China's Southern Regional Electricity Market has formally begun operation, described as the world's largest and the country's first regional power market, advancing the national unified electricity market.

Forecast Energy (预见能源) reports that the Southern regional electricity market officially entered formal operation on October 24.

Five provinces and regions, 290,000 market entities, a trading volume accounting for more than 70% of the national grid's electricity sales, and new energy becoming the largest power source on the entire grid: these are the figures China Southern Power Grid cited in its official interpretation, and they were widely repeated on the day the market went live. The market has "undergone more than a year of real-world testing under extreme operating conditions." During the trial run, clean energy surges, rapid shifts between flood and drought, a super typhoon, a winter cold wave, and high new-energy penetration during the Spring Festival all occurred in turn, and the market did not stall.

The significance of going live lies not in the label "the world's largest electricity marketplace," but in the fact that a single set of rules has, for the first time, proven under real price shocks that it will not fall apart. Once the rules stabilize, the mechanisms for correcting problems begin to function.

**Bigger than "largest": the rules held together under extreme conditions**

When provincial rules differ, the bidding logic that works in Guangdong may not apply in Yunnan, and cross-provincial power transmission often gets stuck at the points where rules meet. The Southern market uses "five unifications and one opening" to bring the five provinces and regions under one clearing framework. Coal, hydro, nuclear, wind, solar, and gas power all bid under the same rules and form prices together.

The technical foundation is "Tianquan," a proprietary solver that supports more than 7,000 model nodes and over 2 million clearing variables. Its computing performance averages 14% faster than leading international solvers.

The value of this system lies not in speed. It turns cross-provincial congestion, cascaded hydropower constraints, and multi-terminal HVDC links, which were previously handled through "negotiation" under centralized dispatch, into variables that can be priced and corrected every 15 minutes.

The trial run also expanded the flexibility of the ancillary services market. Frequency regulation, reserves, ramping, and other products now interact with the spot market, and regional regulation resources have grown by more than five times compared with 2021. Cross-region trading volume exceeded 19.4 billion kWh. Hydropower from the Southwest supported the Yangtze River Delta, wind and solar from the Northwest were delivered directly to the Greater Bay Area, and the country's first market-based transmission rights trade used market mechanisms to put spare corridor capacity to work.

These achievements will not improve on their own after the market goes live. But they have been shown to keep running even when a typhoon and a cold wave arrive at the same time. Only a market that can keep operating has earned the right to talk about "repair."

**The 5 billion yuan in tuition was not wasted: the rules are putting a tourniquet on the losses**

Nearly 80% of retail contracts in Guangxi lock in fixed prices, with an average signed price of about 0.26 yuan/kWh. The spot price rose to 0.395 yuan in September, and institutions expect it to exceed 0.5 yuan in the fourth quarter, when the maximum loss per kWh could exceed 0.37 yuan. In Guangdong, 298 electricity retailers posted losses in the first half of the year, and the industry-wide average profit per kWh, including profitable firms, has shrunk to just 0.0039 yuan. These numbers were on the table before the market went live. What the launch actually changes is not the losses themselves, but whether those losses can be institutionally stopped.

The first clamp on the tourniquet is that retail pricing rules no longer allow a "fixed price" to lock in risk in one direction.

The Guangdong 2027 trading rules already specify that the retail side will use three standardized package types, all tied to market prices. The share of fixed-price electricity is being systematically reduced.

The cap on bilateral long-term negotiated volumes has been cut to 20%. The remaining volume shifts to annual centralized bidding, and monthly market bilateral negotiation products are eliminated. This means retailers' wholesale purchase costs will show up more transparently in retail pricing formulas, and the price spreads that relied on information asymmetry and risk mismatch will be narrowed by the rules. Retailers can no longer pretend wholesale prices do not exist, and customers can no longer pretend they are buying a bill unrelated to the market.

The second clamp is that existing inverted-price contracts now have a way out.

