E2·Fingrid via Google News·来源发布 2025/9/26
Fingrid保障用电增长输电容量
Fingrid已为电力消费增长和新的工业投资锁定输电容量，但芬兰南部的新储能设施接入限制仍在继续。此次安排反映出局部电网接入能力仍然紧张，容量分配需要优先满足新增负荷。由于正文未给出更多政策条款和数据，现阶段可确认的直接影响是储能项目在南部地区接网仍受约束，而工业用电扩张获得了容量保障。
restriction原始依据
返回观察雷达
并网与容量·发现阻力·结论存在分歧
GB并网与容量批量证据呈现集中问题信号
在并网与容量域识别 11 个独立问题证据单元，覆盖 907 条原始记录，来自 9 个独立发布机构、7 个地区；最大证据组来自 National Grid Electricity Distribution，覆盖 894 条原始记录；找到 6 个可直接比较的反证或进展，覆盖 112 条原始记录。
为什么重要
- 如果该信号持续，可能影响并网与容量相关项目的转化速度、成本或可靠性。
还缺什么
- 同口径项目分母与时间序列
- 项目级状态、发生时间和最终结果
- 来自业主或监管方的独立验证
替代解释
- 材料增长可能来自披露频率变化，而不是问题真实恶化。
- 同一事件可能被不同来源重复报道，需要核对项目与事件身份。
审计信息
- 本页只使用欧洲和中国范围内的证据。
- 本轮输入 1302 条材料
- 问题卡生成于 2026/9/5 07:13:55
- 内部排查优先级为 52 分；它不代表发生概率或严重程度。
问题依据 · 11
E1·Energy Networks Association Innovation Portal·采集/快照 2026/8/10
Connected Island
Complete ProjectReferenceNumber: NIA_SPEN_0095 Status: Complete StartDate: 2024-04-01T00:00:00Z EndDate: 2024-12-31T00:00:00Z OwnerNetwork: SP Energy Networks Distribution TechnologyAreas: ["Asset Management","Distributed Generation","Low Carbon Generation"] FundingMechanisms: ["NIA RIIO-2"] StrategyThemes: ["Net zero and the energy system transition"] Connected Island Status: Complete Project Reference Number: NIA_SPEN_0095 STRATEGY THEME: Net zero and the energy system transition START DATE: Apr 2024 END DATE: Dec 2024 Contact Lead Network Project summary Funding Licensee(s): SPEN-D - SP Energy Networks Distribution Funding mechanism: NIA_RIIO-2 Technology: Asset Management Distributed Generation Low Carbon Generation Expenditure: £196,000 Third Party Collaborators: Ricardo Share project Save to my account Summary Learnings Documents This project will support the strategic improvement and evolvement of the planning and connections process to meet net zero in a timely and cost-effective manner. The current connection process has been identified as being over-subscribed, representing a bottleneck. To achieve the Net Zero targets of the country, it is considered necessary to support the development, implementation and connection of low carbon technologies onto the electricity network. This project will be a feasibility study, and would look to investigate, develop and trial new technical and procedural issues associated with connection applications for new developments. It will help maximise potential additional distributed generation on the grid by implementing a "smart island" microgrid for a specified network community. Export and import capacity requirements would be reduced, compared to a standard firm connection. Benefits Merits: Simplifying community connections and reducing the costs and lengthy application windows associated with network reinforcement. Improve queue management and supporting the roll-out of low carbon solutions. The project will enable the prompt introduction of numerous low-carbon technologies at scale within a self-managed network, without the requirement for major grid reinforcement. The connections queue can be efficiently managed to ensure the above benefit can be realised Faster and cheaper network transformation can occur Learnings throughout are captured and used to promote a BaU design and connection application process Benefits - This project will support the business strategy to: Develop a Net-Zero network and support the transition to DSO by enhancing our connections service Transition from service provider to partner by supporting communities achieve Net Zero transition Prepare the business for a sustainable and digital future by supporting the development of Microgrids View Project as PDF Select all Title Date modified Document type NIA_SPEN_0095 Close Down Report 2026-02-11 11_10 (57.2 KB) 2026-02-11 2026-02-11 pdf NIA Project Registration and PEA Document 2024-10-02 4_42 (61.1 KB) 2024-10-02 2024-10-02 pdf NIA Project Registration and PEA Document 2024-03-29 12_15 (61.2 KB) 2024-03-29 2024-03-29 pdf Download Learnings Outcomes Work Package 1: WP1 aimed to review SP Energy Networks' (SPEN) generation connection policy and provide recommendations for future updates to streamline the connection process. The approach involved benchmarking SPEN's policy against those of other Distribution Network Operators (DNOs) and the EREC G98 and G99 standards, which are essential for integrating distributed generation projects. The output was a gap analysis with proposed recommendations to ensure future policy updates comply with the latest standards and anticipated market changes, making revisions clear and unambiguous for prospective customers. Work Package 2: WP2 involved an international review of community microgrid developments and best practices, focusing on key regulatory developments, technical considerations, and relevant case studies. Despite limited progress in the UK, similar innovation projects were reviewed to extract key learnings. The research primarily concentrated on developments in Spain, the Nordic region, other EU countries, and North America, providing a comprehensive overview of the current landscape and insights for future advancements in community microgrids. Community microgrids require significant upfront costs and require specialised expertise to manage the energy system. The reliance on diesel backup generators can conflict with sustainability goals. Community microgrids also face unique regulatory challenges and/or policy gaps. Work Package 3: WP3 focused on conducting a high-level Cost Benefit Analysis (CBA) for implementing community microgrids on SP Energy Networks' distribution system. The analysis evaluated the financial costs of deploying this innovative solution and highlighted potential benefits, such as avoided network reinforcement costs and reduced carbon emissions. The CBA followed the RIIO-2 Cost Benefit Analysis Guidance from Ofgem, ensuring alignment with best practices. The outputs present a business case for integrating community microgrids into SP Energy Networks' distribution system, serving as a reference for future work. The main financial benefit of implementing microgrids will be avoiding network reinforcement costs in sites, Work Package 3: WP3 focused on conducting a high-level Cost Benefit Analysis (CBA) for implementing