The lithium carbonate market is transitioning from a bull cycle into a period of valuation normalization, driven by decelerating downstream demand growth and shifting supply expectations. The key theme across the close of 2025 is the transition from "fast growth" to "marginal slowdown," with price action increasingly dictated by inventory swings and demand visibility rather than supply tightness.
In the short term, the focus remains on market rhythm and timing rather than a fundamental bottom. The price collapse from CNY 160,000 per ton in September to CNY 125,000 per ton was triggered by social inventories significantly exceeding expectations, with marginal weakening in demand forecasts further compounding the bearish sentiment. Any future rebound should be treated as a recovery from oversold levels rather than the start of a new uptrend, as every rebound high since May has progressively declined. The narrative of "strong expectations, weak reality" will keep the upside limited, and for the market to test cost support, October's production plans across the supply chain and energy storage installations will need to continue missing forecasts. Conversely, if monthly destocking of around 10,000 tons and the clearing of warehouse receipts persist within a low-valuation environment, another oversold bounce is likely within the remaining months of the year.
Looking at the long-term horizon, the market is expected to feature strong supply and demand growth through 2027, but with a declining price center. Global supply is projected to expand at a double-digit pace, yet this balance sheet is built on the assumption that at CNY 130,000-150,000 per ton, almost all mines are highly profitable. As prices fall, this optimistic supply outlook will shift to a neutral scenario. Supply from regions such as Jiangxi, Nigeria, and Zimbabwe remains highly uncertain through 2027. While demand growth is losing momentum on a second-derivative basis, it should still maintain double-digit expansion. Consequently, the medium-to-long-term direction is a declining price center, but a repeat of the 2024 single-direction collapse that pierced the industry's cash costs seems unlikely. Instead, the market should experience repeated trading opportunities driven by supply disruptions amid demand divergence.
On the supply side, high lithium prices have historically stimulated supply elasticity, but capital expenditure is now contracting sharply. By the first half of 2026, capital spending by major mines is projected to decline by 50% year-on-year. Australian mine output is demonstrating limited elasticity, with new projects ramping up smoothly while older operations see marginal supply declines. Australian mines recorded a modest inventory drawdown in Q2, with inventories at approximately 48,900 tons LCE by the end of the second quarter of 2026, a 12% decrease quarter-on-quarter. Neutral estimates suggest an additional 471,000 tons in 2026, up 26.8%, followed by a further 491,000 tons in 2027, marking a 22% increase. In Australia specifically, 2026 should bring an additional 64,500 tons of LCE, a 13.8% year-on-year rise, as mines previously on care and maintenance gradually resume operations in the second half.
African supply, meanwhile, presents high elasticity alongside significant disagreements, with Arcadia and Monono contributing new volumes and shipment schedules worth monitoring. Elsewhere, overseas production remains flat, while Sigma's tight cash flow has pushed its 2026 expansion plans back. Overseas brine operations are set to add 111,000 tons in 2026, up 26.4%, with the incremental volumes coming from SQM and 3Q. In China, lepidolite production looks to decline by 24,000 tons in 2026, down 17.3%, making near-term restarts difficult. Domestic salt lake capacity is ramping up in an orderly fashion, with an additional 83,000 tons anticipated in 2026, up 58%. Sichuan's expansion remains slow, while Xinjiang's output is rising notably, with an expected 84,000-ton addition in 2026, up 81.7%. Domestic lithium carbonate production continues its steady climb, with weekly inventory levels declining over four consecutive months.
On the demand side, energy storage is stepping in as a second growth engine following the EV sector. Capital expenditure among leading cell and cathode material manufacturers is gradually recovering, while upstream and midstream players remain cautious. The cathode materials sector is experiencing an increasingly pronounced winner-take-all dynamic, with low net margins, financing difficulties, cautious expansion, and recoveries in demand pushing product prices upward. New capacity additions have slowed significantly. The iron-phosphate sector has seen all projects planned between 2022 and 2024 already commissioned, with new projects halted. In 2026, expansions are exclusively tied to top-tier players such as the additional 40 tons at Yuean, 25 tons at Fuling, 45 tons at Bump, and 9 tons at Longpan, while all others proceed with caution, sharply slowing supply growth. Leading producers are already running at full capacity for Q4, while second-tier firms have recovered to over 80% utilization.
Cathode material output is sustaining high growth, with top-tier factories raising utilization meaningfully in Q1, some running at full capacity. However, production margins remain in the red, making price hikes an urgent necessity. Terminal demand for iron-phosphate batteries remains robust, with China's effective lithium battery capacity projected to reach 2,534 GWh in 2026, a 22% year-on-year increase. EV subsidy policies for 2026 have been released earlier than usual, yet retail EV sales remain weak and are expected to contract domestically in 2026. Channel inventories for new energy vehicles are high, putting pressure on retail, although cell-level inventory-to-sales ratios appear healthy.
European new energy vehicle registrations continue to exceed expectations, while the US market remains stable. The core logic for energy storage lies in policy support both domestically and abroad. In China, regional capacity compensation policies are proving influential, with Inner Mongolia's policy offering more substantial incentives: independent storage commissioned in 2025 can receive CNY 0.35/kWh in capacity compensation, falling to CNY 0.28/kWh in 2026. Storage returns are highly sensitive to lithium prices; installations weaken notably when carbonate prices exceed CNY 170,000 per ton, but a sharp decline in costs would lift internal rates of return and support demand. The rapid integration of renewables into the grid is straining the transmission system's ability to handle unstable energy sources, requiring storage for grid balancing. Peak-valley arbitrage is driving independent storage demand, with projects in Inner Mongolia achieving near 15% IRR while the national average sits at 8-10%.
Overseas, weak grid infrastructure combined with high and volatile electricity prices is driving demand for behind-the-meter storage, particularly in Europe and the US, further boosted by the surging electricity needs of AI and data centers. Energy storage tenders reached 87.2 GWh in August across systems and EPC, up 25.6% month-on-month and 85% year-on-year, with cumulative bidding over January-August reaching 382.2 GWh, up 40.6%. From an installation perspective, the first half of the year has been weak, but a strong installation rush is possible in Q4.
According to the supply-demand balance sheet, the weak retail vehicle sales from January to August and disappointing storage installations have shifted market sentiment from optimism to pessimism, lowering the ceiling for any rebound. Several key points emerge for price forecasting. First, supply-side disruptions are still present, but their marginal impact on prices is fading. Between Q4 2025 and Q1 2026, prices were highly sensitive to supply disruptions because demand expectations were strong; any supply issue led to upward pressure. However, from Q2 onwards, production plans and terminal demand began decelerating year-on-year. Historically, the core driver of price movements has been demand; when demand slows, even a small surplus exerts massive downward pressure on prices.
Second, Q4 2026 might bring another energy storage installation rush, and with low inventories, temporarily depressed valuations, and crowded short positioning, a rebound is possible. But after Q1 2027, the market enters a demand vacuum, with EV volumes flat and storage growth decelerating. If storage grows at 25-30% in 2027, combined with rapid supply release driven by high profit margins, the market faces a small surplus with prices ranging from CNY 100,000 to 130,000 per ton. Should storage demand persistently underperform, prices may test production cost support. The conclusion is clear: whether storage grows at 25% or 30% in 2027, its marginal growth is decelerating from 2026's high base. The market's upward cycle ended in Q1 2026, and lithium prices have already fallen nearly 40% from their peak. In 2027, prices should follow demand's momentum downward in a spiral trend. High prices will continue to stimulate off-balance-sheet production and hidden inventory, and with demand expectations shifting, the ceiling is lowering; the only remaining pillar of support is production cost.
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