Burning Money: Waha Gas Price

Key Takeaways

• 22 Bcf/d associated gas from Permian tight‑oil drilling overwhelms pipelines.
• 47 consecutive negative‑price days cost producers $300‑400 million in April.
• Pipeline capacity expansions of 4.5 Bcf/d expected in late 2026.
• Lack of firm transport contracts stalls midstream investment despite high gas volumes.
• Unused gas could feed Gulf Coast LNG terminals, boosting export revenues.

Pulse Analysis

The Permian Basin’s rapid shift to horizontal, multistage fracturing unlocked unprecedented oil volumes, but the associated‑gas byproduct now exceeds the region’s pipeline bandwidth. While the basin produces roughly 6 MMb/d of oil, its residue gas—about one‑fifth of U.S. marketed output—faces a bottleneck as existing take‑away lines operate near capacity and spring maintenance removes 1‑2 Bcf/d of throughput. This structural mismatch turns the cash market on its head, with producers paying to move molecules rather than curtailing oil flow, a dynamic that highlights the need for integrated planning between upstream drilling and midstream logistics.

Economically, the negative‑price streak has a two‑fold impact. First, the immediate disposal cost—estimated at $300‑$400 million for April alone—directly dents cash flow and raises the breakeven price for marginal oil wells. Second, the cumulative effect since 2019, exceeding $2.5 billion, erodes investor confidence and delays capital deployment for new infrastructure. Midstream firms, wary of long‑term ship‑or‑pay obligations, have postponed projects until basis differentials threaten core oil economics, creating a classic chicken‑and‑egg problem that hampers both gas monetization and LNG export readiness.

Looking ahead, a suite of pipeline projects—Golden Pass (2.6 Bcf/d), Gulf Coast Express (+0.57 Bcf/d), Blackcomb (2.5 Bcf/d) and others—aim to add roughly 4.5 Bcf/d of takeaway capacity by late 2026. If these lines secure firm contracts, stranded gas could be redirected to premium LNG markets, unlocking export revenues and stabilizing regional pricing. Policymakers and investors, however, must align regulatory timelines and financing mechanisms to ensure that infrastructure keeps pace with drilling activity, preventing future negative‑price episodes and sustaining the Permian’s role as a cornerstone of U.S. energy production.