从目前的局势来看，第一种方案（经济罚款）的可能性更大。

1、b体育网页版 从2024年欧洲杯、2025年欧国联到如今的2026年世界杯，法国队在三大杯赛的半决赛中连续三次倒在同一个对手脚下。

德尚急需打破心魔，带领球队冲击连续三届闯入世界杯决赛的历史级成就。b体育网页版无论是深耕招聘等垂直领域，还是通过极致的成本控制，为价格敏感型市场提供高性价比的模型方案；亦或是敏锐捕捉市场变化，为头部客户提供定制化的基础设施服务。

2、AI时代数据存储架构如何创新？西部数据在WAIC公布路线图

（文｜AI Boom Global，整理｜杨秀娟）2026 FIFA世界杯决赛夜，上海INS新乐园变身为乐事观赛派对现场。

3、杜锋怎么了？广东队怎么了？聊聊这两个话题！

而在算力欠缺的背后，更需要搞明白一个事实，那就是GPU有效算力利用率仅30%-60%。

4、揭秘：温网的奖杯雕刻师们是如何工作的？

一签赚0到3000元。

5、统治网坛二十载，从少年到暮年，德约大满贯曾有三次未能破发

球队方面希望拉克鲁瓦续约留队，只是球员本人已下定决心离开。

西甲豪门皇马则是2.165亿欧元，不过银河战舰的实际投入依然可观，姆巴佩虽在2024年零转会费加盟，但附带1亿欧元的签字费，还没计算他每赛季3200万欧元的薪资。

接下来的赛季同样不顺：季前赛小腿受伤，所幸赶在赛季开始前恢复；同年晚些时候，又一次肌肉问题让他缺席多场；2022年1月，轻微肌肉拉伤再次短暂缺阵。

6、“中国光伏行业正经历深度调整”

