Guangdong province, a significant industrial hub in China, has implemented a new gas power policy that is fundamentally altering the role of gas-fired power plants. Historically operating as baseload generators with guaranteed dispatch hours and approved tariffs, these plants are now transitioning to primarily peak-only operations under a pure economic dispatch model. This shift means plants must bid to recover fuel costs, with capacity payments significantly increasing to cover full capital expenditure, compensating for availability rather than generation. This policy, described by Wood Mackenzie as the "Guangdong Model," is seen as a blueprint for how China's largest gas power market is adapting to a grid with increasing renewable energy.
This change in policy is largely driven by a substantial increase in renewable energy capacity in Guangdong, with solar and wind capacity growing from 14 GW to 105 GW between 2020 and 2026. This surge necessitates flexible, dispatchable generation to balance intermittent output. In response, gas power capacity more than doubled from 27 GW to 61 GW during the same period. While gas-fired capacity continues to grow to support grid stability, the policy shift implies fewer running hours for these plants, which is projected to slow the growth of China's overall power gas demand compared to previous expectations of baseload operations.
Geopolitical tensions, specifically an ongoing war in the Middle East, have exacerbated challenges for Guangdong's energy sector. The conflict has constrained natural gas supply from the Persian Gulf, leading to a significant increase in electricity prices. Spot rates climbed to nearly 680 yuan ($100) per megawatt-hour on April 14, a three-year high, up from an average of around 350 yuan in the previous month. This has prompted Guangdong to ask local power producers to rebuild coal stockpiles, curb gas usage, and accelerate nuclear generation additions. Power market brokers are also facing difficulties, with some attempting to cancel long-term supply deals with factories due to surging spot prices.
Despite the current challenges, Wood Mackenzie analysis suggests that for gas power fleets to economically replace subcritical coal plants, spot LNG prices would need to fall to about $6/mmbtu, considering taxes, regasification, and pipeline tariffs, assuming a $95/ton coal price. Until then, most gas fleets are expected to remain in peaking roles, limiting their impact on total power gas demand. Industry executives, including those from GAIL and PetroChina, anticipate that LNG demand in China, India, and Pakistan will rebound once the Middle East supply crunch ends and prices cool, reversing a trend of increased coal and oil usage to replace gas during the conflict.
Guangdong represents a crucial indicator for China's energy market, accounting for 10% of the country's GDP and approximately one-third of its total gas power capacity. In 2025, the province consumed 41 bcm of gas and had LNG demand of 18 Mt, representing 10% and 28% of national totals, respectively. The "Guangdong Model" is expected to be replicated across other Chinese provinces, leading to a structural downside for gas demand growth in the power sector nationwide, as plants run fewer hours despite continued capacity expansion.
