China curtailed an estimated 360 terawatt-hours of wind and solar output in the first half of 2026, up 49% on the same period a year earlier, according to the Global Energy Monitor’s review of China’s coal power in the first half of the year. India’s curtailment over the same six-month period, aggregating a CREA quarterly snapshot for January to March and a Lok Sabha reply citing Grid-India data for April to June, amounts to roughly 8.3 TWh. The ratio between the two figures is approximately 43 to one. The comparison is being made not to dismiss India’s curtailment challenge, which is real and rising, but to reframe the risk hierarchy that is currently shaping investor and policy conversations about renewable energy buildout in both countries.
The absolute gap is partly a function of scale: China operates roughly 1,840 GW of wind and solar capacity against India’s 206 GW, a nine-fold difference in installed fleet. But the fairer comparison is the curtailment rate, the share of potential generation that is wasted rather than delivered to the grid. On that metric, China’s national curtailment rate remains roughly seven times India’s. In China’s most curtailment-intensive provinces, Xinjiang, Qinghai, and Gansu, solar curtailment reaches 10 to 17%, and analysts believe official figures understate actual losses. India’s national curtailment rate, as estimated by Ember for FY2025-26, sits at approximately 1.3% of renewable generation.
Why China’s UHV Network Has Not Solved the Problem
The structural argument for dismissing China’s curtailment figures, that it builds at a pace India cannot match and simply faces the growing pains of scale, does not survive contact with the specifics. China has spent more than a decade constructing the world’s largest ultra-high-voltage transmission network, explicitly designed to move wind and solar electricity from its resource-rich northwest to load centres in the east and south. That network is not experimental infrastructure. It is the mature output of systematic megabase planning and trillions of yuan in capital investment.
Yet today those UHV lines carry approximately one-fifth wind and solar electricity against 42% coal, a ratio that has barely moved since 2021 despite continued renewable capacity additions. Eleven UHV lines built specifically to serve renewable megabases are paired with 40 GW of coal capacity alongside 129 GW of wind and solar. The coal is not incidental or transitional. It is written into the transmission architecture through long-term dispatch contracts and grid operating rules that prevent renewable generators from accessing full grid capacity during the hours when their output is highest. Curtailment grew 49% year on year in the first half of 2026 even as China simultaneously added 30 GW of new coal capacity. The country curtailed enough clean electricity in six months to cover the entire year-on-year growth in national electricity demand.
This is not an early-stage problem trending toward resolution. It is a mature problem getting structurally worse inside an infrastructure base that was supposed to have solved it.
India’s Curtailment: Concentrated, Traceable, and Funded for Resolution
India’s curtailment is not a problem to be dismissed, but its character differs from China’s in ways that matter for assessing risk. A Lok Sabha reply this summer put solar curtailment alone at 8,133 GWh for April to June 2026, and ICRA has flagged that approximately one-third of the 54.8 GW commissioned under India’s temporary grid-access route is experiencing curtailment as high as 50 to 60% during solar hours in states like Rajasthan and Gujarat. Three different official sources produce three different national totals, indicating that India’s curtailment accounting framework is still developing methodological consistency.
But the drivers are specific and narrow. Ember’s analysis identifies the primary cause as coal plants hitting their minimum technical load during midday solar hours, preventing renewable generation from being absorbed into the dispatch stack. The coal fleet’s inability to ramp down fast enough to accommodate the solar generation curve is a known operational constraint with a known technical remedy: battery storage that can absorb midday surplus and deliver it into evening demand. Ember’s analysis estimates that roughly 10 GWh of battery storage would have absorbed most of FY2025-26’s curtailed volume, a quantity that is modest against the storage capacity currently being tendered in Indian markets.
The policy response is already in motion. The government has introduced storage capacity payments designed to improve the economics of battery procurement. Grid-interconnection route reforms are reducing the permissioning bottleneck for storage and transmission projects. The Inter-State Transmission System commissioning pipeline is being accelerated. ICRA’s investment plan for transmission infrastructure through FY2032 is sized at approximately five to six trillion rupees, a level consistent with resolving the transmission lag that is causing the concentrated curtailment in western India’s high-capacity states.
The Structural Distinction That Actually Matters
The more analytically productive distinction between the two countries is not scale but structure. India’s curtailment traces to a bottleneck that is narrow in time, geographically concentrated, and attributable to factors that funded solutions are already addressing. China’s traces to an architectural feature of its power system in which coal capacity is not merely co-existing with renewables but is embedded in the same transmission corridors and long-term contracts that determine renewable dispatch access.
The localisation fallback that China has pursued in some megabase regions, pairing large wind and solar installations with on-site green hydrogen production or coal-to-chemicals plants to consume surplus electricity, illustrates the difficulty of the structural constraint. GEM’s research found that the Baofeng Energy coal-to-olefins project in Inner Mongolia, paired with a 1 GW renewable installation, displaces approximately 2.2% of the plant’s annual coal consumption while fulfilling the regulatory requirement that renewable integration has been achieved. The renewable component is real. The coal displacement is marginal. The regulatory box is checked.
India has not yet built the UHV-scale transmission infrastructure that China’s curtailment problem runs on. In some respects, that creates an opportunity: the transmission and storage architecture India is now funding can be designed around renewable dispatch priority from the outset rather than retrofitted onto coal-era dispatch rules. The 54.8 GW of T-GNA commissioned capacity experiencing high curtailment in Rajasthan and Gujarat is a temporary grid-access route problem, not a transmission infrastructure design problem. The difference matters for how long the constraint persists and what investment resolves it.
The relevant success metric for any renewable megabase programme is not installed capacity but coal displacement. China’s first-half 2026 curtailment data demonstrates that these two metrics can diverge dramatically even in a system operating the most extensive transmission infrastructure of any country in the world. India’s renewable programme is at an earlier stage, with more immediate and tractable bottlenecks, and a smaller gap to close between installed capacity and actual grid contribution. The risk embedded in the curtailment headlines is real but bounded. The risk embedded in China’s structurally worsening trajectory, on a network that experience and capital alone have not improved, is of a different category entirely.
