Texas sits atop multiple lithium-bearing geological formations, and recent analyses of thousands of formation-water samples confirm that several intervals across the state contain lithium concentrations high enough to attract commercial interest. The deposits are not the classic hard-rock mines or salt-flat evaporation ponds you might picture from Australia or South America. Instead, most of the state’s lithium is dissolved in underground brines, many of them already being pumped to the surface as a byproduct of oil and gas production. Whether that dissolved lithium can be economically recovered is the question driving a growing amount of research, investment, and legal wrangling.
Where the Lithium Sits Underground
A study analyzing roughly 2,450 formation-water samples from Texas and neighboring Gulf Coast states found that lithium concentrations vary enormously depending on the rock layer and location. Background levels across the region sit in the range of zero to about 20 milligrams per liter, with the overall distribution showing a median of 9 mg/L and an average of 29 mg/L. But certain formations stand out well above those averages.1Elsevier / Journal of Geochemical Exploration. Controls on lithium content of oilfield waters in Texas and neighboring states (USA)
Three intervals in Texas have returned samples at or above 100 mg/L lithium. The Jurassic Smackover Formation, already well known for its lithium-rich brines in Arkansas, extends along the Gulf Coast into Texas, Louisiana, and Mississippi, where several samples reached that threshold. The Permian and Pennsylvanian Granite Wash in the Anadarko Basin of the Texas Panhandle also returned samples above 100 mg/L, though that finding has not been independently confirmed. And the Cretaceous Edwards Formation of South Texas likewise produced several samples at or above 100 mg/L.1Elsevier / Journal of Geochemical Exploration. Controls on lithium content of oilfield waters in Texas and neighboring states (USA)
To put those numbers in perspective, the richest known brine deposits in the Arkansas portion of the Smackover Formation top 400 mg/L, and researchers have estimated the total dissolved lithium resource in that Arkansas zone alone at between 5.1 and 19 million tons. That range represents roughly 35 to 136 percent of the entire previously estimated U.S. lithium resource.2PubMed Central. Evaluation of the lithium resource in the Smackover Formation brines of southern Arkansas using machine learning Texas concentrations are lower than that Arkansas sweet spot, but the sheer volume of brine already being handled by the state’s oil and gas industry means even moderate lithium levels could add up to a meaningful resource if extraction proves economical.
The Round Top Rhyolite in Trans-Pecos Texas
Not all of Texas’s lithium is dissolved in brine. In the far western corner of the state, the Round Top laccolith near Sierra Blanca contains a different type of deposit altogether. This rhyolite formation is enriched in lithium along with beryllium, fluorine, niobium, tin, uranium, yttrium, zirconium, and a suite of rare earth elements.3Minerals. Petrogenesis of Heavy Rare Earth Element Enriched Rhyolite: Source and Magmatic Evolution of the Round Top Laccolith, Trans-Pecos, Texas It is an unusual geological oddity: a dome of volcanic rock where the original magma was so enriched in incompatible elements that they are now distributed throughout the entire rock mass rather than concentrated in discrete veins.
Round Top has attracted attention primarily for its rare earth elements, which are critical to electronics and defense applications. The lithium content is a potential bonus rather than the main attraction. Extracting minerals from a hard-rock source like Round Top requires crushing and leaching the rock, a fundamentally different process from pulling dissolved metals out of a liquid brine. Development at Round Top has moved slowly, in part because the economics of processing low-grade bulk deposits remain challenging and the permitting process in the region is complex. Still, the site represents a geologically distinct lithium resource that could complement brine-based recovery elsewhere in the state.
How Direct Lithium Extraction Works
The technology that makes Texas brine deposits commercially interesting is direct lithium extraction, commonly abbreviated DLE. Traditional lithium production from brines, as practiced in the salt flats of Chile and Argentina, involves pumping brine into massive evaporation ponds and waiting months for the sun to concentrate the lithium. That approach requires arid climates, enormous land areas, and large volumes of water. It is not a good fit for the humid Gulf Coast or the already-industrialized Permian Basin.