community microgrids in the distribution network of SP Energy Networks. Distribution Energy Scenario data was collected for all the distribution substations in network and the available headroom was calculated for each substation from 2025 to 2050. A microgrid is to be installed behind the meter for substations with negative headroom. This microgrid will help avoid network reinforcement costs. With network reinforcement costs of £1M/MVA, a full-scale rollout is projected to deliver discounted cumulative net financial benefits of £242.34 million and net environmental benefits of £28.88 million, resulting in a total net present value (NPV) of £271.22 million by 2050. The study also evaluated alternative deployment levels, including 20%, 40%, 60%, and 80% rollouts. These partial rollouts yield proportionally lower but still significant benefits. For example, a 20% rollout results in a total NPV of £54.24 million, while an 80% rollout achieves an NPV of £216.97 million. Work Package 4: WP4 focused on assessing the feasibility of integrating community microgrids into the distribution network by evaluating technical, operational, financial, and regulatory aspects. It tested microgrid solutions for improving connection lead times and enhancing network reliability and resilience, especially during peak demand and outages. The analysis also considered the potential of microgrids to support the UK's decarbonisation and net zero goals. Additionally, WP4 involved developing and refining rules and mechanisms to optimize grid operations, investigating community engagement models, assessing economic impacts, identifying barriers to large-scale deployment, and defining strategies for commercialisation or business-as-usual implementation. The potential for new learning includes improving coordination, modelling, and planning capabilities across networks to support holistic and timely system development. This project aims to accelerate connection times for renewables and/or demand sites to meet the 2030 target. It will also support the prioritisation of flexible assets in connection queues, increasing network headroom and reducing the time for viable assets to secure connections. Additionally, it seeks to improve the availability of information to consumers, enabling more cost-effective and diverse decarbonisation choices. Lessons Learnt This research project provided several important lessons that can help guide future work in the energy sector, particularly in the areas of low-carbon technologies and community energy. One of the key findings was the importance of addressing connection and queue management challenges early. These issues often slow down progress, so future projects should look at managing the connection queue more actively and aim to connect projects that are ready to go first. This would help make better use of available capacity and avoid unnecessary delays. Another important lesson was the need to keep generation connection policies up to date. As technology, regulations, and customer needs change, policies must be reviewed and adjusted to stay relevant. Standardising the application process and making it easier to understand can help reduce confusion and improve the experience for both customers and network operators. It is also important to clearly communicate any changes so that everyone involved knows what to expect. The project also highlighted a lack of UK-specific guidance on microgrids. To overcome this, the team looked internationally reviewing global standards such as IEEE and IEC and speaking with experts who have experience in community microgrids. This approach proved valuable and showed that even when local information is limited, there are still ways to gather useful insights by learning from others. Energy communities were identified as a promising way to support the energy transition. They can help people take part in local energy projects, support rural and local economies, and reduce energy poverty by allowing energy sharing with nearby households. These communities also add flexibility to the grid and can act as testing grounds for new ideas. Future projects should look at how to support and grow these kinds of community-led efforts. Finally, the research showed that it is possible to plan for the large-scale use of low-carbon technologies without needing major upgrades to the electricity grid. By designing smarter, more flexible systems, future projects can avoid some of the high costs and delays that come with traditional grid reinforcement. This shows that innovation can come not just from new infrastructure, but also from better planning and smarter use of existing systems.
queue原始依据
E1·Office of Gas and Electricity Markets·采集/快照 2026/8/9
英国改革需求侧并网接入流程
英国就需求侧并网接入改革发布征求意见并公布120份回应的汇总，Ofgem据此形成了初步政策思路，但仍明确这不是最终决定。改革针对需求队列规模扩大、部分项目不可行以及缺乏重要项目优先接入机制三类问题，拟在与政府、NESO和网络公司协作下推进。文件还提出以“Curate、Plan、Connect”三大支柱重塑流程，直接影响数据中心等连接项目的排队和接网时序。
E1·China Southern Power Grid Supply Chain Platform·来源发布 2026/8/13
深圳电网智慧能源技术有限公司2026年构网型电化学储能系统技术改造项目（储能系统仿真测试、调试及搬迁配套服务，并网性能试验及人工短路试验，安全评价）专项服务公开招标招标公告
深圳电网智慧能源技术有限公司2026年构网型电化学储能系统技术改造项目（储能系统仿真测试、调试及搬迁配套服务，并网性能试验及人工短路试验，安全评价）专项服务公开招标招标公告（招标编号：CG0900022002369186） 1.招标条件本招标项目深圳电网智慧能源技术有限公司2026年构网型电化学储能系统技术改造项目（储能系统仿真测试、调试及搬迁配套服务，并网性能试验及人工短路试验，安全评价）专项服务公开招标，招标人为深圳电网智慧能源技术有限公司，项目资金来自自筹资金，出资比例为100%，该项目已具备招标条件，现对本项目进行公开招标。2.项目概况和招标范围2.1项目概述：1）构网型电化学储能系统技术改造项目装机规模20MW/40MWh，由4套5MW/10MWh构网型高压直挂储能电池系统组成，主要设备包括：12套储能电池集装箱、4套一二次设备预制舱、4套电抗器、1套一体化电源舱、1套监控预制舱、2套站用箱变、2套接地变及配套设备设施。项目地址位于深圳市。2）项目分为三个标的，其中标的1为储能系统仿真测试、调试及搬迁配套服务，标的2为并网性能试验及人工短路试验，标的3为安全评价。2.2招标范围：构网型电化学储能系统技术改造项目分为三个标的，其中标的1为储能系统仿真测试、调试及搬迁配套服务，服务期为自合同签订之日起至2026年11月20日，主要工作范围包括20MW/40MWh构网型高压直挂储能系统的仿真测试、现场调试、设备搬迁及配套设备、线缆供货、技术支持等；标的2为并网性能试验及人工短路试验，服务期为自合同签订之日起30天内，主要包括20MW/40MWh构网型高压直挂储能系统并网性能试验、人工短路试验的现场勘察、方案编制、现场试验及试验报告等；标的3为安全评价，服务期为自合同签订之日起30天，主要包括20MW/40MWh构网型高压直挂储能系统安全条件和设施论证评价。具体详见技术条件书。2.3招标项目所在地区：深圳市2.4资格审查方式：资格后审2.5招标分类：专项2.6标的清单及分包情况：序号标的名称标包名称预计采购金额（万元）最高投标限价（万元）最大中标数量服务期是否特殊包投标保证金1标的1：储能系统仿真测试、调试及搬迁配套服务储能系统仿真测试、调试及搬迁配套服务493.33493.331自合同签订之日起至2026年11月20日否/2标的2：并网性能试验及短路试验并网性能试验及短路试验1751751自合同签订之日起30天内否3标的3：安全评价安全评价33.1233.121自合同签订之日起30天内否备注：（1）除不受限制的特殊包外，一个投标人在一个标的中最多只能中不超过最大中标包数的标包。