Oil Majors Double Profits in Europe in Latest Quarter

cleantechnica.com Aug 18, 2026

Oil Majors Double Profits in Europe in Latest Quarter

Curated by Shubham · TechCapsules · Aug 18, 2026

AI-summarised brief · reviewed before publication

Oil majors reported €7.5 billion in excess profits in the EU during the first half of 2026, according to Transport & Environment. Six companies—BP, Shell, Eni, Orlen, Repsol, and OMV—more than doubled EU profits in Q2 compared to the same period last year, driven by Middle East volatility. T&E urges a permanent windfall tax on these profits, citing that 42 % of the €17.9 billion global excess profit was EU‑attributed. The analysis uses country‑by‑country revenue data to allocate group profits to member states, with Poland, Spain, Germany and France topping the list.

💡 Why It Matters

· The proposed tax could redirect billions from oil giants to subsidize electric vehicle adoption, potentially easing fuel price shocks for European motorists.

Read full article on cleantechnica.com

Germany BESS market in strong position but policy questions on grid fees,…

Germany’s grid‑scale battery market remains robust, with projects growing in size and duration and new revenue streams emerging. Experts Anselm Eicke and Philipp Hesel highlighted that batteries currently profit from day‑ahead market spreads, while future gains could come from dynamic grid fees and a forthcoming capacity market. Policy uncertainties persist over flexible connection agreements, network charges, and the implementation of dynamic grid fees, which BNetzA has slated for 2032 but may face opposition. The first German capacity‑market auction, scheduled for next month, is unlikely to include batteries in its initial 9 GW tenders, though a 2 GW duration‑agnostic round next year may open the door for storage assets.

💡 The debate over dynamic grid fees and capacity‑market inclusion will shape the profitability of Germany’s expanding battery sector, determining whether storage can compete with traditional gas plants in the country’s critical reliability market.

cleantechnica.com · Aug 19

Duke’s New Energy Plan for Data Centers Requires Consumer Protections Now

Duke Energy unveiled a new long‑range plan that adds two gas plants and extends coal operations to accommodate projected data‑center demand, citing 8,000 MW from 43 large customers and an additional 6,000 MW in early development. The plan follows a decline in residential and retail growth, prompting the Sierra Club to call for consumer protections. The utility’s strategy prioritizes fossil fuels over solar and battery storage, sparking criticism from local environmental groups and regulators.

💡 The plan shifts investment toward polluting infrastructure, potentially raising costs for ordinary consumers while limiting clean‑energy progress. It forces regulators to decide whether data‑center demand can justify continued reliance on coal and gas.

energy-storage.news · Aug 19

Enel starts building 100MW grid-forming BESS at Chile solar PV plant

Enel Green Power Chile has begun construction of a 100 MW grid‑forming battery energy storage system (BESS) at the Finis Terrae solar PV plant in Antofagasta. The battery, integrated with the existing solar park, will deliver voltage and frequency regulation for Chile’s National Electric System. It is Enel’s sixth large‑scale BESS in the country, bringing the firm’s total storage capacity there to 730 MW. The project joins other Enel assets under development, including the 205 MW Las Salinas and 94 MW Azabache batteries, while three earlier installations – La Cabana (34 MW), Don Humberto (67 MW) and El Manzano (67 MW) – are already operating. Chile leads Latin America in grid‑scale storage, using BESS to curb solar curtailment and stabilize prices.

💡 By adding grid‑forming capability, the new battery turns intermittent solar output into reliable, dispatchable power, directly addressing Chile’s chronic solar curtailment and price volatility.

tribuneonlineng.com · Aug 19

From megawatts to prosperity: Rural electrification in the age of AI

In 2026, artificial‑intelligence firms are confronting a critical bottleneck: reliable, high‑capacity electricity. While earlier AI debates focused on chips and data, the International Energy Agency now projects global data‑centre power use to hit about 945 TWh by 2030—double today’s level and growing 15 % annually, outpacing overall electricity demand four‑fold. Major tech companies are responding by acting like utilities, securing nuclear and gas generation, buying power‑grid assets, and siting new data centres where power is abundant. The shift, dubbed the “Age of Electricity,” promises a 50 % annual rise in global electricity demand from 2026 to 2030, driven by data‑centres, electrified cooling, manufacturing and electric mobility. In Nigeria, the surge reframes electricity from a social service to a cornerstone of economic competitiveness, prompting firms such as REA and RAMCO to rethink investment strategies. Elon Musk’s xAI, despite rumors of a nuclear purchase being unfounded, has built its own generation capacity, deploying gas turbines in Tennessee and committing over $20 billion to a 2 GW data‑centre in Southaven, Mississippi.

💡 The race to secure power will dictate which AI players can scale, reshaping global tech leadership and forcing emerging economies to prioritize energy infrastructure as a competitive asset.

cleantechnica.com · Aug 19

OCTA Is Spending Again On Hydrogen Because The Fuel Chain Failed

The Orange County Transportation Authority is allocating $27.6 million for new hydrogen infrastructure to support expanding its fuel-cell bus fleet from ten to fifty vehicles. This expenditure follows the collapse of a commercial agreement with Air Products, which removed leased equipment from the Santa Ana depot in January 2026. Consequently, the existing station became unusable, causing a 95% drop in hydrogen bus mileage from 2024 to 2025. While OCTA operates battery-electric buses with reliable, cheaper charging infrastructure, it continues investing heavily in hydrogen. The new Garden Grove contract includes design, construction, supply, and maintenance, pushing total refueling spending over $100 million. The agency aims to restore depot capability and add redundancy. Critics argue this represents a strategic failure, given the proven reliability of electric alternatives and the complex, specialized nature of hydrogen supply chains. OCTA’s experience highlights the risks of committing to hydrogen fleets without securing durable, affordable fuel pathways for the vehicles' full service life.

💡 OCTA’s continued investment despite a broken supply chain exposes the hidden fragility of hydrogen transit infrastructure compared to established electric networks. This case study warns other agencies that vehicle procurement is meaningless without a guaranteed, long-term fuel delivery system.

reneweconomy.com.au · Aug 19

“We are still in early days:” World’s biggest battery buyer says costs…

Brookfield Renewables CEO Connor Teskey stated that grid-scale battery storage costs have declined significantly over the past 24 months, with further reductions expected as supply chains scale and technology improves. As the world’s largest battery equipment buyer, Brookfield reported substantial growth, acquiring North American platform Aypa for approximately $US3 billion. The company currently operates or constructs 3,000 megawatts of storage, with 3,500 megawatts under contract and 20 gigawatts in its pipeline. Teskey acknowledged short-term input cost variations but emphasized long-term downward trends in the levelized cost of energy. This trajectory enhances the bankability of renewable projects by enabling efficient energy storage. Consequently, battery storage is shifting from short-term applications to standard eight-hour durations, challenging competitors like pumped hydro. Brookfield identifies batteries as its fastest-growing technology, integrating them with new and existing wind and solar assets globally.

💡 Declining storage costs transform intermittent renewables into reliable baseload power, directly undermining the economic viability of legacy thermal plants. This shift accelerates the global energy transition by making hybrid solar and wind projects financially robust against market price volatility.