在友商行动域识别 38 个独立变化证据单元，覆盖 46 条原始记录，来自 6 个独立发布机构、3 个地区；最大证据组来自 Energy Networks Association Innovation Portal，覆盖 7 条原始记录；找到 0 个可直接比较的反证或进展。
南方电网储能股份有限公司四项科研招标中标结果已公布，分别涉及锂离子电池储能电站消防系统有效性评价试验平台、铁铬液流电池寿命预测、构网型储能支撑能力在线评估装置和钠离子电池储能系统样簇及火灾危险性评价系统。此次结果对应消防评价、寿命预测、支撑能力评估和安全试制等研究方向，反映出储能系统安全与性能评估需求在同步推进。公告于2026年07月29日发布，4个标的分别由安徽科盾新能安防科技有限公司、天津大学、武汉启亦电气有限公司和杭州煦达新能源科技有限公司中标，后续取决于中标人按要求办理通知书和项目实施进度。
深圳供电局有限公司2026年创新项目服务专项公开招标中，标的10“配网电缆宽频阻抗谱在线监测与潜伏性缺陷实时定位关键技术研究开发服务”被终止。原因是招标人要求该标的技术规范书需进一步完善，因此暂停采购流程。公告称后续事宜请留意南方电网供应链统一服务平台相关公告，投标人需据此跟进项目进展。
南方电网科学研究院有限责任公司“构网型变流器涉网性能测试评价理论体系研究”采购已定标，成交人为华南理工大学。该项目说明南网科研院正在推进构网型变流器涉网性能测试评价的理论体系研究，采购结果用于落实相关研究任务。公告仅披露成交结果与领取成交通知书方式，未给出采购金额和研究周期，后续进展取决于研究成果交付和评审落实。
南网科研院构网型变流器涉网性能测试评价理论体系研究成交候选人已公示，华南理工大学以103万元列为第一成交候选人。公示期为2026-07-21至2026-07-24，项目进入异议受理阶段。该研究聚焦构网型变流器的涉网性能测试评价，后续将影响相关测试评价方法和采购执行结果。
南网储能科研院锂离子电池储能电站消防系统有效性评价试验平台、铁铬液流电池寿命预测关键技术、构网型储能支撑能力在线评估装置和钠离子电池储能系统样簇及火灾危险性评价系统试制四项公开招标项目，已于2026年07月09日至07月13日公示中标候选人。项目聚焦储能消防、寿命预测和构网型支撑评估，说明招标重点在于提升不同储能技术的安全性、可靠性和并网支撑能力。四个标的中标报价分别为305万元、231万元、176.4万元和67.9万元，投标人均“符合、满足、满足”，后续将进入异议处理和合同落实阶段。
深圳供电局有限公司2026年创新项目服务专项公开招标中标候选人于2026年7月17日至7月20日公示，涉及车载移动式构网储能、配电网电压柔性控制、人形机器人、电量预测和电压暂降防治等9个标的。此次公示反映出配电网创新研发需求集中在储能并离网切换、柔性控制和配电自动化，招标结果将进入异议期后再推进后续采购。各标的候选人报价从车载移动式构网储能系统的253.3万元到敏感负荷定制化快速接入与切换装置的33.8985万元不等，相关中标候选人资格、质量和工期要求均为“符合”“满足”，直接影响后续研发和试制推进节奏。
深圳供电局有限公司2026年构网型电化学储能系统租赁服务框架公开招标已定标，深圳电网智慧能源技术有限公司中标。公告仅披露中标结果和后续下载中标通知书的安排，未给出租赁规模、期限和技术参数。由于信息主要是招标结果，市场主体目前只能据此确认项目承接方，无法据此判断项目投资额和运行影响。
深圳供电局有限公司2026年构网型电化学储能系统租赁服务框架公开招标中标候选人已公示，中标候选人为深圳电网智慧能源技术有限公司，报价4920万元。公示显示，这是对构网型储能租赁服务的框架采购，反映深圳供电局对该类储能系统服务的持续需求。该项目资格能力条件为“满足”，工期/交货期为“满足”，对后续合同落地和服务执行提出了明确要求。
南网储能公司构网型铁铬液流电池储能系统集成研究技术服务公开谈判采购项目已定标，江苏朗雄能源科技有限公司成为成交供应商。公告未披露研究服务的具体内容和技术指标，仅明确采购结果与后续通知书下载安排。该结果于2026年05月11日发布，直接影响相关研究服务合同落地与后续项目推进节奏。
南网储能公司构网型铁铬液流电池储能系统集成研究技术服务公开谈判采购项目已确定成交供应商，江苏朗雄能源科技有限公司中标。公告未披露采购金额和技术成果，当前信息主要反映该研究服务采购完成，后续取决于成交通知书下载和合同执行。该项目采购编号为CG0200062002278409，公告日期为2026年05月11日，对应供应商需在发布之日起3个工作日内登录平台办理，显示项目进入落地阶段。
南网储能公司构网型铁铬液流电池储能系统集成研究技术服务公开谈判采购项目已公示成交候选人，江苏朗雄能源科技有限公司列第一。此次为公开谈判采购，项目聚焦构网型铁铬液流电池储能系统集成研究，说明相关技术服务进入采购落地阶段。公示期为2026年4月10日至4月13日，响应报价4999.66万元，资格、质量和工期要求均为满足。
海南电网能源发展有限公司就2026年二次设备微电网系统专项项目发布直接采购公示，采购金额为331.65万元，交货期为合同签订后30天内。之所以采用单一来源，是因为该项目源于海南商业航天发射场（二期）应急电力保障系统（EPC）需求，且业主要求按事故抢修模式启动紧急采购。公示还明确实行单价最高限价、按成交单价结算，并要求供应商不得使用美光公司产品，直接影响后续报价有效性和供货资格。
广州供电局2025年科技项目（第三十二批）中标结果已公告，涉及电力作业机器人、“光储直柔”智能微电网控保协同、直流互联多台区容量互济、配网巡检设备和充电桩接入体验优化等多个课题。由于项目覆盖配网运维、微电网控制和电动汽车接入等场景，反映出广州供电局正推进相关技术研发与应用验证。公告列出多个中标单位及标的，如“光储直柔”智能微电网控保协同策略研究、基于直流智能互联的多台区容量互济装置研究和虚拟电厂参与电力市场交易的关键技术研究，直接影响后续技术开发、设备试制和软件试制推进。
广州供电局2025年科技项目（第三十二批）多项课题中标候选人已公示，涵盖光储直柔微电网控保、直流互联多台区互济、配网巡检和充电桩接入优化等方向。公示对应广州供电局科技研发需求，旨在推进微电网控制保护、配网运维和充电场景接入等应用研究。公示列出23个标的中的多数中标候选人及报价，例如“光储直柔”控保协同策略研究技术开发147.73万元、设备试制93.6万元，直接影响后续研发与试制推进节奏。
深圳供电局有限公司2025年创新项目中，构网型储能变流器测试化验加工服务完成公开招标并公布中标结果，同时配套的高价值专利培育知识产权辅导服务也已定标。此次招标属于深圳供电局2025年创新项目服务采购，正文未说明项目建设规模和技术参数，只披露了服务类标的的中标人。中标信息显示，构网型储能变流器测试化验加工服务由许昌开普检测研究院股份有限公司中标，相关测试服务的落地进度因此明确。
广州供电局2025年科技项目（第三十二批）中标候选人已公示，涉及光储直柔微电网控保、直流互联多台区互济、配网巡检和充电桩接入体验优化等23个标的。公示显示，这批项目主要围绕配电网智能化、微电网控制保护和新型用电场景优化展开，反映出电网侧对技术研究和设备试制的集中采购需求。其中特别披露了多项中标候选人及报价，如“光储直柔”智能微电网控保协同策略研究技术开发147.73万元、设备试制93.6万元，相关单位后续需按公示和招标要求完成异议处理及项目实施。
深圳供电局有限公司2026年创新项目服务专项公开招标中标结果已公布，涉及车载移动式构网储能、配电网电压柔性控制、配电设备透明化和电量预测等9个标的。此次招标覆盖并/离网无感切换、储能型DVR电压暂降防治、敏感负荷快速接入等方向，反映出配电网对灵活控制和现场应用技术的需求。公告显示，9个标的分别由深圳市大为弘德汽车工业有限公司、西安爱科赛博电气股份有限公司等企业中标，后续取决于项目研发、研试制和示范应用推进进度。
2026年上半年，中国新型储能招标和中标市场保持增长，招标1987个、同比增41.8%，中标1504个、同比增61.0%，EPC项目增速明显快于单独储能设备采购。推动这一变化的是项目采购继续向总包化和长时储能倾斜，EPC招标与中标量均翻倍，集中采购和框架协议也成为常态。期内储能招标功率24.5GW、同比降3.4%，但容量148.1GWh、同比增88.3%；2小时储能平均中标价602.1元/千瓦时、4小时为541.3元/千瓦时，4小时系统单价更低且采购向少数供应商集中。
Live ProjectReferenceNumber: NIA_NPG_018 Status: Live StartDate: 2017-09-01T00:00:00Z EndDate: 2020-09-01T00:00:00Z OwnerNetwork: Northern Powergrid TechnologyAreas: ["Environmental"] FundingMechanisms: ["Network Innovation Allowance"] StrategyThemes: [] Microresilience Status: Live Project Reference Number: NIA_NPG_018 START DATE: Sep 2017 END DATE: Sep 2020 Contact Lead Network Project summary Funding mechanism: Network Innovation Allowance Technology: Environmental Expenditure: £1,700,000 Third Party Collaborators: Smarter Grid Solutions LCP Delta Share project Save to my account Summary Learnings Documents Significant advances have been made in restoration of supplies by smart methods over recent years, in particular very short term restoration which is considered to be an increase in resilience. Conversely smart techniques have contributed less to increases in true resilience; situations when customers never experience an outage of any length in the first place. In the near future however improvements and cost reductions in battery technology, the prevalence of distributed generation particularly at lower voltages, and improvements in measurement and communications will offer smart opportunities to improve resilience. This would seem to be a potential low-cost route to improved true resilience but which mix of technology options, operational approaches would suit particular circumstances and locations is not known and the residual risk and actual deliverable benefit is not understood. Objectives The project will assess the technical viability and comparative economics (including non-financial benefits) of smart technology enabled resilience under the following circumstances: Critical customers on vulnerable connection Remote customers on vulnerable connection Opportune micro-grid application (using already present DG) Simple storage option The project intends to provide guidance for the appropriateness of the various solutions tested and their technical benefits and disadvantages. The level of resilience improvement will be assessed alongside the level desired by the