2.7其它关键要素（选填）：（1）报价要求：详见附件。（2）结算方式：根据合同约定支付。（3）报价表：详见附件（如有）。3.投标人资格要求3.1通用资格要求通用资格要求序号内容1投标人必须按照南方电网公司要求，在供应链统一服务平台（www.bidding.csg.cn）上完成供应商登记。2中华人民共和国境内注册合法运作的法人，具有独立承担民事责任的能力和独立履行合同的能力；或具有法人授权，且具有独立履行合同的能力的其他组织；或中华人民共和国境内依法登记成立和合法运作的非法人组织。具备有效的营业执照或其他行政主管部门核发的有效登记注册证明。3单位负责人为同一人或者存在控股、管理关系的不同单位，不得同时参加同一标包的投标。4其他不得存在的情形：南方电网公司或公司暂停或取消其投标资格且未解除的。5不接受联合体投标。3.2专用资格要求专用资格要求序号内容关联标的/标包1投标人须提供 2023年 1 月 1 日至本次投标截止日期间类似项目合同复印件作为业绩要求证明（需提供中标通知书或合同扫描件等相关证明材料）。标的1：储能系统仿真测试、调试及搬迁配套服务2投标人须提供 2023年 1 月 1 日至本次投标截止日期间类似项目合同复印件作为业绩要求证明（需提供中标通知书或合同扫描件等相关证明材料）。标的2：并网性能试验及短路试验3投标人需具备承装（修、试）电力设施许可证承试类三级及以上资质。标的2：并网性能试验及短路试验备注：1、如包内存在不同类别的设备材料，投标人须分别满足包内各类别设备材料的商务资格及技术要求方可视为满足此包的资格要求。2、《承装（修、试）电力设施许可证管理办法》（国家发展改革委2025年第30号令）于2025年7月1日起施行，根据《国家能源局关于做好承装（修、试）电力设施许可证换领和延续工作的通知》（国能发资质[2025]44号），自2025年7月1日起，国家能源局资质和信用信息系统为有关持证企业自动换发电子证照，换发后许可证有效期不变。原“三级”自动变更为“二级（110千伏以下）”，作业范围为110千伏及以下；“四级”自动变更为“三级”；“五级”自动变更为“三级（10千伏以下）”，作业范围为10千伏及以下。许可证及换领后许可证延续过渡期为2025年7月1日至12月31日，过渡期内有效期届满的，仍可继续从事承装、承修、承试电力设施活动。4.招标文件获取4.1招标文件获取方式 本招标项目采用电子招标投标方式，根据《电子招标投标办法》规定，投标人应当在招标公告载明的电子招标投标交易平台注册登记，如实递交有关信息，并经电子招标投标交易平台运营机构验证。凡有意参加投标者，在招标文件发售截止时间前通过南方电网公司供应链统一服务平台（www.bidding.csg.cn）完成供应商登记并免费获取电子招标文件，在投标文件递交截止时间前完成供应商数字证书（电子印章）办理、投标文件编制加密及递交。供应商要为数字证书办理预留足够的时间，由于自身原因造成无法投标的，后果由供应商自行承担。电子化投标操作路径如下：获取路径：门户网站->点击供应商登录->选择供应链统一服务平台（新系统）->购标管理；投标路径：门户网站->点击供应商登录->选择供应链统一服务平台（新系统）->投标管理；投标助手下载路径：门户网站->点击供应商登录->选择供应链统一服务平台（新系统）->购标管理-项目参加及文件下载-可下载项目。供应商登记咨询电话：4008100100转1供应链统一服务平台操作咨询电话：4008100100转3数字证书办理咨询电话：400-666-3999电话咨询时间：周一至周五 上午8:30-12:00,下午14:00-17:004.2招标文件获取时间获取开始时间：2026年8月13日18时00分00秒获取结束时间：2026年8月18日18时00分00秒4.3投标人要求澄清招标文件截止时间：2026年8月19日18时00分00秒5.投标文件的递交5.1投标文件递交方式：通过南方电网供应链统一服务平台（www.bidding.csg.cn）递交投标文件。5.2投标文件递交截止时间：2026年9月03日09时00分00秒6.开标时间及地点本项目通过南方电网供应链统一服务平台线上方式开标。6.1开标时间：2026年9月03日09时00分00秒6.2开标地点：供应链统一服务平台（www.bidding.csg.cn）7.发布公告的媒介本次招标公告在“中国招标投标公共服务平台（www.cebpubservice.com）及南方电网公司供应链统一服务平台（www.bidding.csg.cn）”上发布。8.计算机硬件特征码审查要求、违法行为处理8.1计算机硬件特征码审查要求为进一步规范招投标活动，维护公平竞争的市场环境，本项目对投标人在招标文件下载、投标文件制作及上传过程中产生的计算机硬件特征码严格审查。投标人如存在以下任一情形，由评标委员会对其作否决投标处理：（1）与其他投标人下载招标文件的IP地址、投标文件的CPU序列号及硬盘序列号三者同时一致；（2）与其他投标人上传投标文件的IP地址、投标文件的CPU序列号及硬盘序列号三者同时一致；（3）与其他投标人的投标文件网卡MAC地址一致。如采购项目最小独立评审单元（标的/标包/标段）出现上述任一情形，将否决投标人响应该采购项目及同一采购项目后续采购的全部投标文件。如投标文件存在串通投标情形的，将依据南方电网公司相关规定，对相关投标人实施不接受投标处理。8.2串通投标、弄虚作假、行贿等违法行为处理投标人不得相互串通投标或者与招标人串通投标，不得以他人名义投标或者以其他方式弄虚作假骗取中标，不得向招标人或者评标委员会成员行贿谋取中标。请各投标人高度重视投标诚信，对投标文件中存在生产制造能力、服务网点、业绩（含合同、发票）等造假情形，或私下与评标委员会成员进行与投标内容有关的接触（如评标前通过电话、信息和会面等方式询问是否参加评标，请专家在评标中给予关照等）等各类违法违规行为，一经查实，招标人将严格按照国家法律法规及《中国南方电网有限责任公司供应商不良行为处理管理细则》等有关规定进行严肃处理。9.异议及投诉9.1投标人或者其他利害关系人对本项目的招标文件、开标情况、评标结果有异议的，应当在法律规定的时间，以书面形式提出异议。异议文件应当包括下列内容：（1）异议提出人的名称、地址及有效联系方式；（2）异议事项；（3）有效线索和相关证明材料。异议提出人是法人的，异议文件必须由其法定代表人或者授权代表签字并盖章（授权代表同时还需提交授权委托书）；其他组织或自然人提出异议的，异议文件必须由其主要负责人或提出异议人本人签字，并附有效身份证明复印件，由本人提交。异议递交地点：南方电网供应链集团有限公司异议递交方式：邮件异议递交邮箱：zbybyk@csg.cn注：投标人对开标有异议的，在开标结果确认期间内通过南方电网公司供应链统一服务平台（www.bidding.csg.cn）按要求提交。9.2投标人或者其他利害关系人认为本次招标活动不符合法律、法规、规章规定的，可通过供应链统一服务平台（www.bidding.csg.cn)，按以下步骤进入“三公”信箱提交投诉资料：供应链统一服务平台首页→“三公”信箱。投诉主体、时间、形式内容等不符合规定的，将不予受理：（1）投诉人应当是供应链业务活动当事人或其他利害关系人。（2）投诉应当在投诉人知道或者应当知道之日起10日内提出。（3）就资格预审文件、采购文件、开标及评审结果投诉的，应当先在规定时限内，通过公示公告注明的异议渠道向招标人提出异议。（4）投诉应当有明确的请求和必要的证明材料，包括投诉人和被投诉人名称、有效联系方式、投诉事项和相关请求、证明材料等。针对采购项目的投诉，应当附提出异议的证明文件；投诉人是单位的，应当提交单位负责人签字并加盖公章的书面投诉材料；投诉人是个人的，应当附有效身份证明复印件；投诉有关材料是外文的，应当附有中文译本，由翻译机构盖章或者翻译人员签名。（5）投诉人应对反映问题的真实性负责，不得捏造事实、伪造材料或以非法手段取得证明材料进行投诉，一经发现，将按照南方电网公司供应商管理相关制度进行处理。（6）投诉人应保持联系方式畅通，积极配合投诉核查，同一投诉问题请勿重复或多渠道提交。（7）投诉处理人员会严格遵守保密规定，不向无关人员透露知悉信息。9.3异议提出人或投诉人不得以异议投诉为名排挤竞争对手，不得进行虚假、恶意投诉，阻碍招标投标活动的正常进行。经核查发现所提出的异议或投诉存在诬告、故意扰乱招投标秩序等恶意行为，将按照《中国南方电网有限责任公司供应商不良行为处理管理细则》等制度进行处理。10.联系方式招 标 人：深圳电网智慧能源技术有限公司地 址：广东省深圳市联 系 人：任工招标代理机构：南方电网供应链集团有限公司地 址：广东省广州市天河区天河路178号联 系 人：罗工电 话：4008100100转211.公告的其他内容无。12.招标公告附件无。 招标人（或招标代理机构）主要负责人或授权的项目负责人（签名）：马迪马迪 招标人或其招标代理机构名称（盖章）：南方电网供应链集团有限公司【盖章位置】 2026年8月 13日 上一篇：广州电力设计院有限公司2026~2028年质量、环境、职业健康安全、信息安全管理体系、信息安全服务资质监督审核及培训服务招标公告 下一篇：广西电网能源科技有限责任公司2026年第三批服务类公开招标采购项目招标公告
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E1·European Commission Directorate-General for Energy·采集/快照 2026/8/26
European grid capacity, connection queues and anticipatory investment
The EU has one of the most extensive and resilient electricity networks in the world, spanning over 11 million kilometres across its internal market, ensuring that high-quality electricity is delivered to its consumers every day. At the same time, Europe’s power networks are confronted with new and significant challenges such as insufficient grid capacity to meet growing connection requests both on the demand and supply side, delays in project implementation and security threats. European Grids Package The Commission presented the European Grids Package (COM/2025/1005) on 10 December 2025, following the EU Action Plan for Grids adopted in November 2023. It consists of a proposal to revise the TEN-E Regulation and a proposal to accelerate permit granting procedures by amending the Renewable Energy Directive, the Electricity Market Design and the Gas Directive. The process leading to the final package included a call for evidence and an open public consultation between 13 May and 5 August 2025. ©AdobeStock/PictRider Together, the proposals aim to address the key challenges for cross-border energy infrastructure in the EU, focusing on * better coordination at EU level to map and plan the required grids infrastructure * more effective tools for cost-sharing, ensuring projects are funded in a fairer and more equitable way * speeding up and streamlining permitting processes for grids, renewables, storage and recharging stations projects, while ensuring public acceptance and benefit-sharing * making existing infrastructure more efficient, reinforced by new technology, flexibility, and storage capacity * enhancing the resilience and security of our cross-border energy infrastructure The package also includes 2 guidance documents on efficient and timely grid connections and the design of 2-way contracts for difference. Grid connections The increase in demand and deployment of clean energy sources puts strong pressure on network needs. This is evidenced by grid connection