the full year, we are maintaining domestic lease operating expense guidance of $8.10 per BOE with efficiency gains and disciplined cost management helping to offset increasing CO2 cost pressure related to higher oil prices. In midstream and marketing, we expect third quarter income to decline as the Vaha to Gulf Coast natural gas spread narrows. While the narrowing spread reduces midstream income, The impact is expected to be largely offset by stronger upstream gas realizations. Given the segment's strong year-to-date performance, we have increased full-year guidance by $300 million. We remain well positioned to capture commercial opportunities as market conditions develop. On capital, the program remains aligned with our full-year plan with weighting towards the first half of …
Gas realization swings in the Permian are tied directly to Permian takeaway capacity additions; over 3 BCF of capacity has come online and another 2 BCF is expected, which will structurally narrow Waha to Gulf Coast spreads. — The structural narrowing of the Waha basis due to new pipeline capacity directly impacts cash flows for midstream companies operating in the Permian basin, potentially reducing their future revenue growth prospects.
Great. My follow-up, is maybe for Sunil. Sunil, can you talk about some of the puts and takes around the midstream and marketing expectations for second half? Obviously, that's been a key driver of upside on the year-to-date basis, but how do you see that evolving? And perhaps you can give your views on sulfur pricing and Alhosen, the gas optimization with Waha now getting a little bit better, and just thoughts on crude marketing.
Hi, Arun. So if you look at what we've assumed for our third quarter guidance, the biggest change, as you've mentioned, is on the gas marketing side. You know, we have seen a significant narrowing of the spread between Baja and Gulf Coast, you know, with additional Permian takeaway capacity now coming online. But like I mentioned in my prepared remarks, we expect the impact of the narrower spread on the midstream income to be largely offset by upstream You know, with domestic income with the Permian gas price realization improvement. And just a data point on that, you know, with the larger Vaha to Gulf Coast spread in Q2, upstream domestic realized gas price in Q2 was around $2.50 worth in the first quarter. I mean, I think in the second quarter, I realized gas price was negative $1.50. So it was almost a $2.50 swing compared to the first quarter. and what we see is with the spread normalizing, we should see the domestic upstream realized gas price also to normalize. And then with respect to allosin and sulfur, what we've assumed is, you know, we have definitely seen the spot prices move higher in the third quarter, but sulfur from the Middle East is largely exported and the region actually supplies almost half of the global seaborne exports. You know, considering the situation, the current situation in the Middle East, we see a significant volatility with respect to freight costs. And that could potentially impact our third quarter realization and also some potential delay or disruption to our sales. So we have incorporated some of these factors into the third quarter guidance. and what I would say is with respect to the second half compared to what we thought where we would be when we provided the guidance in the last quarter, that spread has actually become even more narrower because there's almost three BCF of capacity that has already come online and potentially another two BCF coming online by the end of the fourth quarter. So with the capacity utilization coming in below 100%, even if there was some planned outages, We're not going to see the same kind of dislocation that we have seen in the last couple of quarters. You could see it for a short period, but we don't believe it's going to sustain for a long time.