本场挪威大概率会延续此前的控球打法，利用中场优势主导球权，通过边路传中持续施压英格兰防线。

而阿根廷需要梅西的超强发挥，以及阿尔瓦雷斯不讲道理的远射，要不然常规战术难敌英格兰。

7、公告“乌龙”：近亿元中标额“说没就没” 金冠股份及相关责任人收警示函

西汉姆联刚刚降入英冠，萨默维尔自然成为多家英超球队争抢的对象，罗马也一度非常接近将他收入囊中。

同期，动力电池出货量约630GWh，同比增长超30%。

8、外线失准，客场失利！青岛崂山啤酒70-87不敌北京北汽

小组赛三战全胜进10球失2球，1/16决赛面对瑞典3比0轻松解决战斗，1/8决赛对阵球风强硬的巴拉圭1比0小胜。

历史告诉我们，从英超中游球队提拔好教练到豪门很少成功，但伊劳拉看起来是最有可能打破这个魔咒的人。

在诺坎普翻新期间，球队曾于2023-24及2024-25两个完整赛季在此作战。

9、科创向新 聚力前行 上海交通大学“十大科技进展”成果揭晓

但可以确定的是谷歌依然是一台高效的赚钱机器，广告的现金流、云的增速都足以支撑它继续留在牌桌上。

在1/4决赛和半决赛的关键战役中，凯恩的发挥难言出色。

10、米体：费内巴切为莱奥开出税后年薪800万欧元外加奖金

财报什么时候发布，临床数据什么时候公布，政策会议什么时候举行，都可以提前写在日程表上。

达利奇执教的克罗地亚，在过去两届世界杯上分别获得亚军和季军，证明了他们是大赛型球队。

1、憾负科斯蒂亚，王曦雨说：还是被鼓励了一下，这种感觉挺好的。

” 他一开始没听懂，后来才知道，对方说的是一笔合同之外的“茶水费”。

2、记者：76人老板与詹姆斯进行交流，强烈希望詹姆斯加盟球队

整体来看，沙特阵容虽然星味不足，但防守组织纪律性强，这也是他们能在2022年爆冷击败阿根廷的关键。

3、郑钦文打脸黑子还得再等等 草地赛季考卷太难 中国军团前进不易

今天我们证明了自己懂得如何面对失利。防蓝光眼镜、护眼灯、叶黄素护眼？真不如把手机、电脑的字调大！此外，法国队中后场的稳固配置，为前场攻击群提供了坚实支撑。

4、考瑞尔批评紫薇消极等待，西班牙名将称阿卡缺席巡回赛如地狱

除此之外，他的表现更多停留在偶尔的灵光一现，远没有达到持续输出的水准。

5、休赛期 火箭有哪些运作空间 火箭拆队的概率到底有多大

分析每家的赛程，各自有各自的难关。

6、体育记者协会评本届世界杯最佳球员：梅西第一，罗德里第六

据知名记者莫雷托爆料，二人之间发生了一些相当激烈的争论，当然出发点都是为了米兰的利益着想。

有条件的家庭，父母本身在职场、有圈子，孩子从小耳濡目染"该怎么规划"；普通家庭的孩子，父母可能自己都没进过写字楼，根本给不了这类信息。

自2月16日以来，他再未为利雅得新月踢过一场正式比赛。

7、官方：巴萨签下阿德耶米，据悉转会费为2200万+700万欧浮动

高端紧缺与低端过剩并存，能量密度160Wh/kg以上的高端电池需求强劲反弹，市场份额从2025年的6%跃升至11%，以三元电池为主。

对于上赛季中场控制力下滑的米兰而言，埃德森正是理想的后腰人选。

8、Timberland x RDET 全新联名三眼船鞋登场

为什么？ “以前投资亏了，可以说是市场风险，创业九死一生。

面对山东泰山，大连队放弃了无谓的控球，祭出低位防守与快速反击的致命杀招。

Nexfin News — China’s lithium battery industry is undergoing a rite of passage, transitioning from wild expansion to disciplined competition. In the first half of the year, a rare divergence between surging corporate earnings and falling stock prices brought a permanent shift in the sector’s underlying dynamics into sharp focus. By mid-July, A-share lithium battery stocks pulled back despite dramatic midyear earnings forecasts. Tianqi Lithium projected net profit growth of up to 4,935% year-over-year, EVE Energy forecast a 95% to 110% increase, and both Sunwoda and REPT BATTERO turned profitable again. Across the supply chain—from upstream lithium salts to downstream battery makers—most companies reported substantial operational gains. Yet robust earnings failed to stop equity valuations from sliding. On July 8, Chengxin Lithium hit its daily downside limit, Yahua Group dropped over 15%, and Tinci Materials saw more than 30 billion yuan in market value evaporate within a week. Ganfeng Lithium has fallen roughly 38% from its peak, while market leader CATL is down about 20%. The immediate trigger for the selloff was the resumption of operations at CATL’s Jianxiawo lithium mine. On June 29, the mine secured its safety production permit, which was officially posted on the Credit China website on July 7. The site—the world’s largest single lepidolite mine—had been idle for over ten months. With an annual capacity of roughly 100,000 metric tons of lithium carbonate, it previously accounted for 8% to 10% of China’s total output. Its return brings over 45,000 tons of additional supply in the second half of the year, hitting elevated lithium prices head-on. Futures markets reacted instantly: on June 18, as restart speculation grew, the main lithium carbonate contract fell 6.58% in a single session, beginning a steady slide from its May high of 205,000 yuan per ton. This stark contrast between thriving industrial output and falling stock prices coincided on the surface with lithium carbonate pulling back rapidly from its May peak of 200,000 yuan per ton to 151,000 yuan. But a more critical question remains: is this the sign of a cyclical peak, or is the industry undergoing a profound revaluation? Answering that requires stepping back to examine the paradigm shift that unfolded across the lithium battery sector between 2025 and 2026. The essence of this shift is not the fluctuation of any single price signal, but a permanent realignment of the industry's competitive playbook—moving from "who expands the fastest" to "who possesses technology, steady profits, and global compliance capabilities." From 60,000 to 200,000 In late June 2025, battery-grade lithium carbonate dropped below 60,000 yuan per ton, touching a three-year low of 59,900 yuan. Lithium salt producers across the sector incurred heavy losses, forcing widespread shutdowns among small and medium-sized manufacturers. From Australian hard-rock mines and small African projects to domestic lepidolite producers, virtually all marginal capacity went offline that summer. A two-and-a-half-year price slump accomplished its single necessary function: clearing out excess supply. By the fourth quarter of 2025, supply and demand dynamics reversed faster than the market had anticipated. The initial spark came from energy storage demand. Data from research firms including InfoLink show that global energy storage cell shipments reached roughly 610 GWh in 2025, up over 90% year-over-year, with fourth-quarter volumes alone topping 200 GWh. Production schedules showed energy storage cells clearing lithium carbonate inventories at an accelerating quarter-over-quarter pace. As growth in electric vehicle batteries moderated, energy storage stepped in not just to absorb excess capacity, but as