China’s New‑Energy‑Storage Sector Shifts From Scale Expansion to Value‑Driven Growth

China’s new‑energy‑storage industry has reached a structural turning‑point after years of explosive capacity expansion. Growth fuelled by policy‑mandated storage requirements is losing momentum. Project margins are under pressure, market arbitrage margins have narrowed, and drawbacks stemming from extensive construction practices have surfaced across the sector. The industry is moving away from high‑speed capacity build‑out and towards quality‑oriented development.

Resolving profitability bottlenecks, reshaping value‑realisation mechanisms and unlocking new application scenarios stand as core imperatives for high‑quality industrial progress.

Data released by the China Energy Storage Alliance (CNESA) at the 11th Western Energy‑Storage Forum, via its CNESA DataLink platform, shows that newly commissioned new‑energy‑storage capacity in the first half of 2026 totalled 21.81 GW / 58.6 GWh. Power‑rating and energy‑volume metrics fell year‑on‑year by 18 per cent and 16 per cent respectively.

According to CNESA’s chairperson, the industry is entering a value‑restructuring phase after an earlier period focused purely on scale growth. Energy‑storage assets mitigate volatility from renewable‑power generation, shifting electricity demand across time by charging during off‑peak tariff windows and discharging at peak hours, while optimising resource allocation spatially through flexible local deployment.

Even so, these uncertainty‑reducing assets have themselves faced highly uncertain revenue streams over recent years. For a long time, market expansion relied on local subsidies and mandatory storage requirements. Subsidies generally delivered one‑off or short‑term rewards, insufficient to cover multi‑decade whole‑life‑cycle costs. Under mandatory‑storage frameworks, many completed facilities operated at low utilisation rates, with some assets standing largely idle.

Important institutional changes are unfolding. In January 2026, China’s National Development and Reform Commission and National Energy Administration issued guidance improving generation‑side capacity‑price mechanisms, bringing grid‑side independent energy‑storage formally within capacity‑remuneration schemes. Gansu, Jilin, Shaanxi, Xinjiang, Hubei, Ningxia and Qinghai have since rolled out local implementing rules.

Capacity‑price reforms mark meaningful progress, steering the sector from policy‑led expansion toward market‑driven operation. Gansu serves as a practical case‑study for this transition. Renewables account for more than 65 per cent of Gansu’s installed power capacity and nearly 40 per cent of local power generation. Net‑load profiles are shifting rapidly, creating simultaneous challenges around mid‑day renewable curtailment and evening peak‑supply pressure.

Market‑oriented arrangements have unlocked large‑scale storage‑regulation capacity, lifting renewable‑energy absorption performance. Energy‑storage assets delivered 3.43 billion kWh of cumulative charging volumes in 2025, improving renewable‑utilisation rates by 2.87 percentage points. Between January and July 2026, cumulative charging reached 3.006 billion kWh, lifting absorption rates by 2.4 percentage points. Full‑year additional renewable‑power output for 2026 is projected to hit 5 billion kWh. Operational‑cost allocation and related systemic hurdles nevertheless persist within the provincial system.

Fair distribution of system‑operation costs according to resource scarcity will allow storage operators to earn returns genuinely derived from their regulatory services. Provinces characterised by low storage‑utilisation rates and narrow spot‑market price spreads face far harsher profitability conditions. Model calculations for a representative 100 MW facility indicate that roughly RMB 69 million in annual revenue is required to cover costs, yet actual realised income stands close to RMB 40 million.

Persistent revenue shortfalls stem from the absence of stable whole‑life‑cycle compensation frameworks. Narrow spot‑market price differentials limit arbitrage gains; frequency‑regulation and spot‑market products often clear sequentially rather than stacking returns; capacity‑remuneration benchmarks remain modest, preventing full monetisation of multi‑faceted storage value.

Four practical lines of reform have been outlined: broadening trading products accessible to storage assets, refining capacity‑compensation arrangements and progressively migrating towards competitive capacity markets; rationalising dispatch protocols and building shared‑storage leasing platforms to raise asset utilisation; revising price‑and‑cost frameworks to optimise system‑cost‑sharing arrangements; strengthening market‑signal guidance to orient investment around genuine system‑level requirements.