customers. Critical customers on a vulnerable connection may have different requirements to a microgrid implementation with a significant degree of embedded generation. View Project as PDF Select all Title Date modified Document type NIA_NPG_018 Annual Progress Report (5) 2026-06-15 1_44 (35.2 KB) 2026-06-15 2026-06-15 pdf NIA_NPG_018 Annual Progress Report (4) 2025-07-21 3_04 (35.5 KB) 2025-07-21 2025-07-21 pdf NIA_NPG_018 Annual Progress Report (3) 2024-07-23 7_51 (35.5 KB) 2024-07-23 2024-07-23 pdf NIA Project Registration and PEA Document_Microresilience NPG_NIA_018.pdf (209.4 KB) 2024-02-22 2024-02-22 pdf Customer Impact Dashboard.pdf (128.3 KB) 2024-02-22 2024-02-22 pdf NIA_NPG_018 Annual Progress Report (2) 2023-07-31 9_33 (35.6 KB) 2023-07-31 2023-07-31 pdf NIA_NPG_018 Annual Progress Report (1) 2022-07-30 10_22 (34.1 KB) 2022-07-30 2022-07-30 pdf NIA_NPG_018 Annual Progress Report 2021-07-27 2_55 (62.0 KB) 2021-07-27 2021-07-27 pdf NIA Project Registration and PEA Document (83.5 KB) 2021-03-25 2021-03-25 pdf NIA_NPG_018 (03-08-2017 11-06-50) (39.4 KB) pdf NIA_NPG_018 (14-02-2018 08-32-25) (46.9 KB) pdf NIA_NPG_018 (21-02-2018 12-20-26) (46.9 KB) pdf NIA_NPG_018 (30-07-2018 13-33-11) (26.3 KB) pdf NIA_NPG_018 (30-07-2019 14-39-21) (26.8 KB) pdf NIA_NPG_018 (31-07-2020 12-36-10) (30.4 KB) pdf project-difference (08-04-2021 15-23-27) (8.4 KB) xlsx Download Learnings Outcomes Outcomes and findings will be covered comprehensively in the closedown reports scheduled for completion and release in Q3 2026. Lessons Learnt During the hiatus of the recent pandemic additional effort was channelled into the interoperability of the microgrid control interface. Legacy storage systems were difficult to support regarding software and firmware updates. Research during this phase found a distinct lack of sub 1MW storage systems available in the UK, with several vendors tending to prefer the larger 5MW systems. Existing energy markets are well established regarding this level of capacity with existing ROI’s being met through the grid frequency support mechanism. As DNO’s begin the transition towards DSO’s there will be additional focus on smaller domestic, SME/I and C energy storage levels. These DER’s will form the basis of a new emerging market focused on local resilience and featuring peer to peer trading.
As the Philippines moves toward decentralised energy systems, microgrids play a critical role in achieving full household electrification by 2028 and meeting national energy security goals. This RfQ seeks a supplier to assist the Department of Energy (DOE) in addressing key data and planning gaps that hinder the development and financing of renewable microgrids. The intervention will support the creation of a targeted, site-specific data collection framework and conduct field data gathering across 8-10 priority sites. The supplier will work closely with DOE to develop pre-feasibility studies, assess energy demand and site conditions, and identify viable and high-risk locations. Findings will inform DOE's microgrid auction strategy and support inclusive, evidence-based planning for rural electrification. noticeIdentifier: UKPACT_ED08 noticeType: Contract noticeStatus: Awarded organisationName: PALLADIUM INTERNATIONAL LIMITED awardedSupplier: Trama TecnoAmbiental SL awardedValue: 185854 awardedDate: 2025-09-16T00:00:00+01:00 valueLow: 186000 valueHigh: 0 start: 2025-08-18T00:00:00+01:00 end: 2026-04-30T00:00:00+01:00 cpvDescription: Energy and related services cpvCodes: 71314000 region: Philippines
The Municipality of Carloforte, on the island of San Pietro in south‑western Sardinia, is continuing to turn its clean energy ambitions into concrete action, with a growing focus on one of the most strategic and challenging areas for island communities: ports and maritime transport. The latest step in this process is the installation of a photovoltaic carport in the port area, marking another milestone in the island’s long‑term transition towards a more resilient and lower‑carbon energy system. Developed within the NRRP‑funded RAISE “Hinspiration” research project, the new infrastructure combines a 20 kW photovoltaic system, a 10 kWh battery storage unit and a smart monitoring platform designed to simulate smart‑grid behaviour, including interaction with storage and virtual hydrogen generation. With a total investment of more than €355,000, the system will also supply a dedicated electric charging point of around 10 kW for port‑related vehicles, while contributing renewable electricity to local port uses such as public lighting. Ports are vital infrastructures for islands such as San Pietro, which is home to just under 6,000 inhabitants across an area of 51 km² and depends heavily on maritime connections for mobility, goods and services. At the same time, ports concentrate significant energy demand and emissions. Decarbonising these hubs is therefore not only a technical challenge but a key lever for strengthening territorial resilience, reducing dependence on imported energy and improving local environmental performance. In parallel with the photovoltaic installation, the Municipality of Carloforte has recently completed the assignment for the design of a new shore‑side electricity supply system for the port quay. Financed through a €500,000 contribution from the Sardinia Region, the project foresees the installation of five 150 kW electricity supply columns to allow ferries to connect to onshore power while docked, replacing the current equipment. The design phase is now underway, with completion expected by 2028. These investments are closely linked to the wider strategic reflection taking place on the island. In 2025, Carloforte hosted the