the industry's primary growth engine. Surging demand was only half the story; supply contracted just as sharply. Small African mines and high-cost domestic lepidolite operations exited the market. Meanwhile, Zimbabwe announced a temporary suspension of lithium concentrate exports in February—a country that accounted for 15.5% of China’s lithium concentrate imports in 2025. Although Australia remained the primary pillar of China's upstream raw material supply at over 50%, the policy further tightened market expectations surrounding upstream supply. Zimbabwe's Ministry of Mines later confirmed that a formal export ban would take effect in January 2027. The tension between supply and demand peaked with the onset of a structural global deficit. Morgan Stanley estimated in early 2026 that the global market would face a shortfall of roughly 100,000 metric tons of lithium carbonate equivalent (LCE) for the year. Soochow Securities calculated total annual lithium mine supply at approximately 2.14 million tons, representing 440,000 tons of new capacity—most of which was not slated to come online until after the third quarter. That timing gap fueled the price rally during the first half of the year. Driven by these converging forces and inventory restocking across midstream channels, lithium carbonate surged from 70,000 yuan per ton in October 2025 to 200,000 yuan by May 2026. Unlike the speculative frenzy that drove prices to 600,000 yuan in 2022, this recovery occurred after capacity had been fully built out, anchored firmly by real end-user demand. Gaogong Industry Research Institute (GGII) summarized the shift: "This is not a bubble, but a return to fundamental value. The structural surge in energy storage demand, combined with supply-side consolidation, has redefined a rational price band for lithium." Prices doubled quickly due to market sentiment and downstream stockpiling. July’s price correction reflected two main factors: the gradual release of new supply and downstream resistance to inflated raw material costs. Analysts generally expect lithium carbonate to trade within a median range of 120,000 to 160,000 yuan per ton for the full year—a price level that keeps most producers profitable without triggering another round of reckless expansion. Energy Storage as the New Engine In the first half of 2026, China's energy storage battery shipments reached roughly 485 GWh, a year-over-year increase of over 80%. Over the same period, power battery shipments totaled roughly 630 GWh, up over 30%. The gap between the two segments is narrowing rapidly. Structural figures are even more telling. In the first quarter of 2026, Chinese energy storage battery shipments totaled about 209 GWh, up 115% year-over-year and accounting for roughly 40% of total lithium battery shipments. By June, energy storage cells made up nearly 41% of monthly production schedules—up from around 30% a year earlier. According to InfoLink, full-year energy storage cell shipments in 2025 reached roughly 610 GWh, approaching 70% of power battery shipments over the same timeframe. Energy storage is no longer a side business for battery makers; it has emerged as an independent market reshaping demand across the industry. Behind this market realignment lies a fundamental shift in purchasing drivers. Before 2024, domestic energy storage growth was driven primarily by mandatory integration policies, which required wind and solar projects to install storage capacity. That regulatory setup created low-quality demand, leading to poor utilization, weak financial returns, and inconsistent cell quality. Between 2025 and 2026, market dynamics pivoted from regulatory compliance to commercial economics. The shift first materialized in the domestic market. In early 2026, the National Development and Reform Commission and the National Energy Administration jointly issued new capacity pricing regulations (NDRC Pricing [2026] No. 114), establishing a national capacity tariff mechanism for standalone energy storage facilities. Local standards were set between 165 and 330 yuan per kilowatt-year, depending on the province. Surveys by Soochow Securities indicated that internal rates of return (IRR) for storage stations in several provinces crossed the 6% threshold required for commercial viability, especially where peak-to-valley price spreads exceeded 0.3 yuan per kWh. IRRs for top-tier projects reached as high as 10%, fundamentally improving overall demand quality. This domestic turning point coincided with an explosion in international demand. Major solar-plus-storage projects launched across the Middle East, particularly in Saudi Arabia and the United Arab Emirates, with individual project capacities regularly reaching several gigawatt-hours. In emerging markets across Australia, Southeast Asia, and Africa, weak power grids and rising renewable energy penetration transformed energy storage from an optional luxury into a necessity. Soochow Securities calculated that utility-scale storage installations in emerging markets grew 233% year-over-year in 2025, with an additional 69% increase projected for 2026. In Europe, energy security concerns and green energy quotas