queues being present in at least 16 EU countries as of mid-2026, with data pointing to some 120 GW of mature renewable projects including 1.5 million household installations at risk of not getting timely grid access by 2030 ( EMBER, 2026 ). There are multiple root causes leading to emergence of grid connection queues, which are linked to inadequate planning and delays in network development, lack of transparency on available capacity and locational incentives for users, and grid connection procedures not accounting for maturity of the projects requesting the connection. The Guidance on efficient and timely grid connections (C/2025/8473) which provides recommendations and shares good practices that EU countries and national regulatory authorities can apply to address these challenges immediately and make the most efficient use of existing grids. These include applying the ‘first-ready first-served’ principle, transparent maturity criteria for all connection requests, establishing clear project-development milestones with associated penalties for non-compliance, and conducting regular monitoring and cleaning of the connection queues. To support the implementation of the Guidance, the Commission, in cooperation with ACER, ENTSO-E, DSO Entity and involving regulatory authorities, EU countries and other stakeholders, is organising a series of targeted stakeholder workshops covering anticipatory investments, flexible connection agreements and grid connections. The first workshop took place on 15 April 2026 to explore the implementation of flexible connection agreements (FCA) and hybrid energy systems as tools to address grid congestion and accelerate renewable energy integration. The workshop summary and presentations are available online. The Commission proposal to future-proof electricity bills in the EU (COM/2026/600) of July 2026 further clarified the application of grid connection measures in case of network congestion by regulatory authorities. 2-way contracts for difference The Guidance on the design of 2-way contracts for difference (C/2025/8479) which provides guidance to EU countries on how to design 2 way-contracts for difference between a power-generating installation operator and a counterpart, usually a public entity, in a way that supports efficient investments, in light of the existing regulatory framework. It also gives examples of how the design criteria for 2 way-contracts for difference, set out in the Electricity Regulation (EU/2019/943) and Renewable Energy Directive (EU/2023/2413), can be met. Energy Highways The Energy Highways initiative, set out as part of the European Grids package, will address 8 key bottlenecks across Europe which represent the most urgent energy infrastructure needs. By supporting the concrete implementation of projects on the ground, it will enhance overall security of supply, help integrate more renewables into the system and reduce reliance on fossil fuels, thus decreasing energy prices. The Commission will fast-track the Energy Highways with targeted support for the EU countries concerned and the project promoters involved, including leveraging financing and measures to further streamline and accelerate permit-granting processes to help bring the projects to a successful conclusion. The 8 Energy Highways are: * Iberian Peninsula: Electricity interconnections across the Pyreneans to better integrate the Iberian Peninsula (Pyrenean crossing 1 and Pyrenean crossing 2). * Great Sea Interconnector: Ending electricity isolation by connecting electricity between Cyprus and continental Europe. * Harmony Link: Strengthening electricity interconnection of the Baltic States, boosting energy security and energy independence from Russia. * TransBalkan Pipeline: reverse gas flow to increase the resilience of energy supplies in the Balkan region and eastern neighbourhood. * Bornholm Energy Island: Transforming the Baltic Sea into an offshore interconnector hub. * South-East Europe: Improve price stability and energy security in southeastern Europe, including through storage. * SouthH2 Corridor: The South hydrogen corridor involving Tunisia, Italy, Austria and Germany. * Southwest hydrogen corridor: from Portugal to Germany A European Grid Action Plan As part of the European Green Deal, the Commission published a Grid Action Plan (COM/2023/757) in November 2023. It highlighted that electricity consumption in the EU is expected to increase by around 60% by 2030. Our networks therefore have to become more digitalised, decentralised and flexible. With 40% of our distribution grids being over 40 years old, and cross-border transmission capacity due to double by 2030, €584 billion in investments are necessary. The Action Plan identifies concrete and tailor-made actions to help unlock the investment required to get European electricity grids up to speed. It focuses on implementation and swift delivery, so that the actions can make a difference in time to contribute to our 2030 objectives. The Action Plan identifies 7 areas of concrete and tailor-made actions to help unlock the investment required to get European electricity grids up to speed. It focuses on implementation and swift delivery, so that the actions can make a difference in time to contribute to our 2030 objectives. * accelerating the implementation of Projects of Common Interest and developing new projects * improving long-term grid planning for a higher share of renewables and increased electrification * introducing regulatory incentives for forward-looking grid build-out * incentivising a better usage of the grids * improving access to finance * accelerating deployment through faster permitting and public engagement * strengthening grid supply chains * In October 2025, the Commission published a study on network development planning, tariff structures and connection requests for electricity distribution grids that explores best practices and provides key recommendations. Anticipatory investments On 2 June 2025, the Commission presented a Guidance document on anticipatory investments for developing forward-looking electricity networks, replying to actions in both