Clean energy for EU islands workshop “Sustainable marine transport and the role of ports in decarbonising energy systems”, organised within the framework of the Clean energy for EU islands initiative. The event provided a dedicated forum for local authorities, experts and stakeholders to discuss how island ports can evolve from energy‑intensive infrastructures into active enablers of the clean energy transition. Discussions focused on sustainable maritime transport, electrification solutions, system integration and the role of ports within broader island energy systems. More broadly, San Pietro has been supported by the Clean energy for EU islands initiative and its italian regional partner Politecnico di Torino, for several years, including the development of its Clean Energy Transition Agenda. While the island already produces part of its electricity from renewable sources — mainly photovoltaic installations on public and private rooftops, including a 1 MW system — most electricity is still imported from the mainland via undersea cables. This makes continued investment in local generation, storage and system flexibility particularly relevant. The recent progress in the port of Carloforte shows how this strategic framework is being translated into practice. By combining renewable electricity production, battery storage, electric mobility and future shore‑side power supply, the island is demonstrating how clean energy planning can be implemented step by step, even in sensitive and complex areas such as ports. The experience of San Pietro underlines an important lesson for other European islands: the clean energy transition is not achieved through a single technology or project, but through a coherent mix of local commitment, technical planning, public investment and European support, turning long‑term visions into tangible improvements for essential island services. Photographer: Francesco Rosso Country Italy
Publication Date 10 April 2026 Language ENGLISH (EN) Report type Technical assistance report Islands Cres & Lošinj Country Croatia Clean energy theme Energy communities Planning and strategy This study presents an assessment of the potential role of a BESS (battery storage system) in selected households with installed PV systems operating under the self-consumption schemes, as well as within a new REC, considering the current transition from the net metering to the billing scheme. In this sense, an assessment of the effectiveness of the current (and potential future) installed PV and BESS capacity to maximise self-consumption and energy community revenues has been performed, using a modelling approach proposed by the Secretariat technical team and targeting a suitable techno-economic viability to: Validate whether, under the new Croatian self-consumption remuneration approach (based on net-billing), the maximisation of RES self-consumption through BESS integration is viable. Evaluate the potential increase of the installed PV as well as the possibility of BESS installation to make self-consumption more effective and potentially offer, through REC storage, flexibility opportunities for the whole island electric system. Document TA_Phase III_Assessment of the viable scenarios for deploying BESS within Renewable Energy Communities in Cres IslandEnglish(1.84 MB - PDF)Download
Publication Date 11 March 2026 Language ENGLISH (EN) Publishing Organisation and Month/Year Clean energy for EU islands secretariat 03/26 Report type Technical assistance report Islands Pantelleria Country Italy Clean energy theme Financing renewable energy projects Renewable energy This report presents the financial assessment of PV and BESS configurations for the airport site, complementing a previously delivered technical study (January 2025) for the island of Pantelleria. The goal is to determine the most financially viable investment scenarios for various stakeholders, including private investors, the Regulatory Authority, and the Distribution System Operator (DSO). A dedicated financial model assessed each scenario over a 20-year horizon, incorporating CAPEX, OPEX, depreciation, feed-in tariffs, avoided diesel costs, financing conditions, and inflation. For PV, production degradation and curtailment were modelled; for BESS, round-trip efficiency, capacity fade, and cycling limits were considered. The results suggest that, for private investors, a PV-only plant at Pantelleria Airport is the most viable choice under current conditions. For the public sector or regulated investment, a grant-funded BESS project without replacement offers the highest return — provided long-term operational performance is assured. The possibility of considering the BESS plant as a regulated asset, for which the DSO can receive amortisation of the investment and return on capital, also ensures significant savings, without requiring direct public investments. Continuous model updates and technical monitoring are essential to adapt to changing market, policy, and technological conditions. Document TA_Phase III_Hybrid PV and storage plant in Pantelleria Airport – Financial AssessmentEnglish(872.68 KB - PDF)DownloadOther languages (1)Italian(908.67 KB - PDF)Download
