Core Viewpoint - The article discusses the significant changes in the distributed photovoltaic (PV) market in Shandong, China, particularly the decision to exclude non-natural person household distributed PV projects from the mechanism price bidding starting in 2027, which may lead to substantial market impacts [1][2]. Group 1: Market Dynamics - From 2020 to 2023, the share of newly installed household PV capacity has consistently exceeded 20%, establishing a three-way market division among household, commercial, and centralized PV sectors [1]. - As of September 2023, Shandong has a cumulative installed PV capacity of 91.728 million kilowatts, maintaining its position as the leading province in China for over seven years, with distributed PV accounting for 59.78 million kilowatts [1]. - The mechanism price bidding for renewable energy projects is being promoted across provinces, with Shandong taking the lead in policy changes [1][2]. Group 2: Policy Implications - The exclusion of non-natural person household distributed PV projects from the mechanism price bidding is seen as a response to the influx of capital that deviates from the original intent of distributed PV, which is to promote local consumption [2]. - The current mechanism price system is viewed as a transitional policy, with the future direction aimed at a unified national electricity market that emphasizes the core attributes of electricity generation [2][4]. Group 3: Future Opportunities - The article suggests that rather than avoiding the Shandong market, stakeholders should leverage it as a "testing ground" to explore viable market-oriented business models, such as energy storage integration and virtual power plants [3]. - The recent changes in time-of-use pricing policies are expected to create challenges for distributed PV while benefiting commercial energy storage, indicating a shift in market dynamics [3][4]. - The cancellation of time-of-use pricing does not imply a uniform electricity price but rather a market-driven price formation, which will necessitate a restructuring of energy storage business models [4].

文 | 四川省发展和改革委员 12月1日，四川省发展和改革委员官网发布了《四川2026年电力市场交易总体方案（征求意见稿）》及《四川电力市场规则体系V4.0 （征求意见稿）》在线意见征集情况，详情如下： 2025年11月20日至2 02 5年11月26日，通过省发展改革委门户网站面向社会公开征求《四川2026年电力市场交易总体方案（征求意见 稿）》及《四川电力市场规则体系V4.0（征求意见稿）》意见。意见征集期间，共收到反馈意见5条，建议内容均为分时电价政策方 面。经认真研究，已采纳相关意见建议， 对分时电价执行方式进行优化调整，零售用户非现货联动电量按照现行分时电价政策执行。 | | | | | | 便民日历 智能问答 无障碍 个人中心 繁體 | (网站支持ipv6 | | --- | --- | --- | --- | --- | --- | --- | | ( ** 12 | 四川省发展和改革委员会 SICHUAN PROVINCIAL DEVELOPMENT AND REFORM COMMISSION | | | | 请输入关键字查询 | Ｑ捜索 | | 首页 | 新闻中心 | 政府信息公开 | 政务 ...

文 | 中关村储能产业技术联盟 根据中关村储能产业技术联盟（CNESA）Da t aLi nk全球储能数据库的不完全统计，全国各地已陆续发布12月电网代理购电价格，截止 发稿，除海南、河南以外，其他地区均已发布。 核心要点： 12月，进入迎峰度冬时期，多地开始执行尖峰电价：广东、山东、湖南、重庆、浙江、河北、江苏、北京、陕西、湖北、江西、辽宁、新疆， 仅山东、河北南网、执行深谷电价。 共有 22个地区 最大峰谷价差超过0.6元/kWh， 17个地区 高峰平段价差超过0.3元/kWh。 价差排名：广东地区最大峰谷价差保持首位， 其中珠三角五市最高达到1.298元/kWh，同比增长0.2%； 其次是湖南1.065元/kWh、山东0.985 元/kWh、重庆0.982元/kWh、浙江0.957元/kWh等。 与去年同期相比 ，23个省份 最大价差呈缩小态势，12个省份呈增长趋势。在最大价差超过0.6的省份中，同比增长最显著的是天津（10%）、 河北南网（9,1%）、四川（5.4%）。 | | | | | 2025年12月电网代理购电电价(一般工商业,单一制,1-10kV) | | | | | 单位:元/kWh | ...

