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TotalEnergies has struck another strategic blow in the British clean-energy market, buying a late-stage development portfolio totalling 435 MW from UK developer Low Carbon. The package comprises eight utility-scale solar farms with a combined 350 MW of generation capacity plus two co-located battery-energy-storage systems (BESS) adding 85 MW of flexible power, all sited across southern England. Although financial terms were not disclosed, the French group said the assets will slot directly into its Integrated Power business and help balance renewables output with dispatchable storage. Grid-connection dates for the first projects fall in 2026-27, aligning with the UK’s push for a fully decarbonised power sector by 2035 and the company’s own timetable to recycle capital quickly once construction is complete. Why the deal matters Strengthening the UK footprint. TotalEnergies already co-owns the 1.1-GW Seagreen offshore wind park and holds stakes in several floating and fixed-bottom wind projects. The newly acquired solar-plus-storage capacity diversifies that mix, giving the company its first meaningful ground-mounted PV foothold in Britain. Firming up flexible supply. Battery storage is increasingly central to TotalEnergies’ “clean-firm” power model. By pairing 85 MW of BESS with new PV, the firm can shift midday solar surpluses into evening peak periods and participate in National Grid’s balancing markets. Acceleration toward global targets. The transaction supports the major’s roadmap to reach 35 GW of gross renewable capacity by the end of 2025 and to produce 100 TWh of clean electricity annually by 2030.  Capital-light growth. Buying projects at an advanced development stage allows TotalEnergies to step in just before the highest-value construction phase while still capturing long-term offtake upside. The company has recycled more than USD 4 billion of capital through similar build-sell-operate structures since 2022, boosting project IRRs in its electricity segment. Nicolas Piau, Senior Vice-President Renewables for Northern Europe, called the deal “a perfect illustration of our integrated power strategy: develop, build, operate and, when relevant, divest minority stakes to recycle capital while continuing to operate the assets.” For Low Carbon, the sale frees up resources for its 20-GW global pipeline and validates its approach of de-risking assets before hand-off to long-term operators. Chief executive Roy Bedlow said the proceeds will be “re-invested into fresh UK and international projects that accelerate the transition to net-zero.” As Britain races to triple solar capacity to 70 GW by 2035, transactions like this underscore how fast-moving developers and deep-pocketed strategics are teaming up to turn planning permissions into shovel-ready projects—and, ultimately, reliable clean power on the grid.

be able to create clean power at its sites. The arrangement was signed with TotalEnergies Renewables Distributed Generation Center East & Africa, which creates

TotalEnergies SE signed a 10-year power purchase agreement to supply renewable electricity to Data4’s data centers in Spain. The deal will deliver clean power to the European operator’s Spanish sites; financial terms, volumes and start date were not disclosed.The agreement advances Data4’s decarbonization goals and hedges energy costs, while supporting TotalEnergies’ expansion in Iberian renewable power marketing. It underscores rising demand from data center operators for long-term green PPAs in Spain’s fast-growing renewables market. Will the PPA source new-build Spanish solar capacity, with storage and Guarantees of Origin? New-build solar: Not disclosed. Tenor and positioning suggest it could underpin new-build Spanish PV, but confirmation from the parties is needed. Storage: Not announced. Most Spanish PPAs still exclude co-located batteries; unless specified, assume no storage. Hybrid PV+storage is growing but remains the exception. Guarantees of Origin: Likely bundled GdOs via Spain’s CNMC and the European Energy Certificate System; verify whether annual or granular (hourly) certificates are included. Additionality: If tied to new-build PV, the deal would provide additionality; otherwise it may rely on an existing portfolio. Ask for COD-linked milestones. Delivery model: Could be physical sleeving through a retail arm or a virtual/financial PPA with balancing; shape/basis risk terms will determine firmness of supply. Timelines: If new-build, start could align with a 2025–2027 COD window; sourcing from existing assets could commence earlier. Regulatory context: Spain enables GdOs with pilots for hourly issuance; data centers increasingly request 24/7-matched certificates—clarify if this is part of the deal. Storage economics: With no broad capacity market, storage is usually financed via ancillary/arbitrage revenues; inclusion in a PPA would require separate terms—seek MW/MWh specs if present. Curtailment: Midday PV curtailment risk is material; PPAs may include curtailment allocation—ask how this is handled and whether batteries are used to mitigate. What to confirm: Asset status (new-build vs existing), project locations, start date and volumes, GdO structure (bundled, hourly vs annual), storage inclusion and specs, delivery (sleeved vs virtual), and commissioning milestones.

