Permian Resources Raises Oil Target to 192.5 MBO/d

Permian Resources Corp lifted its full-year 2026 oil production target to 192,500 barrels per day at the midpoint on Tuesday, May 6, 2026, raising guidance by 3,500 barrels per day after delivering record first-quarter free cash flow of 513 million U.S. dollars. The Midland-based Delaware Basin producer also disclosed that drilling and completion costs fell to about 685 dollars per lateral foot, a 6 percent reduction versus the 2025 program average.

Q1 Production Cleared the Top End of the Old Range

Permian Resources reported total production of 412,850 barrels of oil equivalent per day in the first quarter of 2026, comprising 192,349 bbl/d of oil, 103,338 bbl/d of natural gas liquids, and 702.979 million cubic feet per day of natural gas. Oil volumes alone landed at the upper bound of the prior 190,000 to 195,000 bbl/d range, prompting the midpoint lift to 192.5 thousand bbl/d. Total liquids and gas guidance now spans 400,000 to 430,000 boe/d, with capital expenditures budgeted at 1.75 to 1.95 billion dollars.

Co-Chief Executive Will Hickey credited "strong operational performance and quick reactions to higher March crude prices" for the upgrade. Co-CEO James Walter said the model generates "consistent free cash flow throughout cycles" via cost reduction, accretive bolt-ons, and organic development returns. The company closed approximately 40 bolt-on transactions totaling 205 million dollars during the quarter.

The Permian's Second-Most Aggressive Grower

Permian Resources is now the only public operator besides ExxonMobil calling for material year-over-year oil growth in the Permian in 2026. According to a May 2026 East Daley survey of 14 listed Permian producers, the basin will add roughly 183,000 bbl/d of oil in 2026, with Exxon alone contributing 113,000 bbl/d. Excluding Exxon, the remaining 13 operators are guiding only 1.2 percent collective growth. Permian Resources at 6 percent year-over-year is the standout exception.

The contrast with the Diamondback Energy guidance raise to 520 MBO/d disclosed earlier this month is instructive. Diamondback is the basin's largest pure-play producer by volume, but its 2026 growth profile is roughly flat after the Endeavor merger digestion. Permian Resources is smaller, but its lower starting base and disciplined bolt-on strategy allow it to compound at a faster percentage rate. Goldman Sachs and Wood Mackenzie analysts have flagged both producers as the operational benchmark for sub-700 dollar per lateral foot drilling economics in the Delaware sub-basin.

Investment Grade With 0.8x Leverage

The company finished the quarter with 3.4 billion dollars of net debt and a leverage ratio of 0.8 times trailing EBITDA. All three major rating agencies have now assigned investment-grade ratings: BBB-minus from S&P, Baa3 from Moody's, and BBB-minus from Fitch. Permian Resources declared a base dividend of 16 cents per share for the quarter, an annualized rate of 64 cents and a yield near 2.9 percent on Tuesday's intraday price.

Operating cash flow reached 815 million dollars against capital expenditures of 466 million, generating the 513 million adjusted free cash flow figure. The company eliminated the remaining Class C share structure during the quarter, simplifying the capital stack and reducing legacy sponsor ownership from roughly 45 percent in 2023 to zero. The 2026 program contemplates approximately 250 turn-in-line wells gross at 75 to 80 percent average working interest, with average lateral lengths near 11,000 feet.

Price Backdrop and Cost Implications

West Texas Intermediate crude was trading near 102.60 dollars per barrel on the CME in afternoon trading on Monday, May 18, 2026, according to OilPrice.com quotes pulled at approximately 13:00 MT. Brent traded near 109.40 dollars per barrel on the same screen, with WCS posting an indicative 93.07 dollars per barrel and Henry Hub natural gas at 3.034 dollars per MMBtu. At the current strip, Permian Resources' sub-700 dollar per lateral foot D&C cost translates to a Delaware horizontal breakeven near 38 to 42 dollars per barrel WTI, comfortably below current prices and giving the company room to absorb a multi-quarter slide before guidance would need to be defended.

The 6 percent D&C cost cut is consequential at scale. On the 250 well 2026 program, a 40 dollar per foot reduction across 11,000-foot laterals saves roughly 110 million dollars in annual capital intensity, equivalent to about a quarter of the company's quarterly capex.