While the merger plans were announced in May this year, with rising power demand from data centers, electric vehicles, and other American industries driving a renewed wave of ⁠utility consolidation, the development has also drawn sharp reactions from the lawmakers.

Stating the new program would direct spending toward contractors, suppliers, and service providers in Virginia, NextEra and Dominion have proposed extending monthly USD 10 bill credits to four years from two, along with increasing Dominion’s low-income financial assistance by USD 100 million through 2038.

The companies’ commitments also include a USD 100 million “workforce development fund,” an annual energy ‌summit ⁠in the state of Virginia, apart from maintaining the current employee headcount there for five years.

The combined company will get a shareholder-funded co-headquarters tower in state capital Richmond.

Virginia Governor Abigail ⁠Spanberger said in August she would intervene in the regulatory review of the merger, pressing for commitments on concern areas like power affordability, ⁠job protections, and clean energy investments.

Spanberger would formally ⁠become a party to the case before the Virginia State Corporation Commission, providing her with access to filings and the ability to raise questions and concerns about the transaction.

Shareholders of both companies have, however, approved the proposed USD 66.8 billion merger. The deal, awaiting regulatory approvals, is expected to close in the second half of 2027.

While Virginia-based Dominion serves the largest concentration of data centers globally, the combined entity will create the third-biggest American energy company, behind oil majors Exxon Mobil and Chevron, with an enterprise value topping the next two largest US power companies taken together.

NextEra CEO John Ketchum stated in an SEC filing, “While shareholder approval is a major accomplishment, we still have work to do as we navigate state and federal regulatory approval processes.”

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The power utility made a profit after tax of 30.3 billion rand (USD 1.9 billion) in the year ended March, compared with a restated 14.0 billion rand a year earlier, thereby registering its first annual profit in eight years.

Eskom’s revenue rose 4.1%, reflecting a 12.7% average tariff increase, although a 6.2% decline in electricity sales volumes partly offset the gain. The venture also implemented rolling blackouts on just four days during the financial year, compared with 13 days a year earlier and a record 329 days in 2024.

Power cuts have emerged as one of the headwinds ⁠that have constrained Africa’s biggest economy for more than a decade. However, the latest data from the utility suggests the phenomenon becoming much less frequent.

Outgoing Chief Financial Officer Calib Cassim mentioned that weaker electricity sales and the idling of the Mozal aluminum smelter, which has been placed under care and maintenance after failing to reach a tariff agreement with Eskom, would weigh on results in the current financial year.

The utility’s gross debt stood at 356 billion rand at the end of March 2026, up from 327.7 billion rand a year earlier.

However, Cassim stated that unpaid municipal debt has remained a headache for the state-owned utility.

Municipalities and metropolitan areas account for more than 40% of Eskom’s sales.

“Municipal debt rose 17.9% to 111.6 billion rand and could climb to ⁠358 billion rand by the 2031 financial year unless decisive action is taken,” Eskom said.

As per Cassim, Eskom’s earnings would have been around 15 billion rand higher had it collected the 15.8 billion rand owed by municipalities, as revenue from ⁠non-paying municipalities is only recognised when the utility receives the cash.

“Eskom can be in a position to execute the capital requirements without the need of government support, but you have to solve the municipal debt,” he said.

Cassim, who has spent 24 years at Eskom, apart from serving the utility’s acting Group Chief Executive for a year, will retire during the financial ⁠year ending March 2027.

He played a key role in the utility’s operational recovery and ‌return ⁠to profitability. As per the reports, the utility is looking to appoint Cassim’s replacement before the end of ⁠the 2026 calendar year.

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The governor will become a party to the case before the Virginia State Corporation Commission, giving her access to filings and the ability to raise questions and concerns ⁠about the transaction.

“They’re not sufficient yet, which is one of the reasons why I’ve chosen to intervene in the case. Because I need a lot more details. The action of actually formally intervening is an unprecedented one. As a governor, ‌I ⁠do acknowledge that,” Spanberger said, while taking note of the companies’ merger plan, that, once its completion, will form one of the world’s largest electric utilities, amid the ongoing expansion of energy-intensive data centers.