4. Ensuring safety 4.1 Introduction to battery safety risks 4.2 Grid-scale batteries 4.3 Domestic batteries 4.4 Community batteries 5.1 Australia 5.2 Europe 5.3 UK Lithium-ion batteries have become part of everyday life, from phones and laptops through e-bikes and electric cars to the standalone home and community storage units on which this document focuses. For most people, use of lithium-ion batteries is without incident, but they do carry a risk of fire, particularly if improperly built or installed. That risk does not mean that batteries cannot be used safely – after all, most UK homes contain gas boilers, which similarly pose significant risks if poorly installed or maintained – but does mean that, as for gas boilers, it is important that safety is taken seriously, particularly in design and installation. This section provides an overview of the inherent safety risks associated with battery technologies and the existing regulatory and standards frameworks that apply across domestic and grid‑scale storage. We are seeking views on whether these frameworks remain appropriate and proportionate for community batteries as deployment increases, and whether any gaps in standards, responsibilities, or risk management need to be addressed. Like many modern appliances, from boilers to mobile phones, the components used in batteries have the potential to cause harm, and so it is important that in their manufacture, installation and use, consideration is given as to how most effectively to mitigate that harm. Domestic and grid-scale batteries mainly use lithium‑ion chemistries, with some sodium‑ion systems emerging. Lithium‑ion and sodium‑ion cells hold large amounts of chemical energy in a compact structure. Cells are packaged into modules and packs, controlled by a Battery Management System (BMS) to keep voltage, temperature, and current within safe limits. This energy is normally stable as long as the separator keeps electrodes apart and the BMS regulates charging and temperature. Fire incidents involving lithium‑ion batteries used in mobile applications - such as e‑bikes and e‑scooters, particularly when unlawfully retrofitted - have been documented. However, there is no evidence to suggest that fire incidents involving professionally installed domestic battery storage systems are a common occurrence. These systems are substantial, stationary units that are subject to established regulatory requirements and technical standards that apply to battery manufacture, installation, and operation. Nevertheless, risks may arise where systems are not correctly installed. Community batteries are expected to meet the same baseline safety expectations as other energy storage assets. The overview below therefore provides context for considering whether existing frameworks remain appropriate and proportionate as the sector grows. This document focuses on community batteries, but it is contextually useful to outline the safety regime that exists for larger batteries connected directly to transmission and distribution networks. While fires have occurred at battery sites in Great Britain, they are rare. Fires at grid-scale battery sites are less frequent than those at non-domestic buildings from all sources. The latest available 5-year annual average fire incidence rate for grid-scale batteries is 0.7% (2020/21 to 2024/25),[footnote 11] lower than non-domestic building fires in England at 0.8% (2020/21 to 2024/25).[footnote 12] This risk is mitigated by a robust regulatory framework overseen by the Health and Safety Executive (HSE). This framework requires responsible parties to take measures to ensure health and safety throughout all stages of a battery system’s deployment. It is important that those involved in the deployment of BESS sites are aware of their legal duties. HSE supports this with guidance on its website. Where health and safety standards are concerned, best practice is reflected in common international standards such as National Fire Protection Association’s NFPA 855 Standard for the Installation of Stationary Energy Storage Systems , as well as Underwriters Laboratories’ UL9540A Test Method for Battery Energy Storage Systems (BESS) which is the critical test method for thermal runaway propagation. American standards, such as those developed by NFPA and UL, are normally applied to BESS projects in the UK as there are no currently developed UK or EU equivalent standards. These American standards are recognised globally and the UK insurance industry typically mandates them as a requirement of its insurance agreements. The government works closely with the Electricity Storage Health and Safety Governance Group, whose members include the Health and Safety Executive (HSE), National Fire Chiefs Council, and the Environment Agency. The Governance Group is responsible for ensuring that an appropriate, robust and future-proofed health and safety framework is sustained. As part of this work, the Group has developed and published health and safety guidance for grid-scale batteries. The guidance aims to improve the navigability of existing standards and provide a clearer understanding of relevant H&S standards. The government, through the industry-led Electricity Storage Health and Safety Governance Group, will continue to monitor the sector closely. In August 2025, DEFRA launched a consultation on including grid-scale batteries within the Environmental Permitting Regulations, to provide further safeguards and assurance. DEFRA is currently analysing feedback to this consultation and will publish a government response in due course. For domestic battery storage systems, as with any electrical appliance, there is an inherent risk of fire which cannot be completely eliminated. As for other household appliances, government sets safety standards, but individuals and property owners are best placed to make informed decisions about installation and use, supported by certified installers, product information and the specific characteristics of their property. A range of UK regulations and standards significantly reduce risk and ensure safe installation and operation: In addition to the regulatory and standards framework set out above, the government previously