the Grid Action Plan and the Action Plan for Affordable Energy. The document addresses EU countries, national regulatory authorities and transmission and distribution system operators. It offers concrete recommendations on network planning, regulatory scrutiny and costs and incentives to help them create the right conditions so that grid investments reflect future needs, while also ensuring affordability for consumers and the competitiveness of industry. The Commission and ACER organised a stakeholder workshop on 11 March 2026 to advance the implementation of the Guidance. The discussion focused on how to mitigate risks related to anticipatory investments through robust network planning and early stakeholder involvement. See more details in the workshop summary and main conclusions. Related links Press material * 26 January 2026 Energy Highways: Germany and Denmark agree on joint development of the Bornholm Energy Island offshore wind project * 10 December 2025 Commission proposes upgrade of the EU's energy infrastructure to lower bills and boost independence, Questions and answers, Factsheet * 2 June 2025 EU guidance on ensuring electricity grids are fit for the future * 13 May 2025 Commission collects views in preparation of the European Grids Package * 28 November 2023 Commission sets out actions to accelerate the roll-out of electricity grids * Public inclusion toolbox for renewable energy * Study: Study on network development planning, tariff structures and connection requests for electricity distribution grids (October 2025) * Guidance document on anticipatory investments for developing forward-looking electricity networks (C/2025/3291) * EU Action Plan for Grids (COM/2023/757) * Affordable Energy Action Plan (COM/2025/79) * Clean Industrial Deal * Competitiveness Compass for the EU
E1·China Southern Power Grid Supply Chain Platform·来源发布 2026/5/25
深圳供电局公开招标构网型储能租赁服务
深圳供电局有限公司启动2026年构网型电化学储能系统租赁服务框架公开招标，采购40MW/80MWh储能系统租赁及配套设计、调试、运维等服务。招标是为做好2026年电力保障工作，且按照南方电网公司相关要求，需要采用构网型电化学储能系统进行电力保障。项目预计采购金额4970.8万元，要求在2026年8月31日前并网送电，框架有效期至2026年12月31日，实际结算按单价合同据实执行。
受限原始依据
E1·ESB Networks·采集/快照 2026/8/9
爱尔兰发布配电网容量热力图
ESB Networks发布了爱尔兰配电网容量热力图，向用户展示各变电站在不同电压等级下的可用容量，并配套提供2026年7月的XLSX下载。该工具旨在帮助需求侧和发电侧尽早识别可接入点，因为当地新电力接入需求高企，部分区域配网容量受限，且网络加固往往需要数年。资料显示，容量数据基于Q4 2025的站点能力、2024/2025基础负荷及截至Q4 2025的合同和报价，LV连接通常6个月内完成，而需新变压器或开关设备的MV项目通常约2—3年，直接影响客户接入节奏。
E1·Netbeheer Nederland·采集/快照 2026/8/9
荷兰发布电网容量地图，显现接网排队
Netbeheer Nederland开发了全国电网容量地图，用于展示荷兰各地输电容量的余缺和接入空间。由于运输容量需求快速增长，部分地区的大型用电者、组织和工业用户出现了等待接入的排队。该地图为大用户和其他关注者提供接网空间信息，直接影响选址、并网安排和接入节奏。
E2·OpenAlex·来源发布 2025/12/4
在线反馈优化用于次输电网控制
这篇文章提出用在线反馈优化（OFO）来控制次输电网，并给出一个适用于离散输入的新控制器设计。之所以这样做，是因为电力消费增加、可再生能源占比上升，传统运行方式需要在电压、电流约束下实时优化。文中称该方法对应法国一项真实示范网，并从模型失配、约束满足和跟踪性能三个方面分析其鲁棒性，直接指向提高分布式发电接入条件下的网侧调节能力。
constraint原始依据
E1·National Grid Electricity Distribution·采集/快照 2026/8/9
Clipstone变电站接入容量数据更新
Clipstone 33Kv S Stn 的接入容量信息显示，East Midlands 区域该站点的电力供应和发电可用容量分别为 41.43638093 和 6.802541256，连接申请签出情况也已列明。由于站点当前负荷与发电约束分别标为 green 和 red，说明接入条件存在明显差异。数据显示，负荷连接已发出 1 项、容量 20，而负荷和发电获批连接均为 0，后续项目接入将受站点容量和热约束影响。
E2·Fingrid via Google News·来源发布 2025/11/24
芬兰电网为大型工业项目推出条件接入协议
芬兰电网Fingrid为大型工业项目推出新的条件接入协议。该安排面向大型工业项目，说明其电网接入规则作出调整。由于正文只给出标题和摘要摘录，未披露具体条款、适用条件和时间点。对项目方而言，后续接入安排将取决于协议细则和电网执行口径。
restriction原始依据
进展或反证 · 6
E1·European Commission Directorate-General for Energy·采集/快照 2026/8/26
European grid capacity, connection queues and anticipatory investment
The EU has one of the most extensive and resilient electricity networks in the world, spanning over 11 million kilometres across its internal market, ensuring that high-quality electricity is delivered to its consumers every day. At the same time, Europe’s power networks are confronted with new and significant challenges such as insufficient grid capacity to meet growing connection requests both on the demand and supply side, delays in project implementation and security threats. European Grids Package The Commission presented the European Grids Package (COM/2025/1005) on 10 December 2025, following the EU Action Plan for Grids adopted in November 2023. It consists of a proposal to revise the TEN-E Regulation and a proposal to accelerate permit granting procedures by amending the Renewable Energy Directive, the Electricity Market Design and the Gas Directive. The process leading to the final package included a call for evidence and an open public consultation between 13 May and 5 August 2025. ©AdobeStock/PictRider Together, the proposals aim to address the key challenges for cross-border energy infrastructure in the EU, focusing on * better coordination at EU level to map and plan the required grids infrastructure * more effective tools for cost-sharing, ensuring projects are funded in a fairer and more equitable way * speeding up and streamlining permitting processes for grids, renewables, storage and recharging stations projects, while ensuring public acceptance and benefit-sharing * making existing infrastructure more efficient, reinforced by new technology, flexibility, and storage capacity * enhancing the resilience and security of our cross-border energy infrastructure The package also includes 2 guidance documents on efficient and timely grid connections and the design of 2-way contracts for difference. Grid connections The increase in demand and deployment of clean energy sources puts strong pressure on network needs. This is evidenced by grid connection queues being present in at least 16 EU countries as of mid-2026, with data pointing to some 120 GW of mature renewable projects including 1.5 million household installations at risk of not getting timely grid access by 2030 ( EMBER, 2026 ). There are multiple root causes leading to emergence of grid connection queues, which are linked to inadequate planning and delays in network development, lack of transparency on available capacity and locational incentives for users, and grid connection procedures not accounting for maturity of the projects requesting the connection. The Guidance on efficient and timely grid connections (C/2025/8473) which provides recommendations and shares good practices that EU countries and national regulatory