Including an initial contract signed in late 2025, the two agreements between the companies total 1.5 GWh. AOP plans to deploy the systems in projects intended to support grid reliability and growing electricity demand. Construction is scheduled to begin next year in the Western Electricity Coordinating Council (WECC) and Electric Reliability Council of Texas (ERCOT) power markets.

Under the latest agreement, SAMSUNG SDI will supply its Samsung Battery Box (SBB) 1.7, an integrated energy storage solution using nickel cobalt aluminum (NCA) batteries. All cells and modules will be manufactured at the StarPlus Energy (SPE) plant in Kokomo, Indiana, with delivery scheduled for completion by the end of 2026.

SBB 1.7 Offers Higher Energy Density

The SBB 1.7 uses high-capacity, high-nickel NCA battery chemistry and provides 17% higher energy density than its predecessor, SBB 1.5, while retaining the same 20-foot footprint.

The system incorporates SAMSUNG SDI’s design expertise, including artificial intelligence-powered algorithms for early anomaly detection and battery life prediction. It is designed for 25 years of continuous use, according to the company.

The solution also incorporates SAMSUNG SDI’s proprietary Enhanced Direct Injection (EDI) technology. This system injects fire-extinguishing agents directly into individual battery modules to enhance fire safety.

Safety Certifications and U.S. Manufacturing

SBB 1.7 has obtained certifications and met safety standards including NFPA 855, the National Fire Protection Association standard for installing stationary energy storage systems, and UL 9540, a safety standard for energy storage systems.

Manufacturing the battery cells and modules at the Indiana facility will support the domestic supply chain for the agreement. The companies expect the U.S.-made systems to serve utility-scale projects in two major power markets, with construction planned to start in 2027.

Paul Choi, CEO of Alpha Omega Power, said, “American-made ESS from SAMSUNG SDI will play an important role in AOP’s continued growth. This second agreement strengthens our domestic supply chain supporting the next generation of energy infrastructure.”

Expanding U.S. Energy Storage Partnerships

SAMSUNG SDI said it has secured several energy storage supply agreements with U.S. energy companies during 2026 and is discussing potential agreements with additional local customers. The company expects further orders in the near future.

Industry analysts have attributed recent contract wins in part to its prismatic battery technology, known as PrismStack. SAMSUNG SDI describes itself as the only non-Chinese supplier of prismatic energy storage batteries in North America. The company highlights the durability and fire safety of its prismatic batteries compared with pouch-type batteries.

Fabrice Hudry, President of the ESS team at SAMSUNG SDI America, said, “Alpha Omega Power is one of the fastest growing independent power producers in the country, and the kind of sophisticated operator we want to partner with to tackle grid reliability challenges. With our differentiated technology and local production capabilities, we will continue to expand our business foundation and strengthen our position in the North American ESS market.”

The agreement adds to SAMSUNG SDI’s U.S. energy storage business and combines domestic battery manufacturing with planned utility-scale deployments. The latest 1 GWh contract, together with the earlier agreement, brings the companies’ total contracted supply volume to 1.5 GWh.

The reforms form part of the government’s ambition to quadruple nuclear power output to 24 GW by 2050. Electricity demand in Britain is forecast to rise by 40% by 2035, according to the National Energy System Operator, increasing the importance of reliable electricity generation.

The Office for Nuclear Regulation (ONR), Environment Agency (EA) and Natural Resources Wales (NRW) aim to reduce reactor design approval periods from approximately three or four years to around two years. The changes follow the 2025 Nuclear Regulatory Review, which identified fragmented oversight, costly regulatory decisions and complex legislation as obstacles to nuclear development.

The review made 47 recommendations, including improved coordination between regulators, more proportionate safety assessments and a fleet-based approach that would reduce the need to repeatedly examine identical reactor designs. The government also intends to streamline planning and environmental approvals, which have contributed to lengthy development schedules and high costs.

Holtec SMR Project Could Test Regulatory Cooperation

Holtec’s proposed SMR-300 deployment in the UK could provide an early test of whether regulatory cooperation between Britain and the United States can reduce approval times.

UK authorities have identified the company’s two-unit SMR-300 project at Palisades in Michigan as the reference design for its UK Generic Design Assessment (GDA). The GDA evaluates a reactor design’s safety, security and environmental acceptability independently of a specific site.