DLE skips the evaporation step. Instead, it runs brine through a material that selectively grabs lithium ions while letting everything else pass through, then releases the lithium into a clean solution. One promising class of these materials is based on manganese oxide compounds. In laboratory testing, manganese oxide sorbents have achieved lithium recovery rates of around 86 percent from brine.4PubMed Central. Synthesis of Manganese Oxide Sorbent for the Extraction of Lithium from Hydromineral Raw Materials The process is driven by a chemical reaction at the sorbent surface, and the speed of lithium uptake is governed by that reaction rather than by how fast the liquid flows, which matters for designing systems that can handle the enormous volumes of brine a typical oil well produces.
Compared to conventional hard-rock mining of lithium-bearing minerals like spodumene, DLE-based approaches tend to use less energy and generate lower environmental impacts. A recent holistic comparison of conventional mining, DLE, and electrochemical extraction from spodumene found that DLE achieved the highest profitability among the three, while electrochemical methods offered the lowest carbon footprint.5Green Chemistry. Conventional vs. direct vs. electrochemical lithium extraction: a holistic TEA–LCA of lithium carbonate production from spodumene That comparison was for hard-rock feedstocks rather than oilfield brines, but it illustrates why DLE has become the favored approach for new projects: it threads the needle between cost and environmental performance better than the alternatives.
Which Extraction Methods Suit Texas Brines
Not every DLE technique works equally well at every lithium concentration. A comparative feasibility study of extraction technologies for U.S. oilfield brines found that adsorption, chemical precipitation, and solvent extraction are the most practical methods overall, based on efficiency, environmental impact, and cost. The study highlighted that adsorption is particularly well suited for low-lithium-concentration sources like the brines found in the Bakken formation and the Delaware Basin portion of the Permian, because adsorption-based sorbents are highly selective even when lithium is a tiny fraction of the dissolved solids. Chemical precipitation, on the other hand, works better for high-concentration sources like the Smackover Formation brines in Arkansas.6Elsevier / Desalination and Water Treatment. Comparative feasibility of lithium extraction technologies in U.S. oilfields
For Texas specifically, this means different parts of the state may need different technology pathways. The Permian Basin, where lithium concentrations tend to be lower but brine volumes are massive, is a natural fit for adsorption-based DLE. The Gulf Coast Smackover and Edwards Formation zones, where concentrations are higher, could potentially support chemical precipitation or a hybrid approach. Choosing the right method matters because the economics of lithium recovery from brines are tight: the lithium is dilute compared to a dedicated lithium mine, so the extraction step needs to be cheap and efficient enough to make sense on top of the oil and gas operations that are already paying for the wells and pumps.
The Permian Basin as a Produced-Water Opportunity
The Permian Basin generates staggering volumes of produced water, the salty fluid that comes up alongside oil and gas. Managing that water is one of the industry’s biggest headaches. Operators currently dispose of most of it by injecting it back underground into saltwater disposal wells, but that practice is running into problems: tightening regulatory limits, rising disposal costs, and growing concern about induced seismicity from injection. Researchers have been developing frameworks that treat this waste stream not as a liability but as a potential feedstock for mineral recovery.
A Permian Basin case study built an integrated decision-support model that routes produced water through various treatment and mineral-recovery modules, including desalination and direct lithium extraction, before directing it to end uses like hydraulic fracturing reuse, beneficial surface reuse, or conventional disposal. The optimization framework simultaneously maximizes economic returns, minimizes disposal volumes, and reduces the risk of injection-related seismicity.7Water. Surrogate-Assisted Techno-Economic Optimization to Reduce Saltwater Disposal via Produced-Water Valorization: A Permian Basin Case Study The chemistry-rich produced water in the basin contains not just lithium but also boron, strontium, and other dissolved constituents that could be recovered alongside it.
This dual benefit is a key selling point for lithium extraction in Texas. If operators can offset disposal costs and generate revenue from recovered minerals at the same time, the economics of DLE look much more attractive than they would for a standalone lithium-from-brine operation. The infrastructure is already there: wells are drilled, pumps are running, and the brine is already at the surface. The question is whether bolting on a DLE module pencils out.