“The size and scope of this merger application are also unprecedented,” she stated further.

The deal, which is pending approvals, will create the third-biggest American energy company, behind oil majors Exxon and Chevron. The combined ⁠entity will have an enterprise value topping the next two largest domestic power companies combined.

Spanberger said she was not seeking to take the decision out of ⁠regulators’ hands, stating that “the decision to approve or deny…that authority still lies with the SCC.”

The governor also said that as a ⁠party to the proceeding, she has the “ability to take legal action once there’s a decision made.”

NextEra Energy, meanwhile, beat Wall Street estimates for its Q2 profit, driven by rising electricity demand from data centers, a trend that boosted its utility and renewable energy businesses.

NextEra and its industry peers ‌are investing billions of dollars to expand power generation and transmission as technology companies and data centers race to secure electricity.

NextEra, one of the world’s largest renewable energy developers, to further cash on the ongoing AI boom, will restart ⁠the Duane Arnold nuclear plant in Iowa, that will supply power to Google data centers.

On a post-earnings call, CEO John Ketchum said NextEra had acquired the remaining 30% stake in Duane Arnold from its cooperative partners, giving it full ownership.

However, the venture has not yet finalized the natural gas-fired power projects backed by a US-Japan initiative. These gas-based plants have a combined capacity of nearly 10 GW.

Florida Power & Light (FPL), NextEra’s regulated utility, posted a 10.2% rise in quarterly net income to USD 1.41 ⁠billion. FPL continues to see about 21 GW of hyperscaler opportunities in its pipeline, including nearly 12 GW under advanced negotiations. It expects to sign at least one agreement under its large-load tariff by the 2026 end.

NextEra Energy Resources, the renewable energy unit, reported a net income of USD 1.63 billion, up 66.2%, apart from adding 3.6 GW of storage projects, taking its backlog to ⁠about 35.1 GW.

However, the regulatory review involving the acquisition of Dominion Energy will be NextEra’s biggest test, as apart from Spanberger, the deal is also facing opposition from  American Senator Angus King, who argued it would concentrate too much market power in one company.

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“As potential demand and data center sizes both grow, so does the complexity in forecasting,” said BloombergNEF (BNEF) Senior Associate Nathalie Limandibhratha.

The analysts, while making the prediction, used two scenarios. The experiment, however, resulted in the two models differing by 42 GW in terms of estimating the US data center electricity demand by 2030. As per the BloombergNEF, the divergence only shows growing uncertainty about the scale of the data center buildout even as the trend accelerates.

A base case modeled on US data center development BNEF considers likely to materialise showed demand from the sector of 118 GW in 2030 and 194 GW by 2035, an upward revision of 52% and 83%, respectively, from the firm’s previous outlook, published in December 2025. A second forecast developed around expected AI chip deliveries found there could be 207 GW of data center demand by 2033.

“The report highlights the difficulties in modeling the new demand. BNEF underestimated installed data-center capacity in 2025. Installed capacity topped 47 GW by the end of last year, 16% higher than BNEF’s forecast,” the agency said, while publishing its report.

“We track data centers across the US, and in the last year, we’ve added about 100 GW of project capacity. It’s not only the number of data centers and new developers that are flooding the market, but it’s also the size of these data centers,” Limandibhratha said.

That 42 GW difference, as per the BNEF analysts, is more than four times the peak load of New York City, and the tally, by 2033, will grow to 63 GW.

“Driving the uncertainty are the growing size of data centers, power availability, and the extent to which developers get more efficient in their building,” BNEF said.

“When BNEF was forecasting data center demand a year ago, a 1-GW project was considered large. In our pipeline now, we have over 70 projects that are a gigawatt in size, and even some projects that are multiple gigawatts, up to 10 GW, which is really skewing the project pipeline, and kind of ballooning and leading to the upwards revision as we get more data on how the market is evolving,” Limandibhratha remarked.

US data center demand in 2025 was almost 50 GW, she said, and it’s on pace to more than double over five years.

“It’s quite significant and rapid growth,” the senior analyst noted.

“Almost all US regions ended 2025 with more data center capacity than BNEF had anticipated, with Texas accounting for the largest difference between forecast and actual build,” the agency observed.