文 | 浙江省发改委 1 0月15日，浙江省发改委发布关于公开征求《省发展改革委关于优化分时电价政策有关 事项的通知（征求意见稿）》意见的通知。 其中指出，结合不同季节电力供需形势和负荷特性，优化工商业用户季节性峰谷时段设 置。 与现行政策相比: 全年上午7: 00- 11: 00调整为平时段,下午16: 00- 23: 00调整为高峰 （尖峰）时段，午间低谷增加了一小时。 春秋季（ 2-6 月， 9-11 月） 低谷： 0:00-7:00 、 11:00-14:00 夏冬季（ 1 月、 7 月、 8 月、 12 月） 尖峰： 18:00-22:00 低谷： 0:00-7:00 、 11:00-14:00 高峰： 16:00-23:00 平段： 7:00-11:00 、 14:00-16:00 、 23:00-24:00 高峰： 16:00-18:00 、 22:00-23:00 平段： 7:00-11:00 、 14:00-16:00 、 23:00-24:00 优化重大节假日深谷电价。 劳动节、国庆节假期期间的前三天，以及春节假期（具体时 间以国家公布为准），将0 : 00- 9: 00设置为低谷时段，9 ...

Core Viewpoint - The article discusses the electricity purchasing prices for September 2025 across various regions in China, highlighting the changes in peak and valley pricing, and the impact of time-of-use pricing policies on energy storage profitability [2][4]. Summary by Sections Electricity Purchasing Prices Overview - As of September 2025, most regions have released their electricity purchasing prices, with the exception of Inner Mongolia West, Jilin, and Xinjiang [2]. - No new time-of-use pricing policies have been announced for this month [4]. Peak and Valley Pricing - In September, 18 regions have a peak-valley price difference exceeding 0.6 yuan/kWh, while 16 regions have a peak segment price difference exceeding 0.3 yuan/kWh [4]. - Guangdong has the highest peak-valley price difference at 1.3136 yuan/kWh, followed by Hainan at 1.043 yuan/kWh and Shandong at 0.854 yuan/kWh [4]. Year-on-Year Comparison - Compared to the same period last year, the maximum price differences have generally decreased, with only 9 regions experiencing an increase [4]. - Notable decreases in price differences were observed in Heilongjiang (-57.4%), Jiangsu (-40.6%), and Liaoning (-35.2%) due to adjustments in time-of-use pricing policies [4]. Regional Pricing Details - The article provides detailed tables of electricity prices for various regions, including peak, flat, and valley pricing for different voltage levels [5][6][10][19]. - For example, in Guangdong, the non-time-of-use price for 1-10 kV is 0.6893 yuan/kWh, while the peak price is significantly higher during peak hours [5][10]. Impact on Energy Storage - The changes in time-of-use pricing policies significantly affect the profitability of user-side energy storage systems, with ongoing monitoring by CNESA [4]. Future Data Availability - CNESA will continue to track electricity price trends, with detailed summaries and data analysis available in their global energy storage database [4].

Core Viewpoint - The recent adjustment of time-of-use electricity pricing by Sichuan power companies, including Leshan Electric Power, is aimed at benefiting residential users, which is expected to significantly impact the companies' earnings in 2025 [1][3][4]. Group 1: Impact of Time-of-Use Pricing Adjustment - Leshan Electric Power announced that the new low valley pricing for residential users will lead to an estimated reduction of approximately 16.6 million yuan in its electricity business revenue for 2025 [3][4]. - The low valley pricing will apply to residential users with a "one household, one meter" policy, with rates set at 0.175 yuan/kWh during the low valley period in the wet season and 0.2535 yuan/kWh in the dry and normal water periods [3][4]. - Other Sichuan power companies, such as Xichang Electric Power and Guang'an Aizhong, also reported expected impacts on their earnings due to the new pricing policy, with estimated reductions of 5.55 million yuan and 39.38 million yuan in net profit for 2025, respectively [4][3]. Group 2: Company Performance and Market Reaction - Leshan Electric Power's preliminary net profit for the first half of 2025 is reported to be approximately 7.90 million yuan, while Xichang Electric Power expects around 3.10 million yuan [5]. - Despite the announced impacts of the pricing adjustments on earnings, the capital market has shown strong interest in Leshan Electric Power, with its stock price rising significantly from around 7 yuan to a peak of 18 yuan [5]. - The companies are also exploring new business opportunities, such as Leshan Electric Power's investment in a new energy storage project and Guang'an Aizhong's establishment of an investment fund focused on renewable energy [7].