impact on the structure of the market, a statement claimed on Wednesday. TotalEnergies late last year introduced that it has made a decision to exercise its

as well as the local director for the Middle East as well as North Africa at TotalEnergies, Libya's state-owned electricity company stated in a quick statement. The

Energy, a German battery developer majority owned by TotalEnergies, has started installing three battery energy storage systems (BESS) with a combined capacity of 98

complex located in the district of Citeureup, Bogor city, West Java district. TotalEnergies financed, mounted and now operates the solar system consisted of greater than

TotalEnergies has struck a deal to sell a 50% stake in a 1.4-GW solar portfolio across North America to insurance vehicles and accounts managed by KKR, the latest example of the “partnership model” that has come to dominate large-scale renewables finance. The oil-and-gas major keeps a significant share and operational role, while bringing in long-duration capital eager for stable, inflation-linked cash flows. For institutional buyers, the appeal is clear: contracted generation, standardized technology, and mature interconnections that limit construction risk. For TotalEnergies, the sell-down crystallizes development value, recycles capital into new pipelines, and retains strategic control over asset performance and expansion options, including future battery retrofits at interconnection points. Structurally, these transactions are hybrids of M&A and project finance. Governance frameworks lock in budgeting and capex oversight; offtake profiles are tuned to each market—utility PPAs, corporate PPAs, and selective merchant slices where spreads justify exposure. With grid operators increasingly valuing flexibility, many assets are being engineered with reserved space and transformer headroom for co-located storage that can shift midday solar into evening peaks and deliver ancillary services such as fast frequency response. Operationally, a unified SCADA and analytics stack across the fleet will be central to delivering the yield underwriting expects. Availability targets, cleaning cycles, vegetative management, and curtailment response need to be coordinated across sites to capture marginal gains that compound over time. Strategically, the transaction underscores how supermajors are reshaping their power arms—building, partially selling, and operating at scale to keep growth optionality without over-levering the balance sheet. For KKR’s insurance capital, it’s another anchor in a portfolio designed to meet long-term liabilities with real-asset income. For the market, it’s a reminder that the deepest pools of money still favor durable, grid-integrated megawatts over one-off trophy buys.