kept commercial, industrial, and residential demand robust. GGII projects that global energy storage battery shipments in 2026 will reach 800 to 1,100 GWh, representing year-over-year growth of 30% to 70%. Even at the mid-point estimate of 900 GWh, energy storage output is positioned to approach or match power battery production this year. As the industry's primary growth engine shifts, its core operational requirements are evolving as well. Power battery demand is dominated by automakers, whose priority is cost efficiency. The customer base for energy storage, however, is far more diverse: utility operators prioritize long cycle life and safety, data center owners require high discharge rates and extreme reliability, and overseas projects demand lifecycle compliance and supply-chain traceability. Winning in these markets requires technological adaptation, solid project execution, and international compliance capabilities rather than sheer scale. Oversupply or Industry Maturity? Evaluating battery utilization rates requires a closer look at the underlying numbers. In May 2026, the single-month installation rate for Chinese power batteries dropped to roughly 38%. Over the first five months of the year, cumulative power battery installations totaled 259 GWh against 863 GWh produced—yielding an overall utilization rate of about 30%. Factory output continues to outpace vehicle installations, leaving a substantial share of manufacturing lines underutilized. The five-year trajectory of Chinese power battery installation rates tells a clear story: 70% in 2021, 54% in 2022, roughly 52% in 2023, 50% in 2024, 44% in 2025, and 38% by May 2026. This steady decline in installation rates offers clear evidence of an industry transitioning from rapid early growth into maturity. Yet labeling the sector simply as oversupplied misses crucial nuances. The market is not experiencing a uniform glut; rather, it is undergoing sharp structural polarization. High-end shortages coexist alongside low-end surpluses. Demand for premium batteries with energy densities above 160 Wh/kg—primarily ternary chemistries—rebounded sharply, rising from a 6% market share in 2025 to 11%. Meanwhile, low-end products under 125 Wh/kg have effectively been phased out. Demand has also diverged sharply between commercial and passenger vehicles. Driven by subsidy policies, battery demand for electric heavy trucks and delivery vans surged, with battery consumption for electric cargo vans rising 169% year-over-year. By contrast, electric buses—once the industry's primary market—fell to fifth place. While market leadership remains dynamic, the nature of competitive moats is shifting. CATL and BYD together retain a 68% market share, but second-tier players like Gotion High-tech, EVE Energy, Svolt Energy, and Hithium are making gains. Competition is shifting from pure capacity expansion to technological differentiation and operating margins. From another perspective, declining installation rates are a natural hallmark of industry maturity. As annual growth moderates, a drop in capacity utilization from 70% to 40% is to be expected. While systemic capacity pressures continue to weigh on industry-wide profitability, and smaller players face ongoing price competition, market leaders retain the balance sheet strength to navigate the transition. As top-line growth slows, manufacturers lacking proprietary technology, accumulated capital, or global compliance infrastructure risk being squeezed out. This shift explains recent strategic course corrections by major capital allocators. Anode producer Sinomatech canceled a 10.3 billion yuan expansion, cathode supplier Dynanonic abandoned a 10 billion yuan project, and separator manufacturer Semcorp terminated a roughly 2 billion yuan facility in Malaysia. Top-tier players reining in massive investments is a classic sign of an industry transitioning from early expansion to financial discipline. This reallocation of capital does not mean expansion has halted entirely. In the first half of 2026, manufacturers announced over 65 new planned projects representing more than 1,500 GWh of capacity and over 220 billion yuan in total investment. Hunan Yuneng disclosed a 24 billion yuan expansion, while Yahua Group announced additional capacity in Zimbabwe. Expansion continues, but the prerequisites have changed: only enterprises with strong technical barriers, cash reserves, and global compliance infrastructure are positioned to invest while competitors scale back. Technology Race 2.0: Three Fronts If the period between 2022 and 2024 was defined by a race for manufacturing scale, 2025 and 2026 have marked a pivot toward technological differentiation across three distinct fronts. Front One: Structural Shortages in 314Ah Cells The central operational focus for the energy storage supply chain in 2026 has been a structural shortage of 314Ah cells rather than short-term price swings in raw lithium. By March, average spot prices for 314Ah cells from tier-one manufacturers approached 0.40 yuan per Wh, with small-lot orders reaching 0.45 yuan per Wh—a surge of over 25% within six months compared to the 0.30 to 0.34 yuan per Wh seen in