BNEF estimated 7.4 GW of data center capacity in the Electric Reliability Council of Texas footprint by the 2025 end. Actual demand, as per the report, has now been revised to 8.9 GW. With about 16 GW of data center demand, the PJM Interconnection, out of all the American regions, had the highest power requirement in 2025.

BNEF’s base outlook is relatively conservative, its analysts said.

“Among those 2030 estimates of installed data center capacity, there is about a 100-GW range,” Limandibhratha concluded.

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HH Sheikh Ahmed bin Saeed Al Maktoum, Chairman of the Dubai Supreme Council of Energy, said the launch marked a strategic step in extending Dubai’s expertise across energy, water, sustainability and digital transformation.

“Thanks to the vision and directives of His Highness Sheikh Mohammed bin Rashid Al Maktoum, Vice President and Prime Minister of the UAE and Ruler of Dubai, Dubai has become a global model for achievement and accelerated development. Through its world-class infrastructure, particularly in the energy and water sectors, Dubai has firmly established itself as a leading international benchmark,” the official said further.

He further added that DEWA International would strengthen Dubai’s position as a global source of knowledge and technical expertise.

Saeed Mohammed Al Tayer, MD and CEO of DEWA, said the authority’s operational and financial performance had created a strong foundation for international expansion.

“At its core, DEWA embodies Dubai’s inspiring success story. For decades, DEWA has powered Dubai’s extraordinary rise, not through ambition alone, but through the highest performance and efficiency,” Al Tayer said.

DEWA currently ranks first globally across 13 key utility performance indicators and two regional benchmarks covering generation, transmission, distribution and customer service. Apart from that, the authority, in 2025, recorded revenue of AED32.8 billion, while net profit after tax reached a record AED9.06 billion.

As per the Al Tayer, the financial strength has also provided DEWA with the investment capacity and strategic flexibility required to pursue global expansion-related opportunities.

“DEWA International will develop both power and water projects using advanced technologies and will work with leading organisations around the world. The subsidiary is already identifying investment opportunities, building a project pipeline and establishing strategic partnerships intended to shape its future global presence,” the official noted.

“The new company will draw on DEWA’s experience in utility operations, infrastructure delivery, clean energy, digital transformation and sustainable development as it expands into international markets,” Al Tayer concluded.

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Global energy-related carbon emissions from the production and use of energy rose 1.1% to 35,806 million tonnes of CO₂ in 2025. About 13.3% of that increase came from the United States,” the report said.

Including emissions from the energy sector and from gas flaring and methane, global emissions rose by 1.1% to ⁠41 billion tonnes of CO₂ equivalent. Uncle Sam accounted for 36% of that increase, with total emissions growth of 3.2% on a year-on-year basis, whereas for China, the spike remained at 0.3%.

The United States’ coal consumption, in 2025, jumped 10%, reversing a shift towards cleaner fuels and helping to lift overall emissions.

“China remained the largest emitter, accounting for 31.3% of global energy-sector emissions, but its increase from 2024 was modest at 0.7%. Europe’s emissions rose by 0.5%. North America recorded the largest absolute increase, with emissions rising by nearly 3% from 2024 to 152.3 million tonnes, bucking a 10-year trend of falling emissions,” the Energy Institute study said.

On a per ‌capita ⁠basis, emissions from the American mainland were nearly double those of China at 15.36 tonnes of CO₂ per person, based on Reuters calculations taking the latest population data for 2025 from the US Census Bureau and National Bureau of Statistics of China.

Global energy demand, on the other hand, has continued to rise. As per the study, total energy supply increased 1.7% ⁠in 2025, with renewables making the biggest contribution. Renewable power generation climbed 9.1%, led by a 30% surge in solar.

“Electricity demand rose faster than supply, increasing 3% year-on-year, driven by electric vehicles, data centres and ⁠artificial intelligence (AI). Global oil consumption rose 1.3% in 2025 to 103 million barrels per day, compared with a 1.1% increase in 2024, while production grew 3.5%,” the Energy Institute noted.

In China, gasoline and diesel use declined ⁠in 2025, extending a trend seen in 2024.