An October 16 risk alert from the Guangdong Electric Power Trading Center states that, under the principles of "voluntariness, good faith, and fairness," contract parties may negotiate undelivered contracts for the current year and adjust signed prices by modifying contracts or signing supplementary agreements. In Guangxi, nine central state-owned enterprises submitted requests to "implement orderly termination of retail contracts," based on the provision in the *Guangxi Electric Power Retail Management Measures (Trial)* that a contract may be terminated by paying the liquidated damages specified in its terms.

Negotiated price adjustments and orderly termination will not make existing losses disappear. But they put a second path on the table beyond "endure it or default on it." Until now, retailers facing inverted retail-wholesale prices had two options: endure or renege. Now there is a third: negotiate.

The third clamp comes from performance guarantee instruments operating in substance.

In June 2026, the Guizhou Electric Power Trading Center enforced performance guarantee instruments against nine electricity retailers in arrears, totaling about 20 million yuan in unpaid amounts. This was not an isolated penalty. It shows that credit constraints on the Southern region's retail electricity sector are beginning to shift from "paper requirements" to "enforceable buffers."

Performance guarantees do not stop retailers from making mistakes, but they stop those mistakes from spilling over to customers and the system at no cost.

Installing a tourniquet does not mean every bleeding player will survive. The expected 2027 long-term contract price in Guangdong has already risen to 0.33–0.38 yuan/kWh, and some research reports are optimistic about exceeding 0.4 yuan. The central tendency of retailers' procurement costs is rising.

Once price spreads are institutionally narrowed, retailers that keep selling only "cheap electricity" without offering load management and risk hedging will not be saved by the tourniquet. The 5 billion yuan in tuition has bought an institutional environment that no longer protects fixed prices, and this environment turns "can you offer value-added services?" from a slogan into a threshold for survival.

**Electricity prices have split into tracks that move out of sync: asking "up or down" is already the wrong question**

The most substantive change the market's launch brings to electricity prices is not raising or lowering any single price. It is separating prices that were previously bundled together.

The spot market now independently reflects supply, demand, and congestion. On October 13, the day-ahead weighted average price across the China Southern Grid region jumped to 0.5736 yuan/kWh, up 19.8% from the previous day. The comprehensive medium- and long-term trading price for October was 456.78 yuan/MWh, staying firm despite the off-season.

The second track is cross-provincial price spreads. In April, Guangdong's real-time price briefly hit 745.6 yuan/MWh, compared with 547.8 yuan in Yunnan and 379.5 yuan in Guizhou, a spread of more than double. This is not a leftover of market fragmentation. It is the price of "location" itself, which emerges once transmission corridor constraints are priced. The value of cross-provincial arbitrage and flexible regulation is rooted in this spread.

The third track covers residential and agricultural users, the only segment institutionally insulated from volatility, who remain on catalog tariffs approved by the state. Commercial and industrial users are moving from the buffer of medium- and long-term contracts toward managed exposure to the market. With Guangdong's 2027 packages tied to market prices, enterprise electricity costs increasingly depend on how companies manage their load curves and choose their linkage ratios.

The environmental value of green electricity is also becoming a separate component. The Southern region's cross-provincial "point-to-point" trades have clearly separated energy prices from environmental attribute value in settlement. Guangdong has become the first province in the Southern region to achieve "hourly-level" precise matching of green electricity. Retailers' green power packages and carbon asset management are shifting from "nice to have" to compliance tools for some export-oriented companies.

After the Southern regional market went live, asking "Will electricity prices rise or fall?" is like asking someone who has just had a medical checkup, "Are you healthy or not?" You first need to know which indicator you are asking about. Spot prices, long-term contracts, cross-provincial location value, residential catalog tariffs, and green-power premiums are five tracks, each with its own supply, demand, and institutional logic.

Fixed-price contracts used to be the safe harbor for electricity retailers. Reservoir capacity used to be merely a technical parameter for hydropower stations. Computing load used to be just a total on the electricity bill. Now, as the tourniquet is being installed, the safe harbor is closing, and technical parameters are being repriced. Once price signals begin flowing in 15-minute intervals, they will not go back.