Holtec submitted its Preliminary Safety Analysis Report for Palisades to the U.S. Nuclear Regulatory Commission (NRC) on 30th September 2026. The company intends to use the U.S. design and safety analysis in Britain.

“Our intention is to apply the U.S. design and safety analysis in the UK,” said Patrick O’Brien, Executive Director, Government Affairs and Communications at Holtec International.

Holtec completed Step 2 of the GDA for its SMR-300 in March 2026. The company plans to deploy up to four units with EDF and Tritax at Cottam, a former coal-fired power station in Nottinghamshire, England. The proposed development would provide around 1.3 GW of generating capacity.

Reusing design and engineering work from Palisades could help reduce first-of-a-kind engineering risks and improve schedule and cost predictability. However, the extent to which UK regulators will accept assessments completed by the NRC remains a key factor in determining the potential benefits.

U.S. Reactor Designs Enter UK Assessment Process

Several other U.S. developers are progressing through the British regulatory process. Westinghouse’s 300 MW AP300 reactor entered the GDA process in August 2024. TerraPower’s Natrium reactor formally began its GDA application process in June 2026, while X-energy’s Xe-100 entered the process in September.

TerraPower has not selected a site for its first UK deployment. The company has said the project would represent the first Natrium reactor outside the United States.

X-energy said the GDA remains a rigorous assessment covering safety, security, safeguards and environmental acceptability. Its generic approach allows developers to establish whether a design is acceptable before incurring significant site-specific expenditure.

The company sees similarities with the NRC’s standard design certification process, which allows projects to rely on technology-level assessments rather than repeat every design review. X-energy is working with the ONR and NRC to map U.S. assessments against UK requirements.

A policy introduced by the ONR, EA and NRW in May 2026 provides a framework for the regulators to use assessments conducted by trusted overseas regulatory bodies.

X-energy has selected Centrica as its partner to develop up to 6 GW of advanced nuclear capacity in Britain. The proposed initial development is a 12-reactor, 960 MW project at Hartlepool in northeast England. Centrica owns 20% of Britain’s operational nuclear fleet and holds a 15% stake in the 3.2 GW Sizewell C project in Suffolk.

UK Government Support for Domestic SMR Development

U.S. developers will face competition from Britain’s domestic nuclear programme. Great British Energy-Nuclear has contracted Rolls-Royce SMR to deliver three reactors with a combined generating capacity of 1.4 GW at Wylfa, a former nuclear site on Anglesey in North Wales. The site could eventually accommodate eight units.

Initial work at Wylfa is due to begin in 2026, with the first reactor expected to become operational in the mid-2030s. The UK government has committed more than £2.5 billion to its wider SMR programme, which includes the Wylfa development.

Rolls-Royce SMR also has an established domestic supply chain. The company has spent more than £300 million with suppliers since 2021, with at least 70% of that spending going to UK businesses.

Holtec is evaluating the business case for a UK factory that could serve as a regional component manufacturing hub. Westinghouse signed agreements with six British suppliers in September 2025 to support the construction of AP1000 and AP300 reactors in the UK and other markets.

Stewart Forbes, Counsel at Hogan Lovells Cadwalader said, “The economics of SMRs depend on repeat production and standardisation.” U.S. developers may benefit from their larger domestic market and international manufacturing networks, while Britain’s support for pressurised-water SMRs and Generation IV advanced modular reactors could create opportunities for several reactor designs.

The outcome will depend on how effectively the UK implements its proposed nuclear regulation changes and whether regulators can recognise relevant overseas assessments without compromising safety and environmental standards.

The collaboration will assess potential options to meet the growing electricity requirements of AI-driven infrastructure while reducing its carbon footprint. The proposed data centre energy solutions include low-carbon hydrogen-based power generation, biomethane-based electricity generation, vertical building-applied photovoltaics and renewable energy imports from Malaysia.

The collaboration brings together Nxera’s data centre operations and Sembcorp’s energy capabilities to assess potential supply arrangements. The companies will also examine the potential use of energy from a 2.2 GWp floating solar project at Linggiu Reservoir in Johor, Malaysia. The initiative could provide an avenue to support Singapore’s digital infrastructure.