“Gas demand growth was concentrated in Europe, the Middle East and North America, with Europe and India relying on imports for nearly half of their supply,” the report concluded.

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The market was valued at USD 5.1 billion in 2025 and is expected to reach USD 22.2 billion by 2033, expanding at a compound annual growth rate (CAGR) of 20.4% from 2026 to 2033.

“The growing convergence of artificial intelligence and energy infrastructure is reshaping how electricity is generated, distributed, stored, and consumed. As energy systems become more decentralized and data-intensive, AI is emerging as a critical enabler of predictive analytics, demand forecasting, asset optimization, and real-time operational intelligence. The increasing deployment of smart meters, intelligent sensors, connected energy assets, and advanced grid management systems has created unprecedented volumes of operational data. Energy providers are leveraging AI-powered platforms to transform this data into actionable insights, enabling faster decision-making, lower maintenance costs, and improved service reliability,” Grand View Research noted.

According to the agency, the energy and utility markets are being driven by the rising digitalization of energy infrastructure and the growing need for efficient management of generation, transmission, and distribution networks. AI solutions are helping utilities identify equipment failures before they occur, monitor grid performance in real time, and automate complex operational processes.

“These capabilities are becoming increasingly important as energy providers face growing pressure to enhance reliability while supporting the transition toward cleaner and more sustainable energy systems,” the study noted further.

One of the most significant growth drivers for AI in the energy market is the rapid expansion of renewable energy generation. Solar and wind resources introduce variability into power systems, creating new challenges for grid operators responsible for balancing supply and demand. Artificial intelligence technologies enable advanced forecasting models that analyze weather patterns, historical generation trends, and real-time operational conditions to improve renewable energy output predictions and optimize dispatch decisions. These capabilities allow utilities and energy companies to better manage fluctuating renewable generation while maintaining grid stability,” Grand View Research said.

The report also highlights that renewable energy management accounted for 33.0% of the global market in 2025, making it the largest application segment. Growing investments in renewable power infrastructure, battery storage systems, and distributed energy resources continue to strengthen demand for AI-powered energy management platforms that are capable of enhancing grid stability and maximizing asset performance.

Beyond renewable energy management, AI is also gaining significant traction across predictive maintenance, energy trading optimization, grid automation, and operational safety applications.

“Energy companies are increasingly utilizing machine learning algorithms to identify anomalies, reduce downtime, and improve maintenance planning for critical infrastructure assets. AI-powered predictive maintenance solutions help operators monitor equipment health in real time, minimizing costly outages and extending asset lifecycles. The growing use of advanced analytics also enables utilities to optimize energy distribution networks, improve customer service, and enhance overall operational efficiency,” the agency remarked.

Along with the evolution of AI capabilities, robotics is also emerging as one of the fastest-growing application areas within the energy sector. As per Grand View Research, AI-enabled robots and drones are increasingly being deployed to inspect power plants, transmission networks, pipelines, wind farms, and solar facilities. These technologies are providing continuous monitoring capabilities while reducing risks associated with hazardous or remote-site inspections.

According to Grand View Research, the robotics segment will expand at a CAGR (Compound Annual Growth Rate) of 24.1% through 2033, reflecting growing industry investments in automation technologies designed to improve safety, operational visibility, and infrastructure management.

“From a technology perspective, software and platform-based solutions continue to dominate industry spending. The report indicates that the solutions segment accounted for 69.2% of total market revenue in 2025, reflecting widespread adoption of AI-powered applications supporting forecasting, analytics, grid optimization, and operational automation. Organizations across the energy value chain are investing in intelligent software platforms capable of delivering actionable insights from large and complex datasets,” the agency noted.

Meanwhile, the services segment is expected to grow at a CAGR of 22.0% during the forecast period (from 2026 to 2033), driven by tailwinds like increasing demand for consulting, implementation, integration, training, and support services associated with AI deployments.

“Regionally, North America accounted for 38.2% of global revenue in 2025, maintaining its position as the largest regional market for AI in energy applications. Strong investments in digital transformation initiatives, advanced utility infrastructure, smart grid technologies, and AI innovation ecosystems continue to support market growth throughout the region. The United States remains a key contributor to market expansion, with increasing adoption of intelligent energy management systems, predictive maintenance solutions, and renewable energy optimization technologies. According to the report, the US market is projected to expand at a CAGR exceeding 21.8% through 2033,” Grand View Research mentioned.