commissioned a detailed review of the safety risks associated with domestic lithium-ion battery energy storage systems in 2020. This review, carried out for the Office for Product Safety and Standards (OPSS) and the then Department for Business, Energy & Industrial Strategy (BEIS), examined the operation of domestic battery systems, known incident data, potential failure modes (including thermal runaway), and the effectiveness of existing and emerging mitigation measures. The review also provides an overview of relevant safety standards and codes of practice. Community batteries differ significantly from domestic batteries, in size, location and ownership. They typically have higher total power, energy capacity and voltage, serve multiple households or businesses, and may be installed in shared or public spaces where access and emergency planning needs careful thought. They can also involve varied ownership and maintenance models, which means responsibilities for ongoing safety checks must be clear. While these characteristics do not in themselves indicate a higher level of risk, they do create a different risk profile compared to domestic batteries and raise important questions about whether standards designed for small-scale, single-property installations are sufficient for community-scale projects. For example, PAS 63100 excludes dwellings over 200 m², and MIS 3012 only applies to systems below 50kW. We have identified community batteries in the UK that fall outside the scope of both standards. We want to understand what gaps exist, whether these gaps pose any risks, and what additional measures might be needed. Current and prospective community battery users, as well as relevant local authorities (including fire services), are invited to share views on the following: As noted, community battery projects are already operating in the UK, and we are keen to highlight some examples. Similar initiatives are emerging internationally, particularly in Australia, offering valuable lessons for UK. We are keen to share these insights while also learning from projects developed here at home. One prominent example is Australia’s ‘Community Batteries for Household Solar’ programme, supported by A$200m in federal funding. This initiative aims to deploy around 400 community battery systems nationwide, enabling communities to store excess rooftop solar energy and access affordable power. The programme has attracted significant attention. In June 2024, the Australian Renewable Energy Agency’s (ARENA) awarded A$124.7m in Round 1 to fund 318 batteries ranging from 50kW to 5MW. The application round for Round 2, offering A$46.3m, closed in September 2025. The Department of Industry, Science and Resources is separately administering A$29m of the available grant funding.[footnote 14] This approach has been particularly effective in Australia because high levels of domestic solar generation means that distribution networks are often constrained by excess daytime exports, as large volumes of surplus solar generation flow back into the grid simultaneously. This can lead to grid congestion and force distribution network operators to impose export limits. Community batteries are therefore strategically installed within local distribution networks to store surplus solar energy generated during the day before it reaches the wider grid and release it during peak demand periods. This model benefits both solar and non-solar households: participants can rent storage capacity, earn credits for stored energy, and enjoy lower bills. However, like all retrofit virtual private networks, consumers must switch to a specific supplier to benefit. While uptake has been strong in engaged suburban areas, there have been some challenges in onboarding more vulnerable households. We are keen to explore whether this model, or similar approaches, could be adapted for the UK to deliver benefits such as bill savings for low-income households. PowerBank Community Battery pilot, Western Australia – type 3 virtual private network[footnote 15] Context: PowerBank was a joint pilot by Synergy and Western Power exploring the potential of community‑scale batteries to support Western Australia’s South West Interconnected System (SWIS). Delivered across 12 metropolitan and regional locations, it was the first pilot in Australia to integrate a utility‑scale battery into an existing major metropolitan electricity network for the purpose of providing virtual storage to individual customers. The project aimed to test both the technical value of neighbourhood-embedded batteries and the commercial feasibility of offering household customers access to shared storage without the upfront cost of a home battery. There were three phases of the project: PowerBank (Meadow Springs), PowerBank2 (Falcon and Ellenbrook), and PowerBank3 (additional sites including Kalgoorlie, Vasse, Canning Vale and others). Technical set-up: each PowerBank installation consisted of a grid‑connected community battery operated by Western Power and integrated within the local distribution network. Customers with rooftop solar were able to virtually store excess solar generation produced between 7am and 3pm in the battery. Depending on the subscription selected, participants could use up to 6kWh or 8kWh of stored energy per day to offset consumption during periods when their own solar was not generating. The system provided no physical behind‑the‑meter flow of energy; instead, storage and discharge were modelled virtually through retail billing mechanisms. The batteries provided local network benefits by absorbing excess solar export during the day and smoothing power flows in areas with increasing rooftop PV