Core Viewpoint - The recent adjustments to time-of-use electricity pricing policies across various provinces in China, particularly the designation of midday hours as low-cost periods, have significantly impacted the photovoltaic (PV) industry, leading to a decline in solar power profitability and forcing the sector to seek new avenues for revenue generation [1][5][11]. Group 1: Policy Adjustments - Multiple provinces, including Jiangsu, Anhui, and Hunan, have implemented or are in the process of finalizing time-of-use electricity pricing policies that classify midday hours as low-cost periods, with reductions in electricity prices by as much as 60% [1][5][6]. - As of now, over 20 provinces have adopted similar midday low-cost electricity policies, with some provinces setting the price as low as 0.12 yuan per kilowatt-hour [1][6][7]. Group 2: Impact on the Photovoltaic Industry - The new pricing policies have led to a significant decrease in the profitability of solar power projects, with internal rates of return (IRR) for some projects dropping from 12% to as low as 6% [10]. - The midday hours, which traditionally contribute about 40% of daily solar power generation, are now classified as low-cost periods, severely affecting the cash flow of solar power projects that lack energy storage solutions [9][10]. Group 3: Market Dynamics and Future Directions - The current time-of-use pricing mechanism is seen as an administrative measure rather than a market-driven approach, raising questions about its effectiveness in regulating the market [11]. - The photovoltaic industry is urged to transition towards a more integrated model that combines grid connection, self-consumption, and energy storage to adapt to the new pricing environment [12]. - Enhancing the capacity of the electricity grid to accommodate renewable energy sources is deemed essential for the sustainable development of the photovoltaic sector [14][15].

Core Viewpoint - The article discusses the recent adjustments in time-of-use electricity pricing policies across various regions in China, highlighting their significant impact on commercial and industrial energy storage projects [2][3][19]. Group 1: Time-of-Use Pricing Policy - In the first half of 2025, seven regions including Jilin, Sichuan, and Jiangsu officially updated their time-of-use pricing policies, while three regions issued drafts for public consultation [2][3]. - Key characteristics of the adjustments include changing midday peak periods to flat or valley segments, narrowing the fluctuation range, maintaining stable peak-valley fluctuation ratios, and more refined time segment divisions [2][4][15]. - The adjustments reflect local electricity supply and demand characteristics, significantly affecting the operational revenue of commercial and industrial energy storage projects [3][19]. Group 2: Trends in Pricing Policy Adjustments - Time segment adjustments have led to the midday peak being reclassified as flat or valley periods, with 22 provinces now implementing low valley pricing during midday [4][5]. - The fluctuation range has been reduced, resulting in smaller peak-valley price differences, as seen in Jiangsu where the previous policy allowed for broader price fluctuations [7][13]. - Most provinces did not adjust the peak-valley fluctuation ratios, with Jiangsu being an exception, increasing its ratios for different voltage levels [14]. Group 3: Electricity Grid Purchase Price Situation - From January to July 2025, the average maximum peak-valley price difference across 32 regions was 0.618 yuan/kWh, a 9.1% decrease year-on-year [16]. - The regions with the highest price differences were Guangdong (1.297 yuan/kWh), Hainan (1.053 yuan/kWh), and Hunan (0.975 yuan/kWh) [16][17]. - The adjustments in pricing policies, particularly in Jiangsu, have led to a significant decline in the economic viability of energy storage projects, with estimated daily electricity revenue dropping by 47% from the previous year [19][24]. Group 4: Impact on Commercial and Industrial Energy Storage Development - The changes in pricing policies, especially in Jiangsu, have posed challenges to the economic feasibility of energy storage projects, necessitating further market exploration and participation in virtual power plants and demand response initiatives [19][24]. - The rapid growth of renewable energy installations in Jiangsu, which reached over 100 million kW, has influenced the operational models of distributed solar + storage systems [24]. - The article emphasizes the need for thorough market research and monitoring of electricity supply and demand structures in major solar installation provinces to adapt to policy changes and market reforms [24].

Core Viewpoint - The provincial development and reform commission announced an optimization of the time-of-use electricity pricing policy, effective from August 1, aimed at enhancing the efficiency of electricity consumption and ensuring stable economic operations. Group 1: Policy Adjustments - The optimization includes adjustments to peak and valley time periods and an expansion of the execution range of the time-of-use pricing policy [1][3] - The new pricing structure divides the day into three segments: peak, flat, and valley, each lasting 8 hours [1][4] - The peak hours are set from 16:00 to 24:00, while the valley hours span from 00:00 to 16:00, allowing for a continuous 16-hour low-cost period [2][4] Group 2: Impact on Users - The adjustments are expected to lower midday electricity costs by reallocating peak hours, potentially releasing an additional 3 million kilowatts of electricity demand [2] - The reduction of peak hours includes the cancellation of peak pricing in September, resulting in a total decrease of 120 peak pricing hours annually [2] - The policy now allows commercial users with a capacity of 100 kVA or below to choose between time-of-use pricing or flat pricing, enhancing user flexibility [3] Group 3: Specific User Considerations - Hospitals, previously exempt from the time-of-use pricing policy, can now opt to participate based on their electricity consumption needs [3]