“Industry experts note that the growing intersection between AI adoption and energy demand is becoming an increasingly important strategic issue. As AI workloads expand globally, data centers are consuming larger amounts of electricity, creating additional requirements for grid modernization, power management optimization, and infrastructure resilience. This trend is expected to accelerate investments in intelligent energy technologies capable of improving efficiency and supporting future electricity demand growth,” it added further.

Utilities and energy providers are increasingly exploring AI-powered solutions to address both operational challenges and long-term sustainability objectives. The competitive landscape also includes a mix of global technology leaders, industrial automation providers, and specialized AI software companies focused on transforming energy operations through advanced analytics and machine learning technologies. Companies like Siemens AG, ABB, General Electric, C3.ai, Atos SE, Flex, AppOrchid, Uptake Technologies, Origami Energy, Alpiq, and SmartCloud are becoming part of this growing yet competitive ecosystem.

“These companies are investing heavily in product innovation, strategic partnerships, and digital energy solutions designed to improve grid reliability, optimize asset performance, and support the transition toward cleaner energy systems,” Grand View Research concluded.

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“In 2025, the bank reported an 8:1 ratio in favour of renewable energy financing compared to fossil fuel investment, highlighting a structural shift in Africa’s energy landscape. The trend is further reflected in the growing focus of utilities and energy companies on renewable development, including new initiatives from traditionally coal-reliant utility operators such as Eskom,” Standard Bank noted.

As part of its broader sustainability strategy, Standard Bank has committed to mobilising R100 billion in green finance by 2028, with the aim of supporting the continent’s energy transition and electricity access expansion.

Noting that nearly 600 million people in Africa still lack reliable access to power, Standard Bank’s head of sustainability, Boitumelo Sethlatswe, while interacting with Bizcommunity.com, underscored the scale of investment required in generation, transmission and supporting the energy and utility infrastructure.

“The shift toward renewables reflects a structural change in how energy systems are being developed across Africa, with clean energy becoming central to capacity expansion rather than a marginal addition,” Sethlatswe stated further, while noting that the transition to renewables is not solely focused on emissions reduction but also on improving energy access, supporting inclusive economic growth and building resilience against climate and economic shocks.

Sasha Cook, Standard Bank’s head of sustainable finance for corporate and investment banking, said capital flows are increasingly defining the pace of Africa’s energy transition, with strong fundamentals and improving project economics driving investment into renewables.

As per Standard Bank, it had already mobilised 62% of its R450 billion sustainable finance target by the 2025-end, including R47.1 billion in green finance during the year alone.

“Recent transactions include financing large-scale solar and wind projects in South Africa, such as the 506 MW Khauta South and West Solar projects, the 465 MW Ummbila Emoyeni wind portfolio, and the 400 MW Overberg Wind Farm,” the bank stated further.

The bank, also involved in supporting integrated energy ecosystem-related elements like hybrid energy systems, storage solutions and energy trading structures, remarked, “Renewable energy investment is creating new industrial value chains and supporting wider economic development across the continent, although regulatory and infrastructure constraints continue to limit deployment in some markets. Addressing these barriers will require coordinated action between governments, financiers and private sector players as Africa scales up its clean energy capacity.”

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As per Engie’s Spanish unit (Engie Espana), the solar project will be built alongside the 790.68-MW Castelnou plant in the province of Teruel and will include more than 284,000 photovoltaic panels spread across 360 hectares.

“The hybridization scheme will optimize the complementarity between gas-fired and renewable generation, helping to integrate more solar power into the electricity system while maintaining flexible generation capacity to support grid stability,” the company remarked.

Engie Espana announced the plans as it marked the 20th anniversary of the Castelnou plant, which entered operation in 2006 and is the only combined-cycle gas plant in Teruel province.

“The facility, equipped with two gas turbines and one steam turbine supplied by Mitsubishi, operates with an efficiency of more than 55%. The addition of the solar farm is part of the site’s technological evolution and supports its strategy of reducing emissions while maintaining security of electricity supply,” Engie Espana said.