authorities can apply to address these challenges immediately and make the most efficient use of existing grids. These include applying the ‘first-ready first-served’ principle, transparent maturity criteria for all connection requests, establishing clear project-development milestones with associated penalties for non-compliance, and conducting regular monitoring and cleaning of the connection queues. To support the implementation of the Guidance, the Commission, in cooperation with ACER, ENTSO-E, DSO Entity and involving regulatory authorities, EU countries and other stakeholders, is organising a series of targeted stakeholder workshops covering anticipatory investments, flexible connection agreements and grid connections. The first workshop took place on 15 April 2026 to explore the implementation of flexible connection agreements (FCA) and hybrid energy systems as tools to address grid congestion and accelerate renewable energy integration. The workshop summary and presentations are available online. The Commission proposal to future-proof electricity bills in the EU (COM/2026/600) of July 2026 further clarified the application of grid connection measures in case of network congestion by regulatory authorities. 2-way contracts for difference The Guidance on the design of 2-way contracts for difference (C/2025/8479) which provides guidance to EU countries on how to design 2 way-contracts for difference between a power-generating installation operator and a counterpart, usually a public entity, in a way that supports efficient investments, in light of the existing regulatory framework. It also gives examples of how the design criteria for 2 way-contracts for difference, set out in the Electricity Regulation (EU/2019/943) and Renewable Energy Directive (EU/2023/2413), can be met. Energy Highways The Energy Highways initiative, set out as part of the European Grids package, will address 8 key bottlenecks across Europe which represent the most urgent energy infrastructure needs. By supporting the concrete implementation of projects on the ground, it will enhance overall security of supply, help integrate more renewables into the system and reduce reliance on fossil fuels, thus decreasing energy prices. The Commission will fast-track the Energy Highways with targeted support for the EU countries concerned and the project promoters involved, including leveraging financing and measures to further streamline and accelerate permit-granting processes to help bring the projects to a successful conclusion. The 8 Energy Highways are: * Iberian Peninsula: Electricity interconnections across the Pyreneans to better integrate the Iberian Peninsula (Pyrenean crossing 1 and Pyrenean crossing 2). * Great Sea Interconnector: Ending electricity isolation by connecting electricity between Cyprus and continental Europe. * Harmony Link: Strengthening electricity interconnection of the Baltic States, boosting energy security and energy independence from Russia. * TransBalkan Pipeline: reverse gas flow to increase the resilience of energy supplies in the Balkan region and eastern neighbourhood. * Bornholm Energy Island: Transforming the Baltic Sea into an offshore interconnector hub. * South-East Europe: Improve price stability and energy security in southeastern Europe, including through storage. * SouthH2 Corridor: The South hydrogen corridor involving Tunisia, Italy, Austria and Germany. * Southwest hydrogen corridor: from Portugal to Germany A European Grid Action Plan As part of the European Green Deal, the Commission published a Grid Action Plan (COM/2023/757) in November 2023. It highlighted that electricity consumption in the EU is expected to increase by around 60% by 2030. Our networks therefore have to become more digitalised, decentralised and flexible. With 40% of our distribution grids being over 40 years old, and cross-border transmission capacity due to double by 2030, €584 billion in investments are necessary. The Action Plan identifies concrete and tailor-made actions to help unlock the investment required to get European electricity grids up to speed. It focuses on implementation and swift delivery, so that the actions can make a difference in time to contribute to our 2030 objectives. The Action Plan identifies 7 areas of concrete and tailor-made actions to help unlock the investment required to get European electricity grids up to speed. It focuses on implementation and swift delivery, so that the actions can make a difference in time to contribute to our 2030 objectives. * accelerating the implementation of Projects of Common Interest and developing new projects * improving long-term grid planning for a higher share of renewables and increased electrification * introducing regulatory incentives for forward-looking grid build-out * incentivising a better usage of the grids * improving access to finance * accelerating deployment through faster permitting and public engagement * strengthening grid supply chains * In October 2025, the Commission published a study on network development planning, tariff structures and connection requests for electricity distribution grids that explores best practices and provides key recommendations. Anticipatory investments On 2 June 2025, the Commission presented a Guidance document on anticipatory investments for developing forward-looking electricity networks, replying to actions in both the Grid Action Plan and the Action Plan for Affordable Energy. The document addresses EU countries, national regulatory authorities and transmission and distribution system operators. It offers concrete recommendations on network planning, regulatory scrutiny and costs and incentives to help them create the right conditions so that grid investments reflect future needs, while also ensuring affordability for consumers and the competitiveness of industry. The Commission and ACER organised a stakeholder workshop on 11 March 2026 to advance the implementation of the Guidance. The discussion focused on how to mitigate risks related to anticipatory investments through robust network planning and early stakeholder involvement. See more