penetration. Economics: across all three phases of the PowerBank pilot, 533 participants engaged in the virtual community battery scheme over a period of 3 years and 9 months. On average, each participant stored 6.53kWh of excess solar energy per day and consumed 6.3kWh from the community battery. The pilot demonstrated clear economic benefits for participating households, with an average annual bill saving of A$281.16 per participant. Allume Energy, Parkside, South Australia – type 1 shared-behind-the-meter[footnote 16] Context: in December 2019, Housing Choices Australia (HCA) completed the Mary Street project, which uses Allume Energy’s shared solar system to expand access to clean energy for residents in social and affordable housing. The initiative used the company’s SolShare platform to distribute solar power across multiple flats in a building, enabling households that cannot install individual rooftop systems to benefit from local renewable generation. Residents also benefit from shared battery storage, which increases local resilience by storing excess solar and supporting reliable operation during peak periods. Technical setup: the development comprises 54 flats supported by a shared onsite energy system that includes four solar PV arrays with a combined capacity of 73kWp (around 1.35kWp per flat) and four communal battery units providing 40kWh of storage (about 0.74kWh per flat). The setup dynamically allocates solar generation to residents based on demand and uses the shared batteries to enhance resilience and smooth peak loads across the building. Economics: the project has delivered environmental and financial gains by providing renewable energy to residents who have traditionally been unable to access it, despite physical roof constraints limiting the system size. Average grid electricity consumption reduced by 32% per flat and 195 tonnes of CO₂ emissions were avoided since commissioning. These reductions translate into meaningful household savings: cutting A$332 off annual electricity bills per apartment and directly addressing fuel poverty. Beyond Australia, there are examples in European countries such as the Netherlands and Germany, where community batteries are integrated into local energy systems, often alongside community solar schemes. However, deployment remains limited, usually focusing on smaller pilot projects rather than large-scale rollouts comparable to Australia’s nationwide programme. These examples demonstrate that community battery projects vary in technical design and ownership model. Their impact depends on a combination of factors, including market conditions, regulatory frameworks, and consumer engagement. These initiatives can provide valuable insights into how the benefits case for different consumer battery models can change under different conditions, an area we are keen to understand in more depth. Buurtbatterij pilot project, Netherlands – type 3 virtual power network[footnote 17] Context: in 2018, the Buurtbatterij (“neighbourhood battery”) pilot in Haarlemmermeer was initiated by Liander, the regional grid operator, in partnership with Tegenstroom, a local energy supplier that operates as part of an energy cooperative. Liander owned and operated the battery, while Tegenstroom played a key role in community outreach and coordination. 35 households took part. Participation in the project was free, though households were required to rent solar PV panels from Tegenstroom at a discounted rate, saving around €180 per year. The installation of panels was carried out in partnership with a social housing provider to ensure accessibility for a wide range of residents. The primary aim of the pilot was to stabilise the local grid, which faced increasing pressure from growing renewable generation. Technical set up: the community battery had a capacity of 50kW/130kWh and was installed in front of the residents’ meters, connected directly to the distribution network. Each participating household was equipped with ‘Lyv Dash’, an energy management software that enabled the monitoring of energy flows and optimisation of consumption. Economics: the pilot showed that community batteries can be beneficial for voltage management and offered revenue opportunities, such as providing balancing services through aggregators. There were consumer benefits as well: the community battery allowed residents to store surplus solar PV generation locally and draw on it when needed. The local community consumed 16,354kWh of self-generated solar energy through the battery, which is equivalent to the annual consumption of five households. However, the financial viability of the battery was low, which ultimately led to the removal of the battery in March 2021. Flex4Energy project, Germany – type 3 virtual private network[footnote 18] Context: the Flex4Energy project, led by ENTEGA AG between 2015 and 2018, explored how decentralised flexibility could support Germany’s energy transition while delivering tangible benefits to local communities. The pilot centred on the installation of a community battery “the Quartierspeicher” in Groß‑Umstadt, funded as part of a €4.21m programme. This shared residential battery project responded to residents’ reluctance to install individual home batteries due to space limitations and maintenance concerns. Technical set‑up: the community battery had a capacity of 250kW/115kWh and served 23 households. The households’ PV generation was used onsite first; any surplus was automatically stored free of charge in the shared battery or exported to the low‑voltage grid. ENTEGA equipped each home with a bidirectional meter and developed software coordinating household PV systems and the neighbourhood