Talking about Engie’s renewable energy portfolio in the Aragon region, the company has assets including the 194-MW Goya wind complex, which consists of seven wind farms in Zaragoza province, and the Phoenix project, a group of ten wind farms with more than 340 MW of installed capacity.

However, Engie is expanding its renewable portfolio in other parts of the European country as well. In April this year, the company acquired 278 MW/1,112 MWh of battery energy storage system (BESS) projects under development in Andalusia, southern Spain.

It bought the projects from Spanish developer Rolwind Renovables, which has been working on them since 2022. The acquired package includes the 200-MW/800-MWh Palmosilla project in Tarifa and the 78-MW/312-MWh Cerrillo project in Alora. While these two projects represent the largest standalone battery storage developments currently in progress in Spain, they will also be including synchronous condensers to enhance grid inertia and improve system reliability.

Construction is scheduled to begin in the first half of 2027, with commissioning targeted for 2028. Total investment, on the other hand, is expected to exceed EUR 240 million (USD 280.4 million) between 2026 and 2028. The projects have also received EUR 70 million in grants from the European Regional Development Fund.

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Located in the Spanish municipality of Belvis de Monroy, the new installation represents a significant step forward in the utility giant’s strategy to enhance its energy storage capabilities, which will, in the words of CEO Mario Ruiz-Tagle, “support new demand requiring firm capacity and accelerate the electrification of the Spanish economy.”

The newly installed facility at the Belvis de Monroy consists of two LFP lithium-ion battery modules of roughly 60 MWh each, integrated with the existing solar plants so the site can store excess photovoltaic production and supply it to the system during periods of higher demand—an increasingly essential capability as renewable penetration in Spain continues to expand.

The inauguration was attended by regional and national representatives, including the regional minister of industry, energy, science and territory of Extremadura, Mercedes Moran Alvarez; the government delegate in the region, Jose Luis Quintana; and Julio Castro, CEO of Iberdrola Energia Sostenible Espana, alongside mayors and local officials of Belvis de Monroy.

As per Ruiz-Tagle, projects like Campo Aranuelo are pioneering efforts within the Spanish energy sector and demonstrate how electrification can progress at a steady and reliable pace. He also noted that Iberdrola has long been committed to energy storage and currently operates the vast majority of its battery storage capacity in Spain, with nearly 200 MW in service.

“This new installation constitutes a top-tier investment for Extremadura, reinforcing its position as an emerging energy hub that brings together generation capacity, technological innovation and system stability. Energy storage is crucial for unlocking the region’s exceptional photovoltaic potential and ensuring that the energy transition translates into industrial development, employment and new opportunities for local communities,” Mercedes Moran Alvarez said.

Iberdrola’s project received support from the Institute for Energy Diversification and Saving (IDAE) through its grant programme for innovative storage solutions paired with renewable facilities under the PERTE ERHA framework. With the commissioning of this new battery system, Iberdrola Espana now strengthens Extremadura’s standing as a leader in renewable innovation and storage within the European country.

The Campo Aranuelo I and II photovoltaic plants consist of two photovoltaic plants (50 MWp), a transformer substation and a high-voltage evacuation line. It occupies an area of 200 hectares and has the capacity to produce around 167 GWh renewable energy per year. The project has a total of 256,590 photovoltaic modules installed on a fixed structure, 52 inverters and 18 transformers of 4,920 and 3,280 kVAs.

The energy generated by the photovoltaic panels gets transported by the internal grid at 30 kV before being transformed to 132 kV at the Photovoltaic Plant Almaraz substation. It is then evacuated to the distribution substation via a high-voltage line, comprising a 2.6 km overhead section and a 0.5 km underground section.

CEMOSA, the leading Spanish engineering consultancy and quality control company specialising in transport infrastructure and civil engineering, was awarded the technical assistance-related responsibilities by IBERDROLA. Under the arrangement, CEMOSA helped the 125-year-old Spanish multinational electric utility company in the construction of the two photovoltaic plants, the transformer substation and the high-voltage evacuation line.

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