Welcome back to this week’s Battery Business Insights article on China’s freeze of new battery factory approvals. Chinese financial outlet Cailianshe reported on 6 September 2026 that regulators had stopped approving battery manufacturing projects that have not yet broken ground; Reuters carried it on 7 September, and the South China Morning Post followed on 11 September with an exclusive dating the freeze back to May. Coverage settled quickly on a familiar reading: China built too much, its factories stand idle, and Beijing is pulling the handbrake.
That reading does not survive contact with the market data. This matters for two specific reasons. First, Chinese storage cell lines are not idle — they are running above 90% utilisation, with the mainstream 314Ah cell in tight supply for close to a year and prices up more than 15% in six months. A freeze imposed during a shortage is a different instrument from a freeze imposed during a glut, and it points at a different intention. Second, the measure exists nowhere in published law: no ministry decree, no circular, no named official on the record. Anyone planning capacity, procurement or pricing around it is planning around guidance that can change without notice.
By the Numbers: Output, Orders and the Announcement Pipeline
- 1,755.6 GWh — China’s combined power and energy-storage battery output in 2025, up 60.1% year on year. (CABIA, January 2026)
- 2,608.5 GWh — Combined annual capacity of roughly 100 new battery expansion projects signed in China between January and July 2026, about 1.5 times the country’s entire 2025 output. (Caixin, September 2026)
- Over 800 GWh — Storage-specific cell expansion planned in China for 2026 alone; industry estimate, not an official statistic. (Tian Qingjun, Envision Group, via Cailianshe, September 2026)
- 1.2–1.5 TWh against over 2 TWh — ESS cell capacity expected to be completed by end-2026, versus total planned capacity; industry estimate. (Tian Qingjun, Envision Group, via Cailianshe, September 2026)
- Above 90% — Capacity utilisation across China’s storage battery sector, against roughly 50–55% for Chinese battery manufacturing as a whole. (IEA, 2026)
- CNY 0.365 /Wh ($54.4/kWh) — Average price of 314Ah LFP storage cells in August 2026, against a 2025 trough near CNY 0.26/Wh ($38.8/kWh). (SMM, August 2026)
- 467.84 GWh — Global ESS cell shipments in the first half of 2026, up 94.8% year on year. (InfoLink, August 2026)
- 298 GWh — Overseas orders booked by Chinese storage manufacturers in the first half of 2026, up 83%, with Europe the largest single market at roughly 120 GWh. (Caixin, August 2026)
- 153 GW / 396 GWh — Installed new-type energy storage in China at end-June 2026, up 61% year on year, against 136 GW / 351 GWh at end-2025. (National Energy Administration, July 2026)
- $73, $177, $219 per kWh — Turnkey utility-scale BESS system cost in China, Europe and the United States respectively; global average $117. (BloombergNEF, December 2025)
- 2% rising to 4% — Consumption tax on lithium-ion batteries, effective 1 September 2026 and stepping up 1 September 2027, ending an eleven-year exemption. (Public Notice [2026] No. 20, July 2026)
What Was Actually Paused
The measure is administrative, not legislative. No National Development and Reform Commission circular or Ministry of Industry and Information Technology gazette has been published on any national government portal. What exists instead is guidance, applied through the filing and approval system every new Chinese manufacturing project must pass through — plus a paper trail at provincial level. Jiemian has cited a June 2026 Sichuan provincial notice and a county-level document in Zhongjiang implementing the restriction locally, which suggests a rolling regional rollout rather than a single national switch thrown in May.
The scope is narrower than “no new battery factories” and wider than “storage only.” Projects still at planning stage that have not formally broken ground are suspended from approval and further advancement. Projects already registered, approved, or under construction proceed normally and are explicitly unaffected. Crucially, the filing freeze covers power batteries for electric vehicles as well as energy-storage cells: mainland and Taiwanese reporting both note that from the second half of 2026, localities across China essentially stopped accepting filings for new capacity in either category. Framing this as a storage-sector measure understates it.
Responsibility is shared across MIIT, the NDRC, the State Administration for Market Regulation, the National Energy Administration and provincial governments. That distributed structure is part of why the measure surfaced as guidance rather than as a single published decree, and part of why its edges are hard to establish from outside.
Two prerequisites for lifting the pause have been reported: completion of an industry-wide capacity inventory, and the establishment of a capacity monitoring and early-warning mechanism. Neither carries a published deadline. The measure is described consistently as temporary and adjustable rather than permanent.
The Overcapacity Has Not Arrived Yet — and That Is the Point
The overcapacity driving this intervention is not on the factory floor. It is on paper.