Geothermal Energy and Lithium Together
Another angle under investigation is co-producing lithium with geothermal energy. The U.S. Geological Survey has analyzed subsurface data across the Gulf Coast to identify areas where lithium-bearing brines and economically useful geothermal heat coexist. The analysis evaluated temperature, lithium brine content, and reservoir quality across thirty-four depositional units to map where both resources are likely present in the same formations.8Geothermal Resources Council. Potential for co-production of lithium and geothermal resources in the Gulf Coast
The logic is appealing: a geothermal power plant already pumps hot brine from deep underground, runs it through a heat exchanger to generate electricity, and then reinjects it. If that brine also contains lithium, you can add a DLE step to the loop and pull out lithium without drilling any new wells or handling any additional fluid. The geothermal energy itself can power the extraction process, reducing both the carbon footprint and the operating cost. Parts of the Texas Gulf Coast sit over formations with the right combination of temperature and brine chemistry, though commercial-scale projects pairing the two resources in Texas have not yet materialized.
Who Owns the Lithium Under Texas Land
Even if the geology and the technology cooperate, a thorny legal question could slow development: who actually owns lithium dissolved in underground water in Texas? The answer is less obvious than you might think, because Texas property law draws a sharp line between minerals and water, and lithium dissolved in brine sits right on that line.
Under Texas law, underground water belongs to the surface owner. Minerals, by contrast, typically belong to the mineral estate, which in many cases has been severed from the surface estate and sold to someone else. Legal analysis suggests that lithium would likely be classified as part of the mineral estate under either of the two tests Texas courts use to decide what counts as a mineral. Lithium is plainly a mineral in the ordinary sense of the word, and DLE at an existing wellbore would impact the surface far less than traditional mining methods, which cuts against the policy rationale for excluding certain substances from the mineral estate.9Baker Botts. Ownership of Lithium in Water Reservoirs May Hinge on Texas Law
But the picture gets complicated fast. If the lithium is dissolved in groundwater and a surface owner claims the water, do they also claim the lithium in it? Texas courts have recently held that produced water generated during oil and gas operations belongs to the mineral estate, not the surface owner. Whether that precedent extends to lithium-bearing groundwater that is not produced as part of oil and gas activity is untested.9Baker Botts. Ownership of Lithium in Water Reservoirs May Hinge on Texas Law Until courts or the legislature clarify the rules, companies pursuing DLE in Texas face the risk that the ownership of their target resource could be disputed. Lease agreements in the state will need to account for this ambiguity, and some early movers are reportedly negotiating separate lithium rights alongside traditional mineral leases.
What Separates Texas from Arkansas
Discussions of lithium in the Gulf Coast region inevitably circle back to the Smackover Formation in southern Arkansas, where concentrations exceed 400 mg/L and the estimated in-place resource is enormous. ExxonMobil and Standard Lithium both have major projects under development there. The same Smackover Formation extends into Texas, but the lithium concentrations on the Texas side are generally lower. Several Texas samples from the Smackover along the Gulf Coast reached or exceeded 100 mg/L, which is commercially interesting but a step below the richest Arkansas zones.1Elsevier / Journal of Geochemical Exploration. Controls on lithium content of oilfield waters in Texas and neighboring states (USA)
Arkansas also has a head start in that its Smackover brines are already being pumped to the surface by the bromine industry, which provides a ready-made waste stream for DLE. In fact, researchers estimated that roughly 5,000 tons of dissolved lithium were brought to the surface in Arkansas in 2022 just as an incidental byproduct of bromine and oil-and-gas production.2PubMed Central. Evaluation of the lithium resource in the Smackover Formation brines of southern Arkansas using machine learning Texas does not have a comparable bromine industry along its Gulf Coast, so the existing brine-handling infrastructure is more oriented toward produced water from hydrocarbon extraction. That infrastructure is vast but dispersed, and the brine chemistry varies more from well to well than it does in a single concentrated bromine-producing zone.