Low-Carbon Power Options Under Review

Koh Chiap Khiong, President and CEO of Gas and Related Services and CEO of Singapore at Sembcorp, said, “As AI adoption accelerates globally, demand for reliable, scalable and lower-carbon energy continues to grow. With a proven track record of powering the data centre sector, Sembcorp is well-positioned to support this growth through our diversified energy portfolio. Our partnership with Nxera further affirms our shared ambition to enable the next generation of digital infrastructure while advancing the global energy transition.”

Singapore Malaysia Energy Cooperation

The MOU was signed in the presence of Dr Tan See Leng, Singapore’s Minister for Energy, Trade and Industry (Energy and Industry), and Datuk Amar Haji Fadillah bin Haji Yusof, Malaysia’s Deputy Prime Minister and Minister of Energy Transition and Water Transformation.

Bill Chang, CEO of Nxera and Singtel’s Digital InfraCo unit, said, “AI is driving a step-change in the power needs of data centres, and in a land- and resource-constrained market like Singapore, how we source that power matters. Working with Sembcorp gives us more options to power our growth sustainably and responsibly. Strengthening our energy resilience will be critical to underpinning Nxera’s long-term development in Singapore while supporting Singapore’s digital ambitions.”

The proposed project is planned for Sinop, in Turkey’s Black Sea region. AtkinsRéalis Chief Executive Officer Ian Edwards said in a LinkedIn post that the company would conduct a feasibility study to advance the potential construction of CANDU reactors at the site.

The development follows an agreement between Canada and Turkey to strengthen their strategic partnership, including cooperation in energy, defence, security, trade and investment. Carney said the Turkish government would make the final decision on the nuclear project, but he believes Canada’s prospects have improved.

AtkinsRéalis Explores CANDU Technology for Sinop

Turkey has held discussions with several countries about its planned second nuclear power plant, including Canada, South Korea, Russia, China and Japan. The proposed facility is planned for Sinop, where AtkinsRéalis is exploring the potential application of its CANDU reactor technology.

Speaking to reporters in Istanbul, Carney said there was active competition for the project and suggested a decision could be made before the end of 2026.

He highlighted Canada’s nuclear technology, partnerships with Turkish businesses and potential to develop elements of the supply chain as factors supporting its proposal.

“If you would have asked us a year ago how we would have pegged the chances, they would have been very low. Now there are good chances. There’s real competition, of course,” Carney said.

The feasibility study is an early step in assessing the potential project. The announcement does not confirm a construction contract, a final technology selection or a construction schedule for the proposed plant.

Canada and Turkey Strengthen Nuclear Energy Cooperation

The nuclear discussions form part of a broader effort by Canada and Turkey to expand economic and strategic cooperation. During Carney’s visit to Ankara, the two NATO allies upgraded their bilateral relationship to a strategic partnership, with energy identified as one of its principal areas of cooperation.

The agreement aims to create further opportunities for Canadian and Turkish businesses through expanded trade and investment. The countries also announced plans to increase collaboration across the energy sector, including civil nuclear energy, liquefied natural gas (LNG) and renewable energy.

For AtkinsRéalis, the potential Sinop project would provide an opportunity to explore the use of Canadian CANDU technology in Turkey’s nuclear power development programme. Carney also pointed to cooperation with Turkish companies in construction and the potential to establish supply-chain links as elements of Canada’s proposal.

Turkey’s government will ultimately determine which partner or technology is selected for the second nuclear power plant. The country has been considering proposals from several international participants, and the feasibility study does not guarantee that AtkinsRéalis will be selected.

Turkey’s Nuclear Programme Includes Multiple Planned Plants

Turkey is pursuing nuclear power development at several locations. Its first nuclear power station is under construction at Akkuyu, in the Mediterranean province of Mersin, by Russia’s state-owned nuclear energy company Rosatom.

The Akkuyu project is being developed under a USD 20 billion agreement signed in 2010. Rosatom said in October 2026 that it expected a nuclear start-up at the site by the end of the year.

Beyond Akkuyu, Turkey plans a second nuclear power plant at Sinop and a third in the northwestern region of Thrace. The potential involvement of AtkinsRéalis in Sinop remains under consideration as Turkey engages with international partners.

The selection of a technology provider and project partner will be a significant step in determining how the second plant proceeds. At present, the AtkinsRéalis feasibility study represents progress in evaluating the CANDU option, rather than confirmation that construction will go ahead with the Canadian company.

