Reuse, Recovery & Stormwater
Lithium Extraction from Water Companies
Direct lithium extraction (DLE) from brines and produced water, adsorption, ion exchange, and membrane-based systems.
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Lithium Extraction from Brines and Geothermal Waters: DLE, Evaporation Pond, and Membrane Technologies
Lithium extraction from brine sources (salt lake brines, geothermal brines, oilfield produced water) uses three main technology families. Traditional solar evaporation ponds (used in Atacama, Bolivia, Argentina) concentrate lithium from 200 to 1,500 mg per L to 60,000 mg per L by 12 to 18 months of evaporation, then recover lithium as lithium carbonate by precipitation. Evaporation ponds require flat, arid terrain with high evaporation rates; they are economically practical only in specific geographies, have high water consumption (evaporating large volumes), and are poorly suited to temperate or humid climates.
Direct Lithium Extraction (DLE) technologies selectively extract lithium from brine without full evaporation, reducing water consumption and project timeline from years to hours or days. DLE technologies include: ion exchange sorbents (lithium manganese oxide (LMO) or lithium iron phosphate (LFP) sorbents with capacity 10 to 30 mg Li per g sorbent, selectivity over Na, K, Mg, Ca above 1,000:1); solvent extraction (ionic liquids or organophosphate extractants); and membrane electrodialysis (LiTAS, bidirectional ion transport). DLE produces a lithium-rich eluate at 1,000 to 5,000 mg per L Li, which is then purified by RO concentration and chemical precipitation to battery-grade lithium carbonate (99.5 percent purity minimum) or lithium hydroxide.
Water management is central to lithium brine projects. Brine extraction affects regional groundwater and surface water hydrology; environmental impact assessment must quantify brine reinjection volumes and quality, and surface water level changes. Geothermal brine DLE (Salton Sea region, California; Vulcan Energy, Germany) extracts lithium from hot brines (150 to 300 degrees C, 200 to 400 mg per L Li) already brought to surface for power generation, then reinjects the depleted brine - a zero-net-surface-impact model. Freshwater use for DLE sorbent washing and chemical processing is 10 to 50 times lower per tonne of lithium than solar evaporation. Regulatory frameworks for brine extraction differ globally: US requires NEPA environmental review; Chile and Argentina require lithium production quota agreements.
Frequently Asked Questions
What is Direct Lithium Extraction (DLE) and how does it differ from evaporation ponds?
Direct Lithium Extraction (DLE) selectively removes lithium from brine using sorbents, ion exchange resins, membranes, or solvent extraction without concentrating the entire brine by evaporation. DLE advantages: (1) Speed - hours to days vs 12 to 18 months for evaporation; (2) Recovery rate - 80 to 90 percent vs 40 to 50 percent for evaporation ponds; (3) Water savings - 80 to 95 percent less freshwater consumed; (4) Geography independence - works in humid climates where evaporation is insufficient; (5) Selectivity - produces lithium concentrate directly, avoiding co-precipitation of impurities that complicate downstream processing. Trade-offs: DLE capital cost is higher than simple evaporation ponds, and sorbent regeneration requires acid or hot water, adding operating cost. Technology readiness levels vary: ion exchange sorbents (most mature, commercial deployments), solvent extraction (commercial in some applications), electrodialysis (pilot to demonstration scale).
What water quality is needed for lithium extraction processing?
DLE sorbent performance is sensitive to feedwater quality: high concentrations of competing divalent cations (Mg2+, Ca2+) reduce lithium selectivity and sorbent capacity. Mg:Li ratio is a key brine quality metric: below 10:1 is suitable for most DLE technologies; above 40:1 (common in Atacama southern zones) requires pre-treatment by nanofiltration (rejects Mg2+ at 90 to 98 percent while passing Li+ at 20 to 50 percent selectivity, reducing Mg:Li ratio). Suspended solids must be below 1 to 5 mg per L to prevent sorbent fouling (pre-filtration by multimedia filter or cartridge filter). Fe, Mn, and silica must be controlled (below 0.1 mg per L Fe and Mn; below 20 mg per L SiO2) to prevent precipitation on sorbent surfaces during the high-pH elution step. Process water for sorbent washing (typically deionised or RO water) must be very low in lithium itself to prevent back-dilution of the eluate.
What are the environmental impacts of lithium brine extraction?