TotalEnergies and Holcim inaugurated a 31‑MW floating solar park on a chalk quarry lake in Obourg, Hainaut, Belgium, billed as Europe’s largest floating PV site dedicated to self‑consumption. The array is expected to produce about 30 GWh annually, power that will be consumed directly by Holcim’s operations, displacing grid and fossil-linked electricity.For Holcim, the project advances a target to cut Scope 1 and 2 emissions 25% by 2030 through on‑site renewables. TotalEnergies used launch to underline growth plans: more than 34 GW of gross renewable capacity by early 2026 and over 100 TWh of net electricity output by 2030. How does Belgium’s largest self-consumption floating PV advance Holcim and TotalEnergies’ goals? Policy watch: track evolving grid interconnection reforms aimed at shrinking multi‑year queues and aligning capacity accreditation with inverter-based resources Financing lens: rising interest rates are reshaping PPA prices and shifting developer focus toward projects with contracted offtake and tax-credit transferability Supply chain: diversification away from single‑region dependence is accelerating; domestic content bonuses are nudging new component manufacturing footprints Transmission: multi-state cost allocation remains the chokepoint; advanced conductor uprates and dynamic line ratings offer faster near-term relief than new lines Storage pivot: hybrid solar-plus-storage is becoming the default in congestion-prone markets to capture evening peaks and mitigate curtailment Long-duration storage: iron-air, flow batteries, and thermal storage are moving from pilots to early procurement to address multi-day reliability needs Grid-forming inverters: early deployments are proving voltage and frequency support, a prerequisite for higher shares of inverter-based generation Market design: ancillary service reforms are opening new revenue for batteries; fast frequency response products are proliferating Curtailment management: co-optimization software, flexible PPAs, and dynamic charging of EV fleets are reducing lost generation hours Corporate procurement: shorter PPA tenors and 24/7 carbon-matching contracts are replacing traditional “anytime megawatt-hour” deals Hydrogen crossover: surplus renewables are being paired with electrolyzers near industrial loads; offtake certainty remains the gating factor Offshore wind: supply inflation and turbine scaling risks are prompting contract renegotiations; local port investments are becoming decisive Distributed energy: virtual power plants are aggregating DERs to bid into capacity markets, with performance guarantees tightening Community solar: subscriber acquisition costs are falling with utility on-bill credits and standardized contracts, expanding low-income access Agri-voltaics: elevated racking and crop-compatible spacing are improving rural acceptance while diversifying farm revenue Environmental due diligence: cumulative impacts on wildlife and water are steering developers toward low-conflict siting and adaptive curtailment regimes End-of-life: blade recycling capacity is scaling via mechanical and chemical processes; second-life strategies are factoring into financing Workforce: rapid growth is intensifying demand for electricians and high-voltage technicians; apprenticeship and local hiring mandates shape bids Resilience: microgrids with black-start capable inverters are hardening critical infrastructure against wildfire and storm outages Emerging markets: currency risk hedges and blended finance are unlocking utility-scale solar and wind where sovereign risk is elevated Data and AI: predictive O&M and inverter fault analytics are lifting capacity factors and reducing unplanned downtime EV integration: managed charging and vehicle-to-grid pilots are flattening evening peaks and monetizing grid services Geothermal and tidal: enhanced geothermal systems and tidal stream pilots provide firm, low-variability complements to wind and solar Permitting reform: one-stop siting authorities and time-bound reviews are gaining traction to de-bottleneck project timelines Insurance: extreme weather loss models are raising premiums; hardened racking, tracker stow strategies, and site selection mitigate exposure Equity and engagement: early, revenue-sharing partnerships with Indigenous and local communities are becoming standard for social license International auctions: pay-as-bid vs. uniform pricing and indexation rules are materially affecting bid aggressiveness and project viability Grid flexibility: demand response from data centers and heat pumps is being procured alongside supply to meet winter peaks in colder regions Circular economy: mandates for recycled content in modules and batteries are entering tenders, influencing procurement choices Metrics shift: investors are prioritizing emissions-abated per dollar, not just megawatts installed, to compare cross-technology impact

TotalEnergies will certainly mount a 540-kWp solar photovoltaic or pv (PV) array on top of a Beiersdorf manufacturing site to generate some 830 MWh of electricity annually. The outcome of the system is anticipated to fulfill 20% of the plant's needs. Conclusion of the project is prepared for June 2022. "This project will substantially lower the carbon footprint in our manufacturing centers, making our facilities environmentally friendly. In addition, it additionally offers significant cost savings in the long term," said Dwi Mudriah, Manufacturing Centre Director of Beiersdorf Indonesia.