battery so they could jointly provide self‑consumption optimisation, local grid support and participation in wider energy markets. Economics: the community battery enabled households to use more of their own low‑cost solar power instead of purchasing electricity from the grid, increasing their self‑sufficiency from around 51% to up to 70%, directly reducing electricity bills. Households could view real‑time data on generation, export, import and self‑sufficiency. This shared storage model also allowed residents to avoid the significant upfront cost, space requirements, and ongoing maintenance associated with installing individual home batteries. Respondents are invited to share views on the following: Hazelmead community energy – type 2 microgrid new build[footnote 19] Context: in 2023, Bridport Cohousing (a community-led organisation), Barefoot Architects, Bournemouth Churches Housing Association, and Hazelmead Community Energy Limited, completed a new-build development of 54 homes installed on a microgrid in Bridport, Dorset. The project was motivated by a shortage of affordable, sustainable and community-oriented housing in the local area. The whole development cost just under £10m to construct and it is net zero in operation. Technical setup: a microgrid was set up as the estate was developed, integrating 210kWp of rooftop solar photovoltaic panels with a 1.6MWh Tesla battery, 10 EV chargers and a small amount of wind power. Economics[footnote 20]: by reducing electricity imports and generating export revenues, the microgrid reduced the electricity costs for the development as a whole by the equivalent of £1,300 annually per home (including costs like maintenance and insurance). However, given that this project was one of the first of its kind, the upfront investment and ongoing interest repayments exceeded these savings. As a result, whilst the project provided a 15% bill saving guarantee for residents compared to the price cap, it did so at a loss and remained financially unviable. To make the model feasible in future, a reduction in both technology and financing costs would be required. The cost of batteries has fallen significantly since 2023 and is continuing to fall. The cost of servicing the debt incurred to finance this type of project could decline over time if successful case studies are delivered and investor confidence in the approach is obtained. Brixton Urban Energy Club – type 3 virtual private network[footnote 21] Context: in 2021, a community battery was installed alongside existing solar PV on Elmore house, a low rise 1960s block owned by Lambeth Council and managed by Loughborough Estate Management Board. UK Power Networks used £195k of innovation funding from Ofgem’s Network Innovation Allowance to test the viability of a community battery to provide flexibility services and reduce consumer bills. Technical setup: a 10kW/20kWh battery was connected to the grid via a meter operated by EDF. This allowed EDF to virtually ‘net off’ energy provided by the battery to deliver bill savings to any EDF customers in the block of flats. They received bill credits for any solar they consumed, shared or sold to neighbours, as well as a share of the income from flexibility services. The platform optimised the use of the battery to increase residents’ savings. Economics: the trial required residents to be on an EDF tariff which resulted in just four out of the 63 households at Elmore House receiving benefits. In the final three months of the trial, in which PV savings, battery savings and flexibility savings were all provided, the four households received total savings equivalent to ~£180 annually. However, the trial ran over winter, so electricity usage and thus savings would likely be lower over a full year. A summary of evidence received will be published following analysis of responses. We appreciate the time and insight provided by all contributors. Your evidence will play an important role in helping us understand the benefits of community batteries, the conditions needed for their successful deployment, and any potential regulatory or policy changes that could support their rollout. As a final question as part of this call for evidence, we would welcome views on the following: * Lithium-ion batteries supplied for use in consumer products are in scope of the General Product Safety Regulations 2005. It is the responsibility of producers to ensure these batteries are safe. Businesses must also meet their obligations in the regulations to provide all relevant information, including safety warnings or instructions, with the product to enable safe use. * A Publicly Available Specification for “Protection against fire of battery energy storage systems for use in dwellings” (PAS 63100) was released in 2024 to provide fire-safety requirements for domestic batteries in the UK. Its purpose is to establish a national safety baseline by ensuring installers understand and mitigate fire safety related hazards by specifying safe siting, protective measures and controls, thereby reducing the risk of batteries becoming a source of ignition and limiting the impact of a battery fire should one occur. * Microgeneration Certification Scheme (MCS) standards (MIS 3012) govern installation practices for domestic batteries.[footnote 13] This standard sets out requirements for certified installers covering design, supply, and installation of electrical energy storage systems in homes. Its purpose is to ensure consistent, high‑quality, and competent installation, incorporating provisions for safe wiring, ventilation, fire protection, and commissioning checks to ensure systems are installed reliably and in line with recognised best practice.