Water-related environmental impacts: (1) Brine aquifer drawdown - extraction of lithium brine reduces aquifer levels; inadequate reinjection volumes can lower shallow freshwater table and affect wetland ecosystems. Atacama wetlands supporting flamingo populations are under study for impacts from lithium brine extraction. (2) Surface water diversion - water used in brine processing (washing, chemical processing) diverts freshwater from water-scarce regions; Chilean DGA (water authority) regulates freshwater use in mining. (3) Evaporation pond area - ponds covering tens of km2 affect local hydrology and habitats. (4) Chemical contamination risk - acid and base reagents used in DLE processing require bunded storage and secondary containment. Responsible mining frameworks (Initiative for Responsible Mining Assurance, IRMA) and IFC Performance Standards require social and environmental management plans, water balance studies, and stakeholder engagement with local indigenous communities.
Can lithium be extracted from seawater?
Seawater contains 0.17 mg per L Li (compared to 200 to 1,500 mg per L in Atacama brines), making direct extraction from seawater energetically and economically challenging with current technologies. LMO sorbents can selectively adsorb lithium from seawater, but the dilute concentration requires processing enormous volumes (approximately 5,900 m3 seawater per kg Li vs approximately 2 m3 brine per kg Li for Atacama operations). Energy consumption is 30 to 60 times higher per tonne of lithium vs brine DLE. Research is active in Japan and South Korea (island nations with limited terrestrial lithium deposits) using combined desalination + lithium extraction systems to extract lithium from seawater concentrate (brine reject from SWRO plants, containing 0.34 mg per L Li, approximately twice seawater). No commercial seawater lithium extraction plant operates as of 2026; demonstration scale projects have been reported in China and Japan.
A geothermal energy developer in Cornwall (United Kingdom) co-producing hot brine at 180 degrees C from deep granite aquifers sought to evaluate lithium extraction from the brine as a secondary revenue stream. Brine lithium concentration was 220 mg per L with high competing cation concentrations (Mg:Li ratio of 6:1, Na concentration 14,000 mg per L). The developer needed to demonstrate commercial viability to investors before committing to a pilot plant.
Conducted a DLE sorbent feasibility study: laboratory-scale LMO sorbent columns were run with synthetic brine at site concentrations to determine equilibrium lithium capacity, selectivity over Mg and Na, and acid elution characteristics. Scaled the laboratory data to a 50 L per hr pilot plant design with a cost model for a full commercial DLE unit co-located with the geothermal power plant, using waste heat from the geothermal cycle for sorbent drying.
LMO sorbent achieved 88 percent lithium selectivity over magnesium at site Mg:Li ratio, with sorbent capacity of 18 mg Li per g. Pilot plant design projected lithium recovery of 75 percent from 200 m3 per day of brine, yielding 3.3 tonnes of lithium carbonate equivalent per year. The cost model demonstrated positive NPV over 10 years at lithium carbonate prices above 12,000 USD per tonne, providing investor confidence for pilot plant funding.
Questions to Ask Shortlisted Providers
- 1
What DLE technology do you propose for our specific brine chemistry, and has the technology been validated at pilot or commercial scale on brines with a similar Mg:Li ratio and competing cation profile?
DLE technology performance is highly sensitive to brine chemistry. An LMO sorbent validated on Atacama brine (Mg:Li 6:1) may perform very differently from oilfield produced water (Mg:Li 200:1). Ask for laboratory treatability data or pilot plant results using brine samples from your specific source, not from reference brines with different chemistry. Technology readiness level matters too: commercial vs pilot vs laboratory validation represents very different project risk.
- 2
What are the water management requirements for DLE sorbent washing, and how will the wash water volume and quality affect the site water balance?
DLE sorbent washing (to elute lithium and regenerate the sorbent) requires low-lithium water, typically deionised or RO permeate at very low lithium concentration. For a site in a water-stressed region, the wash water volume (typically 3 to 8 m3 per kg of lithium recovered) must be factored into the site water balance and abstraction licence. DLE processes that are self-described as 'low water' must quantify this precisely for your brine composition.
- 3
What lithium product specification does the downstream market require, and does the proposed DLE process reliably achieve that specification?
Battery-grade lithium carbonate requires above 99.5 percent purity with strict limits on Mg, Na, K, Ca, B, and Fe impurities. DLE eluate contains elevated concentrations of competing ions that must be removed by downstream purification (crystallisation, recrystallisation, nanofiltration). A DLE process that produces 97 percent purity lithium carbonate cannot access the battery precursor market and is worth significantly less per tonne. Confirm the downstream purification steps and the achievable product specification.