TotalEnergies has closed a deal to sell a 50% interest in a 270-MW portfolio of French wind and solar assets to Eiffel Investment Group, a transaction that exemplifies the partnership model now standard in European renewables. The oil-and-gas major keeps skin in the game and operational control, while bringing in a specialist investor with long-dated capital to share risk and accelerate growth. The portfolio mix matters. Combining solar with onshore wind delivers a smoother output profile over the year, reducing volatility and curtailment risk. Unified SCADA and analytics across the fleet enable performance tuning—cleaning cycles, inverter setpoints, and curtailment responses—that can lift yield by meaningful basis points. Many sites are designed with future flexibility in mind: preserved interconnection headroom and pad space for batteries that can shift energy into evening peaks and provide fast frequency response. Financially, the structure crystallizes development value while lowering the cost of capital for new projects. Eiffel gains contracted, grid-integrated assets with predictable cash flows; TotalEnergies frees balance-sheet capacity to pursue additional builds and repowerings without fully exiting operating sites. Governance frameworks typically lock in budget oversight, capex thresholds, and ESG reporting—elements that institutional LPs increasingly require. For host communities, nothing changes day-to-day: plants keep producing, local tax receipts continue, and biodiversity plans remain in force. Over time, the partnership can fund O&M upgrades and, where justified, battery retrofits that turn renewables from energy-only resources into flexible capacity. Strategically, the deal underlines how supermajors and infrastructure funds are reshaping Europe’s power sector: build at scale, share ownership, and keep optionality to adapt assets as market designs evolve. With the transition’s next bottlenecks—connection capacity and flexibility—coming into focus, portfolios that blend technologies and investors are best placed to deliver reliable, affordable clean power.

23 assets are solar with a capacity of 168 and 6 are wind completing 67 MW. TotalEnergies will remain to give asset administration as well as operation as well as

Air Liquide operates the oxygen production facility. To meet their commitment, TotalEnergies and Mulilo will develop a 140-MW wind farm as well as a 120-MW solar park,

to be supplied over the next five years. The business-to-business JV, called TotalEnergies Eneos Renewables Distributed Generation Asia Pte Ltd, will start operations

TotalEnergies has commissioned a 59‑MWp solar farm in Toledo, Castilla‑La Mancha, expanding its footprint. The site uses bifacial modules on single‑axis trackers, string inverters and a controller meeting grid codes (reactive support, ride‑through, ramp‑rate, telemetry). O&M emphasizes string‑level SCADA, IV‑curve tracing and drone thermography. The substation is battery‑ready.Commercially, the plant can sell via corporate PPAs, hedges or blended strategies. Sited near existing infrastructure, it limits lines and interconnection risk. As solar penetration lifts midday supply and saps capture prices, future storage can shift output to evenings and earn ancillary revenues. Local communities gain construction jobs, taxes and technical roles. How will storage deployment and PPAs mitigate capture price erosion in Castilla-La Mancha? Co-located batteries shift midday surplus into evening peaks, raising realized prices versus cannibalized hours. Storage trims curtailment during local congestion, converting otherwise spilled MWh into sellable peak energy. Revenue stacking: day-ahead/intraday arbitrage plus regulation and balancing services to REE (aFRR/mFRR, fast frequency response), buffering low solar capture periods. Firming and ramping from batteries support shaped or baseload-style PPAs, earning premiums over pay-as-produced contracts. Hybrid solar+storage PPAs with firm-energy or availability guarantees reduce profile risk and improve pricing. Floors/collars and index-plus-premium PPAs cap downside when capture prices slump while preserving upside. Longer-tenor corporate PPAs in central Spain with peak or block delivery profiles align with industrial load, stabilizing cash flows. Co-optimization around financial hedges (OMIP futures, CfD-style structures) plus storage minimizes imbalance costs and protects capture. Spanish hybridization rules let storage share interconnection, lowering grid fees/losses and improving netbacks despite cannibalization. Portfolio dispatch across multiple plants and a battery delivers flatter supply to PPA buyers, cutting cannibalization risk premia. Flexibility services to TSO/DSOs (congestion relief, voltage support) provide payments less correlated with solar prices. Smart charging during zero/negative-price intervals widens arbitrage spreads, lifting average revenues. Multi-hour batteries reliably target CLM’s evening peaks in high-insolation seasons, boosting capture. Municipal/community PPAs with predictable tariffs insulate projects from market dips and enhance bankability.