构网型储能变流器涉网性能测试评价理论体系研究成交候选人公示（项目编号：CG1500062002368458） 公示开始时间：2026-08-28 公示结束时间：2026-08-31 构网型储能变流器涉网性能测试评价理论体系研究（项目编号：CG1500062002368458），经采购工作组评审，现将成交候选人公示如下：一、评审情况1、成交候选人基本情况及响应采购文件要求的资格能力条件序号标的标包成交候选人排序成交候选人名称响应报价质量工期/交货期资格能力条件1构网型储能变流器涉网性能测试评价理论体系研究构网型储能变流器涉网性能测试评价理论体系研究1山东大学141.5万元符合满足满足 二、提出异议的渠道和方式报价人或者其他利害关系人对本项目的评审结果有异议的，应当在成交候选人公示期间，以书面形式提出异议。异议文件应当包括下列内容：1.提出异议人的名称、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。提出投诉人是法人的，异议文件必须由其法定代表人或者授权代表签字并盖章，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。4.异议人不得以异议为名排挤竞争对手，进行虚假、恶意异议，阻碍招标投标活动的正常进行。投标人故意捏造事实、伪造证明材料投诉、诽谤他人的，依据中国南方电网有限责任公司供应商相关管理规定对该投标人进行处理。异议文件必须于2026-08-31前通过传真或者当面递交。传真号码：020-38122354递交地址：广州市天河区天河路178号异议递交电话：4008100100转2，递交异议后，请通过电话反馈递交情况。三、其他公示内容发布媒介为南方电网供应链统一服务平台（http://www.bidding.csg.cn/）。四、提出投诉的渠道和方式投标人（供应商）或者其他利害关系人认为本次采购活动不符合法律、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采购人提出异议。（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。五、联系方式采 购 人：南方电网科学研究院有限责任公司联 系 人：袁工电 话：4008100100-2 采购代理机构：南方电网供应链集团有限公司地 址：广州市天河区天河路178号南方电网供应链集团有限公司联 系 人：冯工电 话：4008100100-2 采购人（或采购代理机构）的主要负责人或授权的项目负责人（签名）：宋义林 采购人或其采购代理机构名称：南方电网供应链集团有限公司【盖章位置】2026-08-28 上一篇：南方电网财务有限公司2026-2027年终端设备采购项目(三次招标)中标公示 下一篇：广东电网有限责任公司2027-2028年办公家具采购项目框架招标中标公示
构网型储能变流器涉网性能测试评价理论体系研究成交结果公告 （采购项目编号：CG1500062002368458）经采购人定标，现将本项目成交结果公告如下：一、采购成交结果 序号标的标包成交人1构网型储能变流器涉网性能测试评价理论体系研究构网型储能变流器涉网性能测试评价理论体系研究山东大学 二、成交通知书领取方式请成交供应商于本公告发布之日起3个工作日内登陆中国南方电网有限责任公司供应链统一服务平台（http://www.bidding.csg.cn），按要求查看并下载成交通知书。 三、联系方式采 购 人：南方电网科学研究院有限责任公司联 系 人：袁工电 话：4008100100-2 采购代理机构：南方电网供应链集团有限公司地 址：广州市天河区天河路178号联 系 人：冯工电 话：4008100100-2 采购人（或采购代理机构）主要负责人或授权的项目负责人（签名）：宋义林 采购人或其采购代理机构名称：南方电网供应链集团有限公司【盖章位置】2026-09-02 上一篇：南方电网广西电动汽车服务有限公司2026-2028年人力资源劳务服务公开招标采购项目中标公告 下一篇：云南电网有限责任公司2026年计量中心第2批服务类专项采购（公开询比）成交候选人公示
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）专项服务公开招标中标候选人公示（招标编号：CG0900022002369186） 公示开始时间：2026-09-04 公示结束时间：2026-09-07 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（招标编号：CG0900022002369186），经评标委员会评审，现将中标候选人公示如下：1.评审情况1.1中标候选人基本情况及响应招标文件要求的资格能力条件序号标的标包中标候选人排序中标候选人名称投标报价质量工期/交货期资格能力条件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1南京南瑞继保工程技术有限公司481.6万元符合满足满足2标的3：安全评价安全评价1中国安全生产科学研究院30万元符合满足满足3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投标家数不足，招标失败 1.2中标候选人按照招标文件要求承诺的项目负责人情况（如有）序号标的标包中标候选人排序中标候选人名称项目负责人姓名相关证书名称及编号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1南京南瑞继保工程技术有限公司//2标的3：安全评价安全评价1中国安全生产科学研究院// 2.其他公示内容无。3.监督投诉及异议投标人或其他利害关系人认为本次采购过程中存在违规行为的，或对资格预审文件（如有）、招标文件、评标结果存在异议的，有权通过招标代理机构向招标人提出。异议文件应当包括下列内容：提出异议人的名称、地址及有效联系方式；异议事项；有效线索和相关证明材料。提出异议人是法人的，异议文件必须由其法定代表人或者授权代表签字并盖章，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。异议人不得以异议为名排挤竞争对手，进行虚假、恶意异议，阻碍招标投标活动的正常进行。异议接收机构名称：南方电网供应链集团有限公司异议受理邮箱：zbybyk@csg.cn投标人或者其他利害关系人认为本次采购活动不符合法律、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。4.联系方式招 标 人：深圳电网智慧能源技术有限公司联 系 人：任工电 话：4008100100-2 招标代理机构：南方电网供应链集团有限公司地 址：广州市天河区天河路178号联 系 人：罗工电 话：4008100100-2 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：南方电网供应链集团有限公司【盖章位置】2026年09月04日 上一篇：2026-2027年南方电网数字电网集团(贵州)有限公司-基础平台软件运维原厂标准服务直接采购公示 下一篇：深圳电网智慧能源技术有限公司2026年新型电力系统智能化升级改造项目、长富金茂大厦办公场所设计施工总承包框架采购公开招标中标公示
本轮没有找到这一侧的材料。