Q: How much oil does Texas have left — proved reserves, undiscovered resources, and production outlook as of mid-2026?
Answer
Texas holds more proved crude oil and lease condensate reserves than any other U.S. state, though those reserves declined 3% (529 million barrels) in 2024 — the largest absolute drawdown among all states that year — per the EIA's Year-End 2024 proved reserves report. As of year-end 2023 (the most granular state-level EIA breakout publicly available), Texas carried roughly 20.1 billion barrels of proved reserves, with the Permian Basin and Eagle Ford as the dominant contributors. The Permian is by far the most consequential asset: a January 2026 USGS assessment of the Woodford and Barnett shale formations within the Permian Basin (USGS Fact Sheet 2026-3059) identified an additional 1.6 billion barrels of undiscovered, technically recoverable oil in those deeper formations alone, on top of an earlier USGS assessment estimating 46.3 billion barrels of undiscovered, technically recoverable oil in the Wolfcamp and Bone Spring formations. These are undiscovered resource estimates — geological potential, not proved reserves — and they are not immediately economically productive. At the other end of the maturity spectrum, a June 2026 USGS assessment (Fact Sheet 2026-3015) of the Buda Limestone, a conventional formation underlying the Eagle Ford, found only 12 million barrels of undiscovered technically recoverable oil remaining after the formation has produced roughly 204 million barrels since 1930 — a signal that the oldest conventional plays beneath Texas are approaching exhaustion. Texas currently produces in the range of 5.6–5.8 million barrels per day, accounting for roughly 40–45% of total U.S. crude output, with the Permian region alone having accounted for almost half of all U.S. crude production in 2025 (EIA STEO, January 2026). So the honest answer is: Texas has enormous oil remaining in its Permian stacked-pay formations — measured in tens of billions of barrels of geological resource — but the oldest conventional plays are depleting, proved reserves ticked down in 2024 under lower price incentives, and the economics of reaching deeper undiscovered resources depend heavily on commodity price.
Why This Matters
Texas produces more crude oil than all but a handful of countries globally, and the trajectory of its reserves directly determines U.S. energy security and global supply balances. The divergence between a depleting conventional base (Buda Limestone) and vast but deep unconventional upside (Wolfcamp, Woodford, Barnett shales) illustrates the central challenge for operators: proved reserves are price-sensitive stocks, not fixed inventories, and future resource conversion depends on drilling economics that are increasingly pressured by sub-breakeven WTI price forecasts.
Key Factors (7)
Proved reserves are price-sensitive, not fixed
EIA's Year-End 2024 report shows Texas proved reserves fell 529 million barrels (3%) in 2024, primarily because WTI averaged $76.63/bbl in 2024 — below the threshold at which operators book marginal Permian inventory. Proved reserves expand and contract with the economic price deck, not just geology.
Permian Basin undiscovered resource base remains vast
The USGS has assessed 46.3 billion barrels of undiscovered technically recoverable oil in the Wolfcamp and Bone Spring alone, and an additional 1.6 billion barrels in the deeper Woodford and Barnett shales (USGS, January 2026). These figures represent mean estimates of geological potential under continuous-resource methodology — not drillable proved reserves.
Buda Limestone conventional play is nearly exhausted
The USGS June 2026 assessment (Fact Sheet 2026-3015) found only 12 million barrels of undiscovered technically recoverable oil remaining in the Buda Limestone after ~96 years and 204 million barrels of cumulative production. This is the clearest recent data point on conventional-play exhaustion in Texas.
Eagle Ford shale above the Buda remains productive
Eagle Ford output held in a 2.36–2.46 million boepd range through March 2026, up 2.2% year-over-year on a boe basis (per Mercer Capital as cited in OilPrice.com, June 2026). The Eagle Ford shale itself is a distinct and substantially larger resource than the depleted conventional Buda formation beneath it.