China’s storage cell industry is currently supply-constrained. Utilisation across the sector runs above 90%, with some lines operating beyond rated capacity — against roughly 50–55% for Chinese battery manufacturing taken as a whole. The mainstream 314Ah LFP cell has been tight for nearly a year, and its average price has climbed from roughly CNY 0.26/Wh ($38.8/kWH) at the 2025 trough to about CNY 0.365/Wh ($54.4/kWh) in August 2026. On 9 September, CATL raised its 314Ah quote from CNY 0.414 to CNY 0.423/Wh ($61.7 to $63.1/kWh), EVE Energy applied a 2% surcharge, and Lishen went further — increases triggered principally by the new consumption tax. Industry inventory sits near 28 GWh, roughly eleven days of cover, with lead times of 45 to 60 days and rush premiums of 5 to 10%.
Demand explains it. Global ESS cell shipments reached 467.84 GWh in the first half of 2026, up 94.8% year on year, with markets outside China taking 53.2% of the total. This is not a sector struggling to sell what it makes.
What alarmed regulators is the pipeline behind that boom. Caixin counted roughly 100 new battery expansion projects signed between January and July 2026, with combined annual capacity of about 2,608.5 GWh — one and a half times everything China produced in 2025, committed in seven months. Envision Group’s Tian Qingjun put storage-specific expansion plans for 2026 alone above 800 GWh, with completed ESS cell capacity reaching 1.2 to 1.5 TWh by year-end against total planned capacity exceeding 2 TWh, a figure he described as far beyond real global demand. Those are executive estimates rather than official statistics, and should be read as such.
Then there are the entrants. China’s solar majors — JinkoSolar, JA Solar, LONGi and Trina Solar — have moved into storage manufacturing as panel margins collapsed, with JinkoSolar alone planning to go from 5 GWh to 13 or 14 GWh of battery capacity by end-2026. These are companies with capital, industrial land, and first-hand experience of what happens when everyone builds at once.
That is the situation Beijing is intervening in: a fully booked industry approving a pipeline that would guarantee a glut within roughly eighteen months. The freeze is not a response to idle factories. It is an attempt to prevent them.
The Domestic Demand Wobble Is Real, but Separate
One genuine warning sign sits underneath the export boom. New energy storage commissioned inside China fell to 21.81 GW / 58.60 GWh in the first half of 2026, down 18% in power terms year on year — the first half-year decline the market has recorded. Cumulative installed new-type storage still reached 153 GW / 396 GWh by end-June, up 61% against 136 GW / 351 GWh at the close of 2025, but the rate of addition has turned.
The cause is structural. NDRC and NEA Document No. 136, issued 27 January 2025 and published on 9 February, barred provinces from making storage a precondition for approving or grid-connecting new wind and solar projects, with a 1 June 2025 cut-off separating existing from incremental projects. That removed the guaranteed demand channel underwriting much of China’s storage build-out. Ember found capacity-leasing demand for co-located storage shrank sharply afterwards, with co-located systems falling to 8.4% of new installations between January and April 2026, against 84.7% standalone. CNESA itself frames the first-half decline as a shift from scale expansion to value restructuring — larger, longer-duration standalone projects replacing mandated add-ons — rather than as a demand collapse.
Domestic demand is being rebuilt on economics rather than mandate, and that transition takes time. Export orders, meanwhile, surged: 298 GWh booked overseas by Chinese storage makers in the first half of 2026, up 83%, with Europe at roughly 120 GWh, Australia around 30 GWh, the Middle East just under 30 GWh, and North America collapsing to about 5 GWh after the 30 July executive order barring foreign-made electrical equipment. Southeast Asian imports of Chinese clean-energy products hit a record $20 billion year-to-date, of which storage batteries were the largest single category at roughly $7 billion.
The Carve-Outs Are the Actual Policy
What the freeze exempts says more about Beijing’s objective than what it blocks. Consumer batteries sit outside the restriction, as do lithium-battery materials and supporting projects, technology upgrades, and production-line retrofits. So, explicitly, does the construction of overseas battery factories. Jiemian reports that solid-state and sodium-ion projects are expected to receive preferential treatment rather than restriction.
Read alongside the consumption tax, the pattern is unmistakable. The 2% levy effective 1 September applies to lithium-ion, lithium primary, mercury-free primary, nickel-metal hydride and all-vanadium redox flow batteries, rising to 4% on 1 September 2027. Sodium-ion, solid-state and fuel cells are exempt through 31 December 2028, and direct exports are exempt entirely, with refunds available on tax already paid.