Feasibility Study Precedes a Final Project Decision

Carney said the Turkish government would make the final decision on the second nuclear power plant and noted that competition from other international suppliers remains strong. He nevertheless expressed greater confidence in Canada’s position following the strategic partnership agreement.

AtkinsRéalis has identified the Sinop site as the focus of its feasibility work for potential CANDU reactor construction. The study is intended to advance consideration of the technology, while the broader bilateral agreement creates a framework for further cooperation in civil nuclear energy and other sectors.

No final contract, investment amount or construction timetable for the Sinop plant was announced in the report. The next major milestone will be Turkey’s decision on the project and the technology and partners it chooses to pursue.

The development of nuclear fuel manufacturing is intended to strengthen the domestic nuclear fuel supply chain, support the existing US reactor fleet and enable the wider deployment of advanced nuclear technologies. Westinghouse described the facility as the first fleet-scale nuclear fuel factory built in the United States in more than 50 years.

The investment also aligns with the US government’s efforts to restore domestic nuclear fuel capabilities and meet rising demand for reliable, low-carbon baseload electricity.

New Facility to Expand LEU+ Fuel Production

The new Columbia factory will manufacture LEU+ fuel, which uses uranium enriched to between 5% and 8%. This enrichment range is higher than that of conventional low-enriched uranium fuel used in many commercial reactors.

According to Westinghouse, LEU+ fuel could allow eligible nuclear power plants to extend operating cycles and pursue power uprates, subject to reactor-specific technical assessments and regulatory approvals. These capabilities could help operators increase electricity output, improve operating flexibility and reduce certain operating costs.

The company said the new facility builds on the first successful deployment of LEU+ fuel in the United States in 2025. Expanding production capacity is intended to move the technology toward broader commercial availability.

Westinghouse also expects the fuel to support the long-term operation of existing nuclear plants and the deployment of its AP1000 reactor technology internationally.

Investment Supports US Nuclear Energy Expansion

The project is aligned with the United States’ UPRISE program, which seeks to support increased nuclear generation from the existing reactor fleet. By expanding fuel manufacturing capacity, Westinghouse aims to help utilities access the fuel needed to support higher output from eligible facilities.

US officials have also emphasized the importance of establishing a secure domestic supply chain for nuclear fuel. The Department of Energy is investing in efforts to restore uranium enrichment capabilities for both low-enriched uranium and high-assay low-enriched uranium.

Assistant Secretary for Nuclear Energy Ted Garrish said, “A strong American nuclear industry starts with a secure, domestic supply of nuclear fuel.”

The new factory will provide additional manufacturing capacity to convert enriched uranium into fuel assemblies and other products used in nuclear reactors. Its development forms part of a broader effort to strengthen domestic nuclear infrastructure and support the next generation of nuclear technology.

South Carolina Facility to Support Jobs and Economic Growth

Westinghouse’s Columbia Fuel Fabrication Facility was built in 1968 and is one of the world’s largest nuclear fuel plants. It manufactures fuel pellets, rods, assemblies and components for Westinghouse facilities and customers worldwide.

The site currently employs more than 1,200 people in Lower Richland, South Carolina. The expansion is expected to create additional employment opportunities through construction, equipment installation, workforce development and long-term manufacturing operations.

An economic impact study commissioned by Westinghouse in partnership with researchers at the University of South Carolina’s Darla Moore School of Business estimates that the investment could generate US$4.9 billion in positive economic impact across South Carolina over the next decade. Of that amount, approximately US$3.8 billion is projected to benefit Richland County.

“South Carolina is already leading America’s nuclear renaissance, and our state has been producing the nuclear fuel that powers approximately 10% of the United States from Westinghouse’s fuel operations in Richland County,” said South Carolina Governor Henry McMaster. “We are grateful for Westinghouse’s continued leadership in South Carolina, and we look forward to it expanding its work in our state to create next-generation fuel products that will continue to support nuclear energy production well into the future.”

Congressman James E. Clyburn added, “This investment is a testament to our state’s skilled workforce and the important role we play in strengthening America’s clean energy. By expanding our domestic nuclear fuel production capabilities, we are creating economic opportunities, supporting good-paying jobs and positioning South Carolina as a leader in the nation’s energy sector.”.

Construction Underway Ahead of 2030 Operations

Construction of the new LEU+ fuel manufacturing building is underway, with Westinghouse targeting the start of operations in 2030. The company said support from the US Department of Energy’s tax credit program, state authorities and Richland County helped advance the investment.