Permian production breakeven prices now exceed EIA's price forecast
The Dallas Fed Q1 2026 Energy Survey puts average Permian Basin breakeven drilling prices at $67/bbl, up from $65/bbl a year earlier. The EIA's January 2026 STEO forecast WTI at $52/bbl for 2026 and $50/bbl for 2027 — below breakeven for most new Permian wells — which means the resource base does not automatically translate into active production growth.
Texas output currently running near record levels but facing deceleration
The EIA forecast U.S. crude production at 13.5 million b/d for 2026 — roughly 100,000 b/d below the 2025 record of 13.6 million b/d — with Permian production projected to hold near its 2025 average of 6.6 million b/d before slipping to 6.5 million b/d in 2027 (EIA STEO, January 2026). Texas represents the majority of Permian output.
Depth and access economics limit near-term conversion of deeper resources
The newly assessed Woodford and Barnett shale formations in the Permian sit at depths of 18,000–20,000 feet, deeper than most current drilling targets. Prior to advances in horizontal drilling and hydraulic fracturing, these formations were considered uneconomic — and they remain higher-cost inventory relative to shallower Wolfcamp and Bone Spring benches.
What to Watch (5)
EIA Year-End 2025 Proved Reserves release (expected late 2026)
This will show whether Texas reserves recovered from the 529 million barrel 2024 decline or continued to erode under sub-$65/bbl WTI. A second consecutive year of decline would confirm a structural inventory drawdown, not just a price-driven reclassification.
WTI front-month price vs. $67/bbl Permian breakeven
The Dallas Fed Q1 2026 survey puts average Permian breakeven at $67/bbl. If WTI sustained above that level — note that the current geopolitical environment (U.S.-Iran conflict, Red Sea disruptions as of July 2026) has pushed Brent near $100/bbl per The Guardian's July 23, 2026 live coverage — the economics for new Permian drilling improve materially and proved reserve bookings could rebound.
Rig count in the Permian Basin
The EIA forecasts that a slowdown in Permian drilling activity will outpace productivity gains. Weekly Baker Hughes rig count data for the Permian serves as the earliest leading indicator of whether operators are responding to price signals with capital deployment or continued restraint.
USGS assessments of remaining Permian formation inventory
The USGS has been issuing systematic assessments of individual Permian formations. Future assessments of shallower, higher-volume plays like the Spraberry or Bone Spring — beyond the Woodford/Barnett already released — would materially update total undiscovered resource estimates.
Major operator capital allocation decisions for 2027
Large Permian operators (those with production above 10,000 b/d) carry a $59/bbl breakeven per the Dallas Fed Q1 2026 survey — below current elevated price levels if the geopolitical premium holds. Their FY2027 capex guidance, expected in Q3–Q4 2026 earnings, will signal whether the resource base is being actively developed or held as inventory.
Caveats & Uncertainty (3)
Texas state-level proved reserves figure is as of year-end 2023 from EIA state breakouts; the year-end 2024 figure is confirmed only as a net change (-529 million barrels, -3%)
The most precise Texas-specific proved reserves number in the public record is the ~20.1 billion barrel figure as of 2023 (via EIA data cited by Statista). The 2024 EIA Year-End report confirms a 529 million barrel decline but does not provide a revised Texas-total figure in the search results retrieved — the updated absolute figure is unverified as of today's date.
USGS undiscovered resource estimates are technically recoverable mean estimates, not proved reserves, and should not be compared directly
The 46.3 billion barrel Wolfcamp/Bone Spring figure and the 1.6 billion barrel Woodford/Barnett figure are geological assessments of what could exist and be extracted under defined technical conditions. Conversion to proved reserves requires drilling, appraisal wells, operator commitments, and economic viability at a specific price deck — none of which are guaranteed.
The geopolitical price spike (Brent near $100/bbl as of July 23, 2026) may temporarily improve Texas drilling economics but is not a structural change to the reserve base
War-premium oil prices can pull forward Permian drilling activity and enable marginal proved reserve bookings. However, if the conflict de-escalates and prices revert toward EIA's $52/bbl 2026 forecast, the reserve picture deteriorates again. The current price environment reflects a specific geopolitical shock, not a new structural price floor.