details in the workshop summary and main conclusions. Related links Press material * 26 January 2026 Energy Highways: Germany and Denmark agree on joint development of the Bornholm Energy Island offshore wind project * 10 December 2025 Commission proposes upgrade of the EU's energy infrastructure to lower bills and boost independence, Questions and answers, Factsheet * 2 June 2025 EU guidance on ensuring electricity grids are fit for the future * 13 May 2025 Commission collects views in preparation of the European Grids Package * 28 November 2023 Commission sets out actions to accelerate the roll-out of electricity grids * Public inclusion toolbox for renewable energy * Study: Study on network development planning, tariff structures and connection requests for electricity distribution grids (October 2025) * Guidance document on anticipatory investments for developing forward-looking electricity networks (C/2025/3291) * EU Action Plan for Grids (COM/2023/757) * Affordable Energy Action Plan (COM/2025/79) * Clean Industrial Deal * Competitiveness Compass for the EU
reinforcement原始依据
E2·OpenAlex·来源发布 2026/1/1
数据驱动优化控制用于并网变流器
这篇论文提出了面向并网电力变流器的数据驱动最优控制架构DeePConverters。之所以这样做，是因为传统PID通常基于简化模型整定，而实际电网复杂、变化且往往未知，容易带来性能下降甚至不稳定。文中称该方法可隐式感知被测数据中的系统特性，并通过高保真仿真和硬件在环测试验证其有效性，直接指向储能、可再生能源和直流接口等并网场景的控制优化。
connected原始依据
E1·ESB Networks·采集/快照 2026/8/9
爱尔兰发布配电网容量热力图
ESB Networks发布了爱尔兰配电网容量热力图，向用户展示各变电站在不同电压等级下的可用容量，并配套提供2026年7月的XLSX下载。该工具旨在帮助需求侧和发电侧尽早识别可接入点，因为当地新电力接入需求高企，部分区域配网容量受限，且网络加固往往需要数年。资料显示，容量数据基于Q4 2025的站点能力、2024/2025基础负荷及截至Q4 2025的合同和报价，LV连接通常6个月内完成，而需新变压器或开关设备的MV项目通常约2—3年，直接影响客户接入节奏。
E1·Office of Gas and Electricity Markets·采集/快照 2026/8/9
英国改革需求侧并网接入流程
英国就需求侧并网接入改革发布征求意见并公布120份回应的汇总，Ofgem据此形成了初步政策思路，但仍明确这不是最终决定。改革针对需求队列规模扩大、部分项目不可行以及缺乏重要项目优先接入机制三类问题，拟在与政府、NESO和网络公司协作下推进。文件还提出以“Curate、Plan、Connect”三大支柱重塑流程，直接影响数据中心等连接项目的排队和接网时序。
reinforcement原始依据
E1·National Grid Electricity Distribution·采集/快照 2026/8/9
Tuffley 33/11千伏供电容量偏紧
Tuffley 33/11kV站点的用电容量处于偏紧状态，demandAvailableCapacity仅为1.906689167，demandConstraint标记为amber。generationAvailableCapacity为7.501791，generationConstraint为green，表明发电侧余量相对充足。该页面显示已接受1项负荷接入申请、容量1.8，后续负荷接入更受热约束限制。
E1·Energy Networks Association Innovation Portal·采集/快照 2026/8/10
Connected Island
Complete ProjectReferenceNumber: NIA_SPEN_0095 Status: Complete StartDate: 2024-04-01T00:00:00Z EndDate: 2024-12-31T00:00:00Z OwnerNetwork: SP Energy Networks Distribution TechnologyAreas: ["Asset Management","Distributed Generation","Low Carbon Generation"] FundingMechanisms: ["NIA RIIO-2"] StrategyThemes: ["Net zero and the energy system transition"] Connected Island Status: Complete Project Reference Number: NIA_SPEN_0095 STRATEGY THEME: Net zero and the energy system transition START DATE: Apr 2024 END DATE: Dec 2024 Contact Lead Network Project summary Funding Licensee(s): SPEN-D - SP Energy Networks Distribution Funding mechanism: NIA_RIIO-2 Technology: Asset Management Distributed Generation Low Carbon Generation Expenditure: £196,000 Third Party Collaborators: Ricardo Share project Save to my account Summary Learnings Documents This project will support the strategic improvement and evolvement of the planning and connections process to meet net zero in a timely and cost-effective manner. The current connection process has been identified as being over-subscribed, representing a bottleneck. To achieve the Net Zero targets of the country, it is considered necessary to support the development, implementation and connection of low carbon technologies onto the electricity network. This project will be a feasibility study, and would look to investigate, develop and trial new technical and procedural issues associated with connection applications for new developments. It will help maximise potential additional distributed generation on the grid by implementing a "smart island" microgrid for a specified network community. Export and import capacity requirements would be reduced, compared to a standard firm connection. Benefits Merits: Simplifying community connections and reducing the costs and lengthy application windows associated with network reinforcement. Improve queue management and supporting the roll-out of low carbon solutions. The project will enable the prompt introduction of numerous low-carbon technologies at scale within a self-managed network, without the requirement for major grid reinforcement. The connections queue can be efficiently managed to ensure the above benefit can be realised Faster and cheaper network transformation can occur Learnings throughout are captured and used to promote a BaU design and connection application process Benefits - This project will support the business strategy to: Develop a Net-Zero network and support the transition to DSO by enhancing our connections service Transition from service provider to partner by supporting communities achieve Net Zero transition Prepare the business for a sustainable and digital future by supporting the development of Microgrids View Project as PDF Select all Title Date modified Document type NIA_SPEN_0095 Close Down Report 2026-02-11 11_10 (57.2 KB) 2026-02-11 2026-02-11 pdf NIA Project Registration and PEA Document 2024-10-02 4_42 (61.1 KB) 2024-10-02 2024-10-02 pdf NIA Project Registration and PEA Document 2024-03-29 12_15 (61.2 KB) 2024-03-29 2024-03-29 pdf Download Learnings Outcomes Work Package 1: WP1 aimed to review SP Energy Networks' (SPEN) generation connection policy and provide recommendations for future updates to streamline the connection process. The approach involved benchmarking SPEN's policy against those of other Distribution Network Operators (DNOs) and the EREC G98 and G99 standards, which are essential for integrating distributed generation projects. The output was a gap analysis with proposed recommendations to ensure future policy updates comply with the latest standards and anticipated market changes, making revisions clear and unambiguous for prospective customers. Work Package 2: WP2 involved an international review of community microgrid developments and best practices, focusing on key regulatory developments, technical considerations, and relevant