Taken together: mature chemistry gets a cost burden and an approval freeze; next-generation chemistry gets an exemption and priority handling; and anything aimed at foreign markets is left alone. This is not a brake on the battery industry but a steering input, pushing capital out of commodity LFP cell capacity and toward either technology differentiation or an overseas production footprint.
What Is Not Confirmed
The evidence for the freeze is strong but entirely indirect. No Chinese ministry has announced it, no named official has confirmed it on the record, and no national instrument has been published. What exists is consistent reporting from Cailianshe, Reuters, Caixin, the South China Morning Post and Jiemian, corroborated by provincial and county documents. That is enough to treat the measure as real. It is not enough to treat any particular description of its scope as authoritative.
Three things remain genuinely open. The May 2026 start date rests on a single sourced report, and the provincial paper trail suggests a staggered rollout rather than a uniform national one. Whether the promised capacity inventory and early-warning mechanism are being built at all is unverified — they have been reported as conditions, not observed as programmes. And no timetable for resuming approvals has been published. A capacity control administered by discretion rather than by published rule can be tightened, loosened or abandoned without any announcement at all.
Filings for new power-battery and storage-battery capacity stopped from H2 2026
Registered, approved and under-construction projects continue unaffected
Carve-outs: consumer batteries, materials and supporting projects, technology upgrades, line retrofits, overseas plants
The consumption tax is published law: 2% from 1 September 2026, 4% from 1 September 2027
Sodium-ion, solid-state and fuel cells exempt from that tax through 31 December 2028
No named official has confirmed the measure on the record
The May 2026 start date rests on a single sourced report
Whether the freeze is uniform nationally or varies province by province
Whether the capacity inventory and early-warning mechanism are actually being built
When, or whether, approvals resume — no deadline has been published
Total planned ESS capacity figures are executive estimates, not official statistics
Beijing Learned From Solar and Moved Earlier
China has run this cycle before, in photovoltaics: provincial subsidies drove a capacity race, prices collapsed below cash cost, the sector consolidated violently, and regulators intervened after the damage was done. The battery industry sits at an earlier point on the same curve, and the timing of this intervention is the most interesting thing about it.
In January 2026, four regulators convened sixteen major battery manufacturers to warn that blind capacity expansion and cutthroat pricing were disrupting market order. Eight months later, approvals stopped — while utilisation was above 90% and prices were rising. Acting at the top of the cycle rather than the bottom is a departure from how Chinese industrial policy has usually worked, and if the promised early-warning mechanism is actually built, it matters more than the freeze itself.
The risk is the obvious one. Capacity controls administered by discretion, without a published instrument or an appeal route, favour incumbents. CATL reported 94.86% company-wide utilisation in the first half of 2026 and EVE reports its storage business at full production and sales — both company-reported figures, and neither firm needs a new approval in the near term. The producers frozen out are the second- and third-tier entrants and the solar crossovers — precisely the competitive pressure that drove Chinese cell costs to a level nobody else can match. A more concentrated Chinese battery industry is good for Chinese margins and worse for everyone buying from it.
For buyers outside China, the near-term signal is not scarcity but the end of a deflationary assumption. BloombergNEF’s most recent survey put turnkey utility-scale systems at $73/kWh in China against $177 in Europe and $219 in the United States. Those Chinese numbers reflect a price war that regulators have now set out to end, with a consumption tax on top. Procurement models built on continued Chinese price declines through 2027 and 2028 need revisiting — not because supply is at risk, but because the policy direction has reversed.
Bottom Line
China has frozen approvals for new battery manufacturing projects that have not broken ground, covering EV cells as well as storage, since roughly May 2026. It is administrative guidance rather than published law, it exempts projects already under way, and it can be lifted once a capacity inventory and monitoring mechanism exist. What makes it significant is the timing: it arrives with storage cell lines running above 90%, cells in short supply and prices rising — not with idle factories. The overcapacity Beijing is acting against is the 2,608.5 GWh of projects signed in seven months, not anything currently built. Combined with a consumption tax that spares sodium-ion and solid-state, and carve-outs that spare overseas plants and technology upgrades, the policy reads as a deliberate redirection of capital rather than a retreat from batteries. The global storage market should stop reading this as a supply risk and start reading it as the end of Chinese price deflation.
Battery Business Insights is an independent industry publication. The approval freeze described here has not been confirmed by any named official or published instrument; it is reported by industry participants and Chinese financial media, and corroborated by provincial documentation. Capacity and pricing figures reflect the most recent data available at the publication date, and planned-capacity totals are industry estimates rather than official statistics.
