Permian Basin Pumps Record 6.5 Million bpd Despite Rig Count Falling Below 300

The Permian Basin, straddling West Texas and southeastern New Mexico, has once again defied expectations, pumping a record 6.5 million barrels per day (bpd) of crude oil even as the active rig count has slipped below 300 for the first time since 2021. According to the latest Drilling Productivity Report from the US Energy Information Administration (EIA), output per rig has climbed to roughly 1,450 bpd, a 35% improvement over 2022 levels.

The productivity surge is being driven by longer laterals of up to 15,000 feet, simul-frac completions, and the widespread adoption of electric frac fleets powered by associated gas. Companies such as ExxonMobil, which absorbed Pioneer Natural Resources for US$59.5 billion, Chevron and Diamondback Energy are now able to maintain flat or growing production with significantly less capital expenditure, with breakevens reportedly falling below US$40 per barrel in the core Midland sub-basin.

For Trinidad and Tobago, the implications stretch across the entire Caribbean trade lane. The Permian's light, sweet WTI Midland grade increasingly competes for refining slots on the US Gulf Coast and in Europe, displacing medium and heavy barrels traditionally supplied by Venezuela, Mexico and, to a lesser extent, T&T's own Galeota and Calypso streams. Heritage Petroleum, which markets its crude on a Brent-linked basis, has had to accept tighter differentials as Gulf Coast refiners optimise around cheaper domestic supply.

The flood of Permian barrels into the Atlantic Basin has also been a structural negative for Brent-WTI spreads, which narrowed to under US$3.50 per barrel in recent weeks. This has knock-on effects for the Point Lisas petrochemicals complex, where ammonia and methanol producers benchmark feedstock and product pricing against US Gulf Coast indices. Trinidad's natural gas producers, including BP Trinidad and Tobago (bpTT), Shell and EOG Resources, are watching closely as associated gas from the Permian continues to depress Henry Hub prices, which the EIA expects to average US$3.10 per MMBtu in 2026.

Pipeline takeaway capacity remains a key constraint that could yet limit Permian growth. The Matterhorn Express Pipeline came online in late 2024, adding 2.5 billion cubic feet per day of gas evacuation, while crude takeaway is supported by EPIC, Gray Oak and Cactus II. However, water disposal and seismicity in the Delaware sub-basin are emerging as binding constraints that could moderate the pace of growth from 2026 onwards.

For T&T policymakers, the Permian story underscores the urgency of unlocking deepwater and cross-border gas resources. With the Loran-Manatee field straddling the maritime boundary with Venezuela, and Shell's Manatee development targeting first gas in 2027, the country is racing to maintain its position as the Caribbean's energy hub. Energy Chamber CEO Dr Thackwray Driver has repeatedly warned that without timely sanctioning of new gas projects, Trinidad risks ceding ground to lower-cost US LNG and petrochemicals exports flowing out of Corpus Christi and Freeport.