case studies. Despite limited progress in the UK, similar innovation projects were reviewed to extract key learnings. The research primarily concentrated on developments in Spain, the Nordic region, other EU countries, and North America, providing a comprehensive overview of the current landscape and insights for future advancements in community microgrids. Community microgrids require significant upfront costs and require specialised expertise to manage the energy system. The reliance on diesel backup generators can conflict with sustainability goals. Community microgrids also face unique regulatory challenges and/or policy gaps. Work Package 3: WP3 focused on conducting a high-level Cost Benefit Analysis (CBA) for implementing community microgrids on SP Energy Networks' distribution system. The analysis evaluated the financial costs of deploying this innovative solution and highlighted potential benefits, such as avoided network reinforcement costs and reduced carbon emissions. The CBA followed the RIIO-2 Cost Benefit Analysis Guidance from Ofgem, ensuring alignment with best practices. The outputs present a business case for integrating community microgrids into SP Energy Networks' distribution system, serving as a reference for future work. The main financial benefit of implementing microgrids will be avoiding network reinforcement costs in sites, Work Package 3: WP3 focused on conducting a high-level Cost Benefit Analysis (CBA) for implementing community microgrids in the distribution network of SP Energy Networks. Distribution Energy Scenario data was collected for all the distribution substations in network and the available headroom was calculated for each substation from 2025 to 2050. A microgrid is to be installed behind the meter for substations with negative headroom. This microgrid will help avoid network reinforcement costs. With network reinforcement costs of £1M/MVA, a full-scale rollout is projected to deliver discounted cumulative net financial benefits of £242.34 million and net environmental benefits of £28.88 million, resulting in a total net present value (NPV) of £271.22 million by 2050. The study also evaluated alternative deployment levels, including 20%, 40%, 60%, and 80% rollouts. These partial rollouts yield proportionally lower but still significant benefits. For example, a 20% rollout results in a total NPV of £54.24 million, while an 80% rollout achieves an NPV of £216.97 million. Work Package 4: WP4 focused on assessing the feasibility of integrating community microgrids into the distribution network by evaluating technical, operational, financial, and regulatory aspects. It tested microgrid solutions for improving connection lead times and enhancing network reliability and resilience, especially during peak demand and outages. The analysis also considered the potential of microgrids to support the UK's decarbonisation and net zero goals. Additionally, WP4 involved developing and refining rules and mechanisms to optimize grid operations, investigating community engagement models, assessing economic impacts, identifying barriers to large-scale deployment, and defining strategies for commercialisation or business-as-usual implementation. The potential for new learning includes improving coordination, modelling, and planning capabilities across networks to support holistic and timely system development. This project aims to accelerate connection times for renewables and/or demand sites to meet the 2030 target. It will also support the prioritisation of flexible assets in connection queues, increasing network headroom and reducing the time for viable assets to secure connections. Additionally, it seeks to improve the availability of information to consumers, enabling more cost-effective and diverse decarbonisation choices. Lessons Learnt This research project provided several important lessons that can help guide future work in the energy sector, particularly in the areas of low-carbon technologies and community energy. One of the key findings was the importance of addressing connection and queue management challenges early. These issues often slow down progress, so future projects should look at managing the connection queue more actively and aim to connect projects that are ready to go first. This would help make better use of available capacity and avoid unnecessary delays. Another important lesson was the need to keep generation connection policies up to date. As technology, regulations, and customer needs change, policies must be reviewed and adjusted to stay relevant. Standardising the application process and making it easier to understand can help reduce confusion and improve the experience for both customers and network operators. It is also important to clearly communicate any changes so that everyone involved knows what to expect. The project also highlighted a lack of UK-specific guidance on microgrids. To overcome this, the team looked internationally reviewing global standards such as IEEE and IEC and speaking with experts who have experience in community microgrids. This approach proved valuable and showed that even when local information is limited, there are still ways to gather useful insights by learning from others. Energy communities were identified as a promising way to support the energy transition. They can help people take part in local energy projects, support rural and local economies, and reduce energy poverty by allowing energy sharing with nearby households. These communities also add flexibility to the grid and can act as testing grounds for new ideas. Future projects should look at how to support and grow these kinds of community-led efforts. Finally, the research showed that it is possible to plan for the large-scale use of low-carbon technologies without needing major upgrades to the electricity grid. By designing smarter, more flexible systems, future projects can avoid some of the high costs and delays that come with traditional grid reinforcement. This shows that innovation can come not just from new infrastructure, but also from better planning and smarter use of existing systems.