Chinese alkaline electrolyzer system costs have fallen to approximately $1.0M/MW in 2025, against approximately $2.0–2.5M/MW for Western equivalents — a gap that has widened as Chinese manufacturing capacity expanded to 39 GW/year against demand that generated only 693 MW of procurement in the first ten months of 2024. The cost trajectory is real. Its implication for green hydrogen competitiveness requires more precision than the headline numbers provide.
Electrolyzer capital expenditure represents approximately 15–35% of the levelised cost of hydrogen (LCOH) under typical project assumptions. Renewable electricity supply accounts for 60–70%. The practical consequence: halving electrolyzer CAPEX reduces total LCOH from a reference case of $3.50/kg to approximately $2.80–3.00/kg in best-case configurations. Grey hydrogen from steam methane reforming currently costs $1.00–1.50/kg. The hardware cost reduction is meaningful; it does not close the fossil-fuel parity gap in most markets.
A second constraint that LCOH comparisons systematically underweight is the operating profile mismatch between Chinese alkaline electrolyzer design and variable renewable coupling. Chinese alkaline stacks are optimised for steady-state operation. Coupling to intermittent solar or wind results in frequent partial-load and start-stop cycles that reduce system efficiency — electrolyzers operated below 20% of rated capacity show substantially reduced stack efficiency — and accelerate membrane degradation, reducing the effective stack lifetime below the manufacturer-rated figure. Stack replacement is a material mid-project cost that project financial models frequently exclude from LCOH calculations presented to lenders and equity investors.
The market structure consequences are also worth noting. IEA's 2025 Global Hydrogen Review confirms that electrolyzer manufacturers outside China face sharp revenue reductions and financial losses, with some facing bankruptcy or acquisition. Nel's halt of stack production at its recently modernised Herøya facility illustrates the competitive pressure. The market concentration this creates — China at 60–65% of installed capacity and manufacturing capability, trending toward 70–75% — produces a supply chain dependency with a structure directly analogous to the European solar and battery dependency now being addressed at considerable policy cost.
For project developers and development finance institutions active in emerging markets, three practical implications follow. First, electrolyzer procurement decisions made at current Chinese price points for twenty-year infrastructure assets embed supply chain dependencies that need to be assessed explicitly, not treated as background risk. Second, project LCOH models should be stress-tested against degradation assumptions that reflect variable renewable operating profiles rather than steady-state laboratory ratings. Third, the domestic industrial hydrogen use case — green ammonia for fertiliser, green hydrogen for direct reduced iron steelmaking, green methanol — offers more defensible economics in resource-rich emerging markets than the export-to-Europe model, where delivered cost remains €4.2–4.9/kg without European policy support even at the continent's best renewable electricity prices.
REM Episode 16 presents the full LCOH cost waterfall, a comparative technology assessment of Chinese and Western alkaline electrolyzer specifications, and a detailed analysis of the Africa strategic context.
Published at donfackfortune.medium.com
Donfack Fortune is a mechanical engineer and energy systems analyst publishing Renewable Energy Mall & Engineering Review (REM).