Westinghouse has also stated that the project will incorporate environmental stewardship measures, including responsible site development and preservation of native landscapes that support wildlife habitats and local air and water resources.

Once operational, the facility is expected to increase US capacity to manufacture advanced nuclear fuel. The expansion will be an important step in Westinghouse’s plans to support existing reactors, enable potential increases in nuclear generation and supply fuel for future reactor deployments.

The green hydrogen project represents a further step in China’s efforts to scale up renewable hydrogen and low-carbon fuel production for industrial and international markets. According to CEEC, the expansion involves an investment of RMB 10.83 billion and builds on the operating experience of the industrial park’s first phase.

Second Phase Targets Higher Production and Lower Costs

The second phase is designed to improve production efficiency and reduce the cost of manufacturing green ammonia. CEEC expects unit production costs to fall by more than 10% compared with Phase 1, supported by optimized facility design, upgraded domestic equipment and digital industrial management systems.

The wider industrial park integrates renewable electricity generation with hydrogen production, ammonia synthesis and methanol manufacturing. Wind and solar power supply electricity for electrolysis, which separates water into hydrogen and oxygen. The hydrogen can then be used to produce ammonia and other chemical products.

This integrated approach links renewable power generation with industrial fuel production. It also offers a way to store and transport renewable energy in chemical form, potentially serving sectors where direct electrification remains difficult.

The broader development plan envisages 3,000 MW of renewable energy generation capacity and large-scale production of green hydrogen, ammonia and methanol. The second phase will expand the facility’s production capabilities as CEEC seeks to improve the economics of renewable fuels.

Phase 1 Provides the Operational Foundation

The first phase of the Songyuan Hydrogen Energy Industrial Park began operations in December 2025. It includes 800 MW of renewable energy capacity and was designed to produce 45,000 metric tons of green hydrogen and 200,000 metric tons of green ammonia annually, alongside green methanol production and hydrogen storage facilities.

The first phase established the initial production infrastructure for the larger industrial park. The second phase is intended to build on that foundation through increased capacity, equipment upgrades and improved operating efficiency.

China Power Engineering Consulting Group’s Northeast Institute served as the engineering, procurement and construction contractor for the original project, according to CEEC. Other suppliers involved in the wider development include Sungrow Hydrogen for hydrogen production systems, Goldwind for wind turbines and subsidiaries of CIMC Enric for hydrogen storage equipment.

The green hydrogen project received ISCC EU certification in December 2025, according to CEEC. Such certification can support participation in international renewable fuel markets by providing evidence related to sustainability and supply-chain requirements.

Green Ammonia Targets Shipping and Industrial Markets

Green ammonia is one potential output of the expanded facility, with applications in established chemical markets and emerging low-carbon fuel markets. In shipping, ammonia can potentially be used as a marine fuel or as a carrier for hydrogen, offering an alternative pathway for reducing emissions in hard-to-electrify sectors.

In October 2026, ammonia produced at the facility was reportedly used in a ship-to-ship green ammonia bunkering operation in Zhoushan, Zhejiang Province. The demonstration connected production with storage, transfer and maritime fuel application.

Green ammonia may also serve conventional industrial uses, including fertilizer manufacturing. Its environmental benefits depend on factors such as the electricity source, production methods, supply-chain emissions and end use. Safe handling will require specialized procedures, while broader maritime adoption depends on the availability of suitable vessels, engines and bunkering infrastructure.

Expanding production could help CEEC pursue emerging demand from shipping operators and industrial consumers seeking alternatives to fossil-derived fuels. However, the commercial outlook will depend on production costs, certification requirements, transport infrastructure and buyers’ willingness to pay for lower-carbon products.

Cost Competitiveness Remains Key to Expansion

The Songyuan project reflects China’s efforts to move renewable hydrogen technologies from early deployments toward large-scale industrial production. The country’s established wind and solar manufacturing sectors, chemical production infrastructure and domestic ammonia market provide a foundation for integrating renewable electricity with fuel manufacturing.

Larger production volumes may help spread capital costs across more output and improve equipment utilization. Nevertheless, the commercial viability of green ammonia will continue to depend on renewable electricity prices, electrolyzer performance, financing costs, infrastructure availability and long-term purchase agreements.

