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2025-10-20

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On October 13, the National Development and Reform Commission and the National Energy Administration jointly issued the Notice on Printing and Distributing the "Inter-Provincial and Inter-Regional Power Emergency Dispatch Management Measures" (NDRC Operation Regulation [2025] No. 1193), which will take effect on October 1, 2025, with a validity period of 5 years.

National Policies and Headlines

01 The National Development and Reform Commission and the National Energy Administration have issued the "Inter-Provincial and Inter-Regional Power Emergency Dispatch Management Measures."

On October 13, the National Development and Reform Commission and the National Energy Administration jointly issued the Notice on Printing and Distributing the "Inter-Provincial and Inter-Regional Power Emergency Dispatch Management Measures" (NDRC Operation Regulation [2025] No. 1193), which will come into effect on October 1, 2025, with a validity period of 5 years.

The document mentions that when safety risks arise during power operations or when there is a shortfall in the balance between electricity supply and demand, resources should first be allocated and prices formed through market-based mechanisms such as inter-provincial and inter-regional medium- to long-term power trading and spot trading. If these market-driven approaches cannot fully address the issue, the power dispatching agency will organize and implement emergency dispatching at the day-ahead and intraday stages.

Emergency dispatch should be seamlessly integrated with market-based transactions. In principle, the bidding prices, volume offers, and trading routes from the inter-provincial and inter-regional electricity spot markets should serve as the reference basis. Moreover, the emergency dispatch of power capacity must not exceed the volume that the receiving party has declared but failed to secure in either the electricity spot market or inter-provincial incremental trading.

Regarding the price mechanism and settlement management, emergency dispatch determines the on-grid electricity price in the sending province by adding the market transaction price of the corresponding period within the province—along with the system operation costs for that month's equivalent power volume. Specifically: if the electricity spot market operates continuously, the market transaction price is based on the real-time spot prices within the province; if the electricity spot market does not operate continuously, the market transaction price is set according to the average mid-to-long-term market transaction price from the previous month within the province.

Emergency dispatch pricing on the receiving province's grid side is determined by the higher of either the inter-provincial spot market settlement price cap or the clearing price cap of the Southern Regional spot market.

If the receiving province's delivered electricity price, after deducting the sending province's grid-connected electricity price, transmission costs at each stage, and line-loss discounts, yields a positive result, the associated costs will be included in the sending province's system operation fees and shared jointly by the users and power generation enterprises in the sending province, with a sharing ratio of 80% for users and 20% for power generators. If the calculation results in a negative value, the relevant costs will instead be incorporated into the receiving province's system operation fees, to be borne entirely by the users in the receiving province. Power generation enterprises will settle their payments based on the market transaction price in the sending province plus their share of the costs. Emergency dispatch transmission prices and line-loss discounts will be implemented according to the standards approved by the State Council's pricing authority.

When the emergency dispatch for inter-provincial and inter-regional DC special projects is opposite to the actual physical transmission power, the emergency dispatch's inter-provincial and inter-regional transmission charges and line-loss discounts are used to offset the transmission costs and line-loss discounts of the inter-provincial and inter-regional DC special projects.

The electricity operation authorities of each province (region, municipality) should collaborate with relevant parties to guide grid enterprises and power trading institutions in clearly defining the allocation and cost-sharing mechanisms for emergency dispatch power and associated electricity charges—specifically, how these are distributed between the sending provinces' generation facilities and user sides, as well as among the receiving provinces' user bases—based on the principle of "whoever provides support reaps the benefits, and whoever benefits bears the costs." Grid enterprises and power trading institutions are required to separately collect data related to emergency dispatch power and associated electricity charges as stipulated. Notably, emergency dispatch power will not be included in the calculation of ancillary service fees or subject to deviation-quantity assessments.

The settlement price for electricity dispatched across operational zones under emergency scheduling shall be determined by agreement between the sender and the receiver; if no such agreement is reached, the settlement will follow the price mechanism stipulated in these measures.

02 The National Development and Reform Commission has issued an announcement seeking public input on the "Implementation Measures for the Minimum Proportion Target of Renewable Energy Consumption and the Responsibility Weight System for Renewable Energy Power Consumption (Draft for Comments)."

On October 13, the National Development and Reform Commission released the "Implementation Measures for Minimum Renewable Energy Consumption Proportion Targets and Renewable Energy Power Consumption Responsibility Weight System (Draft for Comments)." The document states that, guided by these measures, it will oversee the formulation, monitoring, and evaluation of renewable energy consumption targets for energy users as well as the renewable energy power consumption responsibility weights assigned to provincial-level administrative regions. According to the document, the minimum renewable energy consumption targets are divided into two categories: the minimum proportion of renewable energy electricity consumption and the minimum proportion of non-electric renewable energy use. Specifically, the electricity consumption target encompasses all types of renewable energy generation, while the non-electric consumption target includes renewable energy applications such as heating (and cooling), hydrogen/ammonia/alcohol production from renewables, and biofuels. The State Council's energy authority will annually set the minimum targets for both renewable energy electricity consumption and non-electric renewable energy use, which will then be implemented by provincial-level energy authorities in collaboration with relevant industry regulators. Notably, key energy-consuming sectors can meet their minimum renewable energy electricity consumption targets through self-generated and self-used renewable energy, direct green power connections, or via green certificate-based green power trading (including transfers).