- 4
What regulatory approvals are required for brine extraction at our site, and how long will the permitting process take?
Brine extraction from deep geological formations in the UK requires an environmental permit from the Environment Agency for any dewatering above 20 m3 per day, and may require planning consent for surface processing facilities. In Chile and Argentina, lithium brine extraction is subject to national resource regulation and indigenous community consultation requirements. The permitting timeline (typically 12 to 36 months for a new brine extraction operation) is often the critical path item for project development.
- 5
What is the projected price sensitivity of the business case, and at what lithium carbonate price does the project become unviable?
Lithium carbonate prices have ranged from 5,000 USD per tonne to 80,000 USD per tonne over the 2018 to 2026 period, with extreme volatility driven by EV demand and supply cycles. A DLE project with a breakeven price above 15,000 USD per tonne has significant economic risk given the price cycles observed. Ask for the full economic model sensitivity table, showing IRR and NPV at lithium prices from 10,000 to 30,000 USD per tonne.
What Drives Cost in This Category
DLE sorbent capital and operating cost per tonne of lithium recovered is inversely proportional to brine lithium concentration. Processing 100 mg per L Li brine requires twice the sorbent volume and twice the brine throughput versus 200 mg per L Li brine for the same output. High Mg:Li ratios (above 50:1) require nanofiltration pre-treatment to reduce Mg, adding 30 to 50 percent to capital cost and 20 to 40 percent to operating cost.
Single-use sorbent IX systems (sorbent discarded after one cycle, no regeneration): lowest capital cost but highest operating cost (sorbent 10,000 to 50,000 GBP per tonne, consumption 5 to 20 kg per tonne Li). Regenerable sorbents (LMO, LFP): moderate capital, low consumable cost, but require acid for regeneration and produce acid waste. CSTR (continuous stirred tank reactor) sorbent systems have lower capital than column systems but require solid-liquid separation equipment.
DLE eluate purification to battery-grade lithium carbonate (above 99.5 percent purity) requires crystallisation, washing, and drying steps. Capital cost for a 1,000 tonne per year LCE downstream purification plant: 5 to 20 million GBP. Operating cost: 1,500 to 4,000 USD per tonne of LCE in energy, chemicals, and labour. This downstream cost is often underestimated in early project evaluations focused on the DLE extraction step only.
Depleted brine after lithium extraction retains most of its original TDS (removing lithium at 200 mg per L from a 30,000 mg per L TDS brine reduces TDS by less than 1 percent). Brine must be reinjected to a permitted geological formation or managed as liquid waste. Reinjection well construction: 500,000 to 3,000,000 GBP per well. Failure to secure a reinjection permit before committing to a DLE plant makes the project unviable in inland locations.
Key Regulations & Standards
Extraction of brine from geological formations in England requires an environmental permit from the Environment Agency under EPR 2016 (mining waste and groundwater activities). Reinjection of depleted brine requires a separate groundwater activity permit specifying the permitted volume, injection zone, and monitoring requirements. The EA's groundwater protection policy (GP3) applies to all groundwater activities; injection of brine above 200 mg per L total dissolved solids into chalk or sandstone aquifers may be restricted under aquifer vulnerability criteria.
UK REACH (retained EU REACH Regulation) requires registration of chemical substances manufactured or imported above 1 tonne per year, including lithium compounds (lithium chloride, lithium carbonate, lithium hydroxide) produced at or imported to a UK processing facility. DLE project developers must confirm REACH registration status for all produced lithium compounds and for sorbent regeneration acids and bases used on site. Lithium is not currently an SVHC but regulatory status is subject to review.
DLE surface processing facilities (sorbent columns, brine storage tanks, downstream crystallisation plant) require full planning permission from the local planning authority under the Town and Country Planning Act 1990. Facilities on sites already permitted for geothermal energy or mining may be covered by existing planning consents, but material changes to site footprint or process chemistry typically require a planning amendment. Environmental Impact Assessment under the Town and Country Planning (EIA) Regulations 2017 is required for developments above specified thresholds.
The UK Government's Critical Minerals Strategy (2023) designates lithium as a critical mineral for net-zero transition. The Environment Act 2021 and associated planning policy supports domestic critical mineral production, including streamlining environmental permitting for demonstrably low-impact extraction projects. UKRI Faraday Battery Challenge and Innovate UK funds are available for DLE pilot projects in the UK, reducing early-stage capital requirements and de-risking technology validation.



