The second phase will therefore provide a significant test of whether improved technology, optimized facility design and increased output can make renewable ammonia more competitive with conventional ammonia produced using fossil fuels.

International trade could provide another growth opportunity, linking Chinese renewable fuel production with shipping and industrial demand in overseas markets. Access to those markets will depend on sustainability certification, fuel standards, logistics and commercial agreements.

With the first phase operating and construction of the second phase underway, the Qingqing No. 1 Songyuan Hydrogen Energy Industrial Park is moving toward expanded production of green hydrogen and renewable fuels. Its performance will help demonstrate whether integrated renewable power and chemical production can achieve the cost reductions required for broader commercial adoption.

The battery system is located alongside the onshore converter station for Ørsted’s Hornsea 3 offshore wind farm. It comprises 170 Megapack battery units designed to store surplus electricity and release it when demand increases, supporting grid balancing and the integration of renewable energy.

The project brings together specialists from Ørsted, Hitachi Energy, Knights Brown and Tesla. Once completed and operational, Iceni is expected to rank among Europe’s largest battery energy storage systems.

Iceni Battery Storage Project Reaches Construction Milestone

The Iceni facility is designed to provide 300 MW of power and 600 MWh of energy storage capacity. According to Ørsted, this is equivalent to the daily electricity consumption of approximately 80,000 UK homes.

The system uses 170 Megapack units installed across two separate areas of the site. These areas are divided by the Hornsea 3 onshore converter station, creating a more complex layout than a conventional battery storage facility with a single connected site.

The two sections are linked by 18 cross-site cables operating at 33 kV, each extending more than 600 metres. Integrating the battery system with Hornsea 3’s shared grid connection has also introduced additional technical requirements compared with a standalone connection to the National Grid.

The successful completion of construction represents an important step towards bringing the storage facility into service. The remaining work includes electrical installation, cable termination, commissioning and preparations to energise the battery storage transformer.

Battery Storage to Support Renewable Energy Integration

Beatrice d’Eufemia, Project Manager for Iceni BESS at Ørsted, said, “It is a milestone moment for Ørsted that construction is now complete on our first large scale BESS in the UK. The system will make the best use of renewable energy produced in the UK as when electricity generation exceeds demand, the excess can be stored and then used when demand is greater, helping balance the grid and lower electricity costs for everyone.”

The facility’s 600 MWh capacity and 300 MW power rating define how much energy it can store and the rate at which it can deliver electricity. Actual operating performance will depend on commissioning outcomes, operating conditions and the requirements of the electricity system.

Complex Site Layout Requires Cross-Company Coordination

The project’s split-site configuration has required close coordination among the organisations involved in construction and electrical integration. The two battery areas must operate as part of a connected system despite being separated by the offshore wind farm’s onshore converter station.

Installing and terminating the 33 kV cross-site cables is a key part of this process. The shared grid connection with Hornsea 3 also adds complexity to the integration and commissioning work.

Richard Swann, Construction Manager for Iceni BESS at Ørsted, said, “It’s a real testament to the hard work, dedication, and co-operation of the team from many different organisations that the construction has been completed successfully.”

The project team includes specialists from Ørsted, Hitachi Energy, Knights Brown and Tesla, combining expertise in energy infrastructure, electrical systems, construction and battery technology.

Project Supports UK Energy Infrastructure Development

The project has also created opportunities for local skills development and employment. David Shillabeer, Head of Transmission & Distribution at Knights Brown, said, “Reaching this milestone is a significant achievement for everyone involved in the Iceni project. Delivering a BESS of this scale has required close collaboration between Ørsted, Knights Brown, and the many other organisations that have contributed to its success. Beyond the engineering, the scheme has enabled us to invest in local people, develop skills, and create opportunities across Norfolk and the wider region. We are proud to have played our part in an important project that will support the UK’s transition to a more resilient, low-carbon energy system, while leaving a positive legacy for the communities in which we work.”

With construction complete, Iceni is moving towards the remaining commissioning and energisation stages before full operation. Its planned 300 MW output and 600 MWh storage capacity are intended to provide additional flexibility for the UK electricity system and support the use of renewable power.

The development marks Ørsted’s entry into large-scale battery energy storage in the UK and demonstrates the role of storage infrastructure alongside offshore wind generation.