August 2025. The immediate driver was rising raw lithium costs—at 180,000 yuan per ton of lithium carbonate, theoretical cell production costs sit between 0.35 and 0.38 yuan per Wh. However, the root cause was a supply gap during the industry's transition to larger formats. As manufacturers shift from 280Ah and 314Ah form factors toward 500Ah+ designs, investment in legacy 314Ah production lines has largely ceased. Because next-generation 500Ah+ cell capacity will not scale up until late 2026, production ramps and customer testing created a temporary bottleneck. During this supply gap, the deficit widened significantly, pushing delivery timelines for select orders into 2027. This dynamic reflects a clear shift in industry economics: market returns are no longer guaranteed simply by bringing capacity online, but by executing format transitions ahead of competitors. CATL has already deployed its 587Ah cell in a 2.4 GWh standalone storage project in Inner Mongolia, while EVE Energy has accelerated mass production of its 628Ah format. With the shift toward larger cell formats underway, manufacturing execution is everything. While 314Ah supply constraints present an immediate operational challenge, solid-state technology represents the long-term competitive battlefield. Front Two: A Return to Realism in Solid-State Batteries Although 2026 has been touted as the inaugural year for commercial solid-state battery deployment, that label requires qualification: current production consists almost entirely of semi-solid (hybrid liquid-solid) chemistries. Models including the NIO ET9, MG4, GAC Hyper, and Chery vehicles have entered the market equipped with semi-solid packs featuring energy densities between 350 and 400 Wh/kg. Because these designs remain compatible with over 90% of existing liquid battery production lines, retooling costs remain manageable and rollout schedules are accelerating. However, the commercial reality of all-solid-state technology remains far more complex than vehicle showroom specifications suggest. In March 2026, Ouyang Minggao, an academician at the Chinese Academy of Sciences, offered a candid assessment: "To be prudent, it is best not to commercialize all-solid-state battery vehicles over the next two years." He cited three major technical hurdles: solid-solid interface stability, where microscopic gaps between solid electrolytes and electrodes cause internal resistance to spike; lithium dendrite formation and safety risks; and the environmental volatility of sulfide electrolytes, which decompose upon exposure to moisture and demand strict manufacturing conditions. Industry leaders report steady if measured progress. CATL’s sulfide-based solid-state cell has surpassed an energy density of 500 Wh/kg, with small-scale production anticipated in 2027. BYD’s 20 GWh facility in Chongqing is scheduled to begin semi-solid production in the third quarter of 2026, targeting pilot runs for all-solid-state cells in 2027. Gotion High-tech plans to initiate operations on a 2 GWh solid-state line by late 2026, while EVE Energy has produced sample 60Ah solid-state cells. A clear timeline has taken shape: 2026 is focused on pilot line verification, 2027 on vehicle testing, and 2030 on potential large-scale commercialization. The implementation of recommended national standard GB/T 43568-2026 (Solid-State Batteries for Electric Vehicles) on July 1, 2026, established an initial regulatory framework for long-term development. Ultimately, 2026 marks less the mass adoption of solid-state technology than a recalibration of market expectations. Meanwhile, an underappreciated demand driver is quietly gathering momentum. Front Three: AIDC Storage as AI Infrastructure In the first five months of 2026, global energy storage shipments for AI data centers (AIDC) reached 10 GWh, surpassing total volume for all of 2025. Industry research firms project that global AIDC storage demand will reach 300 to 400 GWh by 2030—more than twenty times its 2025 level. Capital deployment in the segment is ramping up. CATL invested roughly 4.1 billion yuan to acquire a strategic stake in Senter Power to secure positioning in high-voltage DC power distribution for data centers, while winning a bid for a 2 GW / 4 GWh storage project at a computing center in Guizhou. Fluence signed agreements covering a 12 GW pipeline of potential projects with two major U.S. cloud providers, LG secured eight data center storage contracts totaling 6 GWh—including projects for Oracle—and Panasonic announced 350 billion yen in battery investment aimed at tripling its data center storage revenue. The expansion of AIDC storage is driven by a widening gap between AI computing power demands and utility grid capacity. Power consumption per rack in modern AI facilities has jumped from 5–8 kW in traditional data centers to 40–100 kW, while grid connection approvals and capacity upgrades often take three to five years. Onsite battery systems serve both as backup power and as a bridge to accelerate facility commissioning. Energy storage is moving from an auxiliary fallback to an integrated structural component of data centers. Following NVIDIA’s October 2025 announcem