The practical upshot is that Texas lithium development will probably look different from the Arkansas model. Rather than a few large, centralized extraction plants fed by dedicated brine wells, Texas operations may involve modular DLE units installed at oilfield water-handling facilities across a wide area. The per-unit lithium yield will be lower, but the aggregate volume could still be substantial given the scale of Texas oil and gas production.
How Federal Policy Shapes the Timeline
Domestic lithium production of any kind has gotten a boost from U.S. policy aimed at reducing dependence on foreign supply chains for critical minerals. The Inflation Reduction Act’s electric vehicle tax credits include provisions tying incentives to the domestic sourcing or processing of battery minerals, lithium chief among them. This creates a price floor of sorts for U.S.-produced lithium: manufacturers building battery plants in the U.S. have a financial incentive to buy from domestic suppliers even if the sticker price is higher than imported lithium from Chile or Australia.
For Texas, this policy environment shifts the math in favor of projects that might not have penciled out on commodity pricing alone. A DLE operation pulling lithium from Permian Basin produced water does not need to compete head-to-head on cost with a massive evaporation-pond operation in the Atacama Desert if the lithium it produces qualifies for domestic-content credits. Whether those policy incentives survive shifting political winds is anyone’s guess, but they have already catalyzed investment in pilot projects across the state.
Water Use and Environmental Trade-Offs
One of the more underappreciated aspects of brine-based lithium extraction in Texas is its relationship to water. Conventional lithium production from evaporation ponds in South America has been criticized for consuming large volumes of freshwater in arid regions. Extracting lithium from oilfield produced water in Texas flips that dynamic: the water being processed is a waste product that would otherwise be injected underground at significant cost and environmental risk. DLE does not consume fresh water; it processes water that has already been brought up and needs to go somewhere.
Reducing the volume of produced water sent to saltwater disposal wells also addresses the induced seismicity concern that has become a major issue in West Texas. Earthquakes linked to deep wastewater injection have increased in frequency and severity in the region, prompting regulatory action to limit injection volumes. If DLE and associated water-treatment technologies can divert a meaningful fraction of produced water away from disposal wells and toward beneficial reuse, the seismicity risk drops along with the disposal costs. The Permian Basin optimization framework described earlier explicitly treats disposal-volume reduction and injection-risk minimization as objectives alongside profit.7Water. Surrogate-Assisted Techno-Economic Optimization to Reduce Saltwater Disposal via Produced-Water Valorization: A Permian Basin Case Study
That said, DLE is not impact-free. The sorbents and chemicals used in the process have their own supply chains and waste streams. Spent sorbents need to be regenerated or disposed of. The brine that remains after lithium is removed still contains high concentrations of salts and other dissolved solids and must be managed responsibly. Scaling DLE from laboratory demonstrations to commercial-volume operations in the field will surface engineering and environmental challenges that pilot projects have not fully resolved.
Lithium Concentrations in Context
It helps to understand what the numbers mean in practical terms. When researchers report lithium concentrations in brines, they are measuring milligrams of lithium per liter of fluid. Most Texas formation waters fall in the single digits to low twenties, with that statewide median sitting around 9 mg/L.1Elsevier / Journal of Geochemical Exploration. Controls on lithium content of oilfield waters in Texas and neighboring states (USA) The standout zones where concentrations reach 100 mg/L or higher are exceptions rather than the rule. For comparison, seawater contains about 0.17 mg/L of lithium, so even the lowest Texas oilfield brines are enriched by a factor of roughly 50 relative to the ocean.
Whether a given concentration is “enough” depends entirely on the extraction technology, the volume of brine available, and the price of lithium. At current lithium carbonate prices and the efficiency levels demonstrated by adsorption-based DLE, concentrations below about 50 mg/L are generally considered marginal. Above 100 mg/L, the economics start to look more favorable, especially when the brine is already being pumped and the operator is already paying to dispose of it. The sweet spot for Texas is likely the higher-concentration zones in the Edwards, Smackover, and Granite Wash formations, at least until DLE costs come down enough to make lower-grade brines worthwhile.