The test marks a technical development in integrating renewable energy into grid restoration procedures. As wind and solar power account for a growing share of electricity generation in the region, grid-forming technology could provide additional resources for restoring local power supplies when conventional grid connections are unavailable.

Grid-Forming Technology Supports Black Start Capability

Black start refers to the process of restoring electricity generation and transmission after a widespread blackout without relying on an external power supply to restart the system. Conventional wind turbines generally follow the voltage and frequency established by the grid, meaning they cannot independently restart a power system after a complete loss of supply.

Grid-forming wind turbines, when integrated with energy storage, can establish voltage and frequency independently. This capability allows the equipment to energize selected electrical infrastructure and potentially support the gradual restoration of other equipment within a wind farm.

During the wind farm black start test, energy storage equipment helped the grid-forming system establish voltage and energize the 35 kV collector line. The equipment then operated stably for more than three hours, demonstrating that a single grid-forming turbine could drive the restart process for the wind farm under the tested conditions.

The result provides a potential pathway for incorporating renewable generation into emergency grid restoration strategies. However, wider deployment will depend on technical requirements, system configuration and validation under different grid conditions.

Renewable Energy Growth Increases Grid Restoration Needs

The test comes as renewable energy capacity continues to expand across Hebei’s southern power grid. By the end of September 2026, installed wind and solar capacity in the region had reached 59.23 million kilowatts, equivalent to 59.23 GW, accounting for more than 61% of total installed capacity.

With wind and solar resources representing a growing proportion of the regional generation mix, grid operators are exploring ways to maintain stability and restore electricity supply during major disruptions. Wind farms equipped with grid-forming systems and energy storage could potentially provide local support alongside established black start resources, including pumped-storage hydropower.

The ability to establish voltage without an external grid supply is particularly relevant during emergency conditions. It could help reduce dependence on conventional generation sources for initial restoration and provide additional options for reconnecting parts of the electricity network.

Simulation and Risk Assessment Preceded the Test

Before the field test, technical specialists from the State Grid Hebei Electric Power Research Institute developed a high-precision simulation model to assess system behaviour under complex operating conditions. The team repeatedly evaluated risks associated with key stages, including voltage establishment, grid connection and stable load carrying.

This preparatory work helped assess the system’s response before the technology was tested at the wind farm. During the field operation, the integrated grid-forming and energy storage equipment established voltage and energized the collector line, after which the system maintained stable operation for more than three hours.

The successful test indicates that the technology can support a defined black start sequence at the station level. Further engineering work and operational validation would be needed to establish how the approach could be applied across different wind farms and wider network restoration scenarios.

Wind Farms Could Expand Emergency Power Resources

The Liuqing test adds wind generation to the range of resources being evaluated for grid restoration in Hebei. By combining grid-forming turbines with energy storage, operators could potentially use renewable energy facilities as local emergency resources rather than relying exclusively on conventional generation and storage assets.

The approach may be particularly useful in areas with high renewable energy penetration, where maintaining reliable electricity supply requires new methods of coordinating generation, storage and grid control systems.

The successful demonstration provides an engineering example for further evaluation in North China and other regions with substantial wind and solar capacity. Its wider contribution will depend on the ability to replicate the performance under different network configurations, operating conditions and restoration requirements.

As renewable generation expands, grid-forming technology could become an increasingly important part of strategies to strengthen electricity system resilience and accelerate recovery from major power disruptions.

On 20th October 2026, the county’s board of supervisors voted 3-1 in favour of the project following several hours of public comment. The approval follows an August recommendation from the local planning commission to grant the conditional use permit required for the development.

Dominion Energy plans to build the facility in Cumberland County, approximately an hour west of Richmond, Virginia. The company has identified a site of around 150 acres off Duncan Store Road and is targeting 2029 for the start of construction.

Combined-Cycle Technology Planned for 3 GW Facility

The proposed Cumberland Energy Center would use two combined-cycle gas-fired units, each configured in a two-on-one arrangement. Together, the units are expected to provide approximately 3 GW of baseload generating capacity.

Combined-cycle power plants use gas turbines to generate electricity and capture heat from their exhaust to produce additional power through a steam turbine. This configuration can improve fuel efficiency compared with generating electricity using a gas turbine alone.

Dominion Energy has positioned the project as part of its efforts to maintain reliable electricity supplies as demand increases across its service territory.

