As nine significant provinces in China shifted to a more flexible, market linked price for electricity across various slots in the day, it has upended  a cosy market for many BESS based service providers. These firms were happy to charge during slots when the fixed price was low, and discharge during higher rate time slots. Now they face a more difficult task of planning for more volatile prices with the new policy kicking in.    

Why the Change Happened

The decision aligns with new electricity market rules issued by China’s National Development and Reform Commission (NDRC) and other government departments last December, which took effect in March. In other words, it’s the culmination of a broader push to mature China’s power markets — replacing administratively fixed tariff schedules with market-determined prices that genuinely reflect real-time supply and demand.

Anhui, Henan, Hubei, Liaoning, Shaanxi, and five other provinces announced that market participants directly involved in electricity trading would no longer be subject to fixed time-of-use pricing levels and periods starting in April.

The logic behind the reform is sound from a market-design perspective: fixed TOU schedules were a blunt instrument. They set peak, flat, and valley periods by administrative fiat, but those windows often failed to match actual grid conditions — especially as massive amounts of solar and wind generation warped the traditional demand curve. By pushing industrial and commercial users into spot and mid-to-long-term markets, the NDRC wants price signals to organically reflect real scarcity rather than a bureaucratic clock.

How This Burns the Old Arbitrage Model

Fixed time-of-use electricity pricing divides the day into peak, flat, and valley periods, and sets different rates each period. This method creates an arbitrage opportunity for industrial and commercial energy storage, which charges during valley periods and discharges during peak periods.

This was a remarkably simple and reliable business model: the price differential was guaranteed by government schedule, so operators didn’t need to forecast anything — they just had to charge at night and discharge at noon. The economics were purely a function of the spread. C&I energy storage projects in China mainly profit from peak-valley arbitrage while reducing demand charges by monitoring inverters’ power output in real time to prevent transformers of industrial parks from exceeding their capacity limits.

Now, fixed price calculations will lose their effectiveness, heavily impacting market players who lack the capability to anticipate fluctuations in electricity demand and prices. Those unable to adapt quickly are likely to face significant challenges or exclusion from the market.

How Firms Are Adapting

The industry is pivoting toward three alternative revenue streams:

1. Ancillary Services Markets Energy storage can participate in the electricity ancillary services market to obtain revenue from peak shaving and backup services.  This is a more sophisticated market — operators must bid competitively and manage dispatch schedules actively — but it offers recurring, grid-contracted income.

2. “Reliability Insurance” for Critical Infrastructure Energy storage can provide an uninterrupted power supply and voltage support services for key users such as data centers and high-end manufacturing, thereby earning “reliability insurance” income.  This is a service-based model where storage is essentially leased as a grid-quality guarantor to high-value, power-sensitive customers.

3. Renewable Integration & Solar Pairing An obvious route where Energy storage can be bundled with renewable energy power plants, smoothing out unstable output from wind and solar, thereby supporting the absorption of renewable energy.  As China mandates that new wind and solar projects participate in power markets directly, the case for co-located storage becomes stronger for firming up their variable output before it hits the grid.

4. Spot Market Arbitrage (Replacing Fixed-Schedule Arbitrage) The death of fixed TOU doesn’t kill arbitrage — it just makes it harder. Firms that build real-time price-forecasting capabilities can still trade the spread between cheap midday solar and expensive evening demand hours, but now they must do so dynamically through spot markets rather than a preset schedule. This sharply raises the bar for market sophistication.

The Broader Outlook

As the electricity market matures and price signals fully reflect the supply and demand relationship, the Chinese energy storage market is expected to experience more rapid growth within the next two to three years. The provinces that scrapped fixed TOU are not abandoning storage — they’re simply forcing the industry to graduate from a subsidized, schedule-dependent model into a genuinely competitive market participant. For well-capitalized firms with forecasting and trading capabilities, this could ultimately expand the addressable market. For smaller operators who were essentially arbitraging a government-printed price schedule, it is an extinction-level event.