TA Realty and its data center development arm, TA Digital Group, have completed the sale of two hyperscale data center buildings totaling 745,000 square feet and 165MW of IT load capacity in Leesburg, Virginia. The facilities mark its first two completed and fully leased buildings within a planned five-building, 450MW hyperscale campus designed for a single hyperscale cloud tenant.
“This sale is a significant milestone for TA Realty and TADG,” commented Allison O’Rourke, Partner at TA Realty. “It reflects our strategy of developing build-to-suit facilities for hyperscale customers in Tier 1 U.S. markets and monetizing assets upon stabilization. Northern Virginia is the premier global data center market, and the completion and sale of these initial buildings demonstrates the strength of our development and execution capabilities.”
Located in the heart of Loudoun County’s “Data Center Alley,” this sale reflects TA Realty’s execution of a build-to-suit hyperscale campus in Northern Virginia, the world’s largest data center market. The Leesburg campus has been purpose-built to meet the increasing demand from hyperscale cloud operators for scalable power and connectivity in a Tier 1 market.
In addition to its core development work, TA Realty’s ability to deliver a project of this scale reflects deep coordination with local utilities and regional infrastructure partners. “Being able to assemble the land to support a development of this scale, which also included partnering with some of the local utilities to add additional infrastructure that will not only support this project but provide for growth in the surrounding area, is also part of our strategy in these Tier 1 markets,” said Tim Shaheen, Partner at TA Realty and Chief Development Officer at TADG. “The scale of this campus enabled the delivery of two independent substations to support grid power, providing a level of redundancy and capacity that is increasingly difficult to achieve in core markets.”
TA Realty has established a scaled data center platform that includes more than 12 projects owned or controlled across its investment vehicles, representing nearly 3GW of power capacity. Based in Ashburn, Virginia, the center of global interconnectivity, TA Digital Group oversees development and construction activity across the platform. Alongside its Northern Virginia portfolio, the company’s data center assets also include strategic developments in Chicago and Atlanta, with plans for continued expansion.
As data-heavy workloads and AI-driven infrastructure continue to shape hyperscale demand, TA Realty’s latest sale highlights the firm’s disciplined approach to value creation: designing, developing, and stabilizing mission-critical campuses that contribute to the strength and scalability of the nation’s digital backbone.
Spain installed 1.14 GW of solar capacity for self-consumption in 2025, lifting cumulative capacity to 9.3 GW, as residential and commercial installations declined while industrial and off-grid segments showed greater resilience, according to data from the Spanish Photovoltaic Union.
Solar self-consumption capacity in Spain reached a cumulative 9.3 GW in 2025, according to data from the Spanish Photovoltaic Union (UNEF).
Spain added 1,139 MW of new self-consumption capacity during the year, representing a 3.7% slowdown compared with 2024. UNEF said the deceleration signals a phase of market stabilization following several years of rapid growth.
The residential segment accounted for 229 MW across 36,330 new installations, a year-on-year decline of 17%. UNEF attributed the contraction to the phase-out of tax incentives linked to energy-efficient home renovations and lower compensation for surplus electricity exported to the grid under deregulated market contracts.
UNEF said falling surplus compensation prices are reducing the attractiveness of oversized systems designed primarily for grid injection. As a result, demand is shifting toward installations optimized for instantaneous self-consumption. The association is calling for revisions to the simplified regulated compensation mechanism to enable broader settlement of surplus energy and improve economic signals for small-scale systems.
The commercial segment installed 176 MW in 2025, down 15% from the previous year. Collective self-consumption remains limited despite its potential to optimize shared generation and demand. Industry representatives said pending regulatory updates are needed to enable aggregated management models, dynamic energy allocation, and an expansion of eligible self-consumption areas.
Industrial self-consumption installations totaled 679 MW, marking a slight increase compared with 2024. UNEF said growth in this segment is being driven by larger medium-voltage systems aimed at reducing electricity costs and partially covering electrified thermal demand. Project viability increasingly depends on tariff structures with a higher variable component and more streamlined permitting for medium-sized installations.
Off-grid installations reached 55 MW in 2025, reflecting growing uptake of hybrid solar-plus-storage systems in rural areas and locations without grid access. Battery integration in grid-connected installations also continued to rise, improving controllability of generation and supporting system flexibility.
UNEF said Spain will need to deploy an average of around 2 GW of self-consumption capacity per year to meet the 19 GW target set out in the country’s National Integrated Energy and Climate Plan. Achieving that level will require regulatory stability, administrative simplification, and more effective integration of distributed energy storage.
Czechia’s first international conference on solar and flexibility highlighted that the combination of solar with storage and flexibility sources is key to not just Czechia’s, but also Europe’s, secure and competitive electricity system.
Solar Flex Prague, jointly organised by SolarPower Europe, Solární Asociace and Asociace AKU-BAT CZ, welcomed visitors to a snowy Czech capital on Thursday (29 January), bringing together stakeholders from across Europe to discuss how flexibility solutions and storage can be further deployed.
The conference began with a speech from SolarPower Europe CEO, Walburga Hemetsberger, who said that while electrification is a lifeline for Europe, there is dwindling confidence in the energy transition among some politicians, some leading businesses and key players in the defence sector.
“The way out of the doubts is to really bank big time on flexibility, on storage and on electrification. This will show very concrete benefits very quickly, make politicians understand and really feel the benefits,