“We look forward to continuing to engage with the community as we move forward with this very vital project, not only to our customers in providing reliable power but also to the Cumberland community,” said Jeremy Slayton, a Dominion Energy spokesperson, in a statement.

The local permit approval represents one stage in the development process. The project still needs an air permit from the Virginia Department of Environmental Quality and approval from the Virginia State Corporation Commission before it can advance.

Dominion Energy Plans Additional Generation Capacity

The Cumberland Energy Center forms part of Dominion Energy’s broader planning for future electricity demand. Earlier in 2026, the utility projected that it might need to develop as many as six natural gas-fired power plants over the next two decades, alongside additional renewable energy projects.

Dominion has also advanced solar and battery storage developments in Virginia. State officials approved five proposed solar and battery storage projects earlier in 2026, as well as ten power purchase agreements representing up to 1 GW of generating capacity.

These developments reflect the utility’s plans to expand its generation resources to meet anticipated demand. The proposed gas-fired facility would provide dispatchable generation, while renewable energy and battery storage projects would contribute additional capacity and flexibility to the electricity system.

Project Cost Expected to Reach Billions of Dollars

Dominion Energy has not announced an official cost estimate for the Cumberland Energy Center, but the utility has described it as a “multi-billion-dollar project.” The company has indicated that the project will cost more than its Chesterfield Energy Reliability Center, a separate 944 MW gas-fired power plant approved by regulators in 2025.

The Chesterfield facility has an estimated price tag of US$1.47 billion and is being built at the former Chesterfield Power Station, where the last operating coal-fired units retired in 2023. The new plant is located near existing gas-fired Units 7 and 8, which have a combined generating capacity of 446 MW.

The Cumberland project would represent a substantially larger proposed gas-fired development, although its final investment cost and construction schedule remain subject to further approvals and project decisions.

Further Energy Projects Planned in Virginia

Virginia is also attracting investment in other forms of electricity generation. In December 2024, Commonwealth Fusion Systems announced plans to develop a proposed 400 MW fusion power facility at James River Industrial Park.

The proposed fusion project is separate from Dominion Energy’s Cumberland Energy Center, but it highlights the range of generation technologies being considered for the state’s future electricity supply.

For the Cumberland Energy Center, the immediate milestones are securing the outstanding state permits and regulatory approval. Dominion Energy is targeting construction to begin in 2029, but the project’s development timeline will depend on the completion of those remaining steps.

The two projects strengthen Acciona Energía’s wind power portfolio in Croatia, where the company has operated the 30 MW Jelinak wind farm since 2013. Croatia had 1,309 MW of installed wind capacity at the end of the first half of 2026, according to a WindEurope report. Globally, Acciona Energía’s total installed capacity reached 14.7 GW by the end of June 2026.

Wind Farms Add 72 MW of Capacity

One of the Croatian wind farms, The Opor wind farm, located in the Split-Dalmatia region, has a capacity of 27 MW and comprises six wind turbines. The other one, Boraja II, situated in Šibenik-Knin County, adds 45 MW through ten turbines. Both facilities use 4.5 MW Nordex turbines mounted on 105-metre steel towers.

Together, the wind farms are expected to generate approximately 203 GWh of electricity annually. Acciona Energía estimates that their output will prevent around 135,000 tonnes of carbon dioxide emissions each year. During peak construction activity, the projects created up to 400 direct jobs.

Both wind farms operate under 12-year contracts for difference (CfDs) awarded through a public auction. The scheme was launched by the Croatian government and HROTE and approved by the European Commission to support renewable energy deployment.

Under the CfD mechanism, projects receive a reference price for the electricity they generate. This arrangement provides greater revenue stability and reduces exposure to fluctuations in wholesale electricity prices, according to Acciona Energía.

Acciona Energía Expands Its Croatian Renewable Energy Portfolio

Acciona Energía secured support for the two wind projects at Croatia’s first auction for utility-scale renewable electricity plants in July 2022. The company was the only successful bidder to win premiums for wind power projects in that auction.

In 2024, Acciona Energía also secured a 12-year CfD agreement for its Promina photovoltaic project in Šibenik-Knin County, expanding its presence in Croatia’s solar energy sector.

The start of commercial operations at Opor and Boraja II marks a further step in the company’s Croatian development activities, adding new wind generation capacity supported by long-term electricity pricing arrangements.