03 The National Development and Reform Commission has issued a notice on the promulgation of the "Special Management Measures for Central Budget-Funded Investment in Energy Conservation and Carbon Reduction."

On October 14, the National Development and Reform Commission issued a notice announcing the release of the "Special Management Measures for Central Budget Investment in Energy Conservation and Carbon Reduction."

The special management measures indicate that central budget investments will be allocated through direct investment, capital injection, investment subsidies, and other methods tailored to actual conditions, supporting projects in sectors that significantly contribute to achieving the "dual carbon" goals and hold substantial potential for energy conservation and carbon reduction.

Key areas of support include: energy conservation and carbon reduction, clean substitution of coal consumption, circular economy initiatives that drive decarbonization, low-carbon, zero-carbon, and negative-carbon demonstration projects, and the development of foundational capabilities for peaking carbon emissions and achieving carbon neutrality.

Among these, regarding low-carbon, zero-carbon, and negative-carbon demonstration projects, the management measures specify: supporting the demonstration application of advanced, green, and low-carbon technologies that are both effective and practical. They also support projects such as the construction of energy supply facilities, infrastructure upgrades, and process-based carbon reduction initiatives aimed at helping zero-carbon parks and zero-carbon transportation corridors achieve near-zero carbon targets. Additionally, the measures encourage green methanol and sustainable aviation fuel production projects, as well as large-scale carbon capture, utilization, and storage (CCUS) infrastructure development.

The support ratios for demonstration projects such as low-carbon, zero-carbon, and negative-carbon initiatives all stand at 20% of the approved total investment.

04 The "Three-Year Doubling Action Plan for Electric Vehicle Charging Infrastructure Capacity (2025–2027)," released by the National Development and Reform Commission, the National Energy Administration, and other relevant departments

On October 15, the National Development and Reform Commission, the National Energy Administration, and other departments released the "Three-Year Action Plan for Doubling Electric Vehicle Charging Infrastructure Capacity (2025–2027)," which outlines efforts to further boost consumer confidence and accelerate the widespread adoption of electric vehicles by continuously improving the charging network, enhancing charging efficiency, elevating service quality, and fostering an innovative industry ecosystem. By the end of 2027, the plan aims to establish 28 million charging facilities nationwide, providing over 300 million kilowatts of public charging capacity—enough to meet the charging needs of more than 80 million electric vehicles, thereby doubling the nation's overall charging infrastructure capacity.

Local Policies and Headlines

01 The Zhejiang Provincial Development and Reform Commission is publicly seeking opinions on the "Notice from the Provincial Development and Reform Commission Regarding Matters Related to Optimizing Time-of-Use Electricity Pricing Policies (Draft for Comments)."

On October 15, the Zhejiang Provincial Development and Reform Commission publicly sought opinions on the "Notice from the Provincial Development and Reform Commission Regarding Matters Related to Optimizing Time-of-Use Electricity Pricing Policies (Draft for Comments)." Compared to the current policy, the 4-hour period from 7:00 a.m. to 11:00 a.m. throughout the year will now be adjusted to the regular rate period, while the 7-hour window from 4:00 p.m. to 11:00 p.m. will be shifted to the peak (peak) period. Additionally, the midday off-peak period will be extended by one hour.

In addition, during the first three days of the Labor Day and National Day holidays, as well as the Spring Festival holiday (the exact dates will be announced by the national authorities), the period from 0:00 to 9:00 will be designated as the "low-demand hours," while 9:00 to 15:00 will be considered the "deep-demand hours."

Standardize the time-of-use electricity price fluctuation ratio for industrial and commercial users. The flat-rate electricity price will be determined by adding the feed-in tariff, transmission and distribution line loss charges, and system operation costs, with subsequent upward or downward adjustments based on this base rate. The specific fluctuation ratios for peak, high-peak, flat, off-peak, and deep-off-peak periods are 2.05:1.85:1:0.4:0.2, respectively.

02 Hebei Provincial Development and Reform Commission and six other departments jointly issued the "Notice on Strengthening Safety Management of Electrochemical Energy Storage Power Stations."

On October 9, Hebei's Development and Reform Commission along with six other departments jointly issued the "Notice on Strengthening Safety Management of Electrochemical Energy Storage Power Stations," which clearly states: Grid companies must rigorously oversee the grid connection and acceptance processes for electrochemical energy storage stations. Any station failing to meet national (or industry) grid-connection technical standards will be strictly prohibited from connecting to the grid while still flawed. In the early stages, a comprehensive analysis of the project's safety production conditions and facilities must be conducted, resulting in a written report that should be properly archived for future reference. After completion or trial operation, a thorough inspection of the project's safety facilities is required—any identified issues must be promptly addressed and rectified. Finally, once the project has been operational for a certain period, a safety assessment should be carried out to ensure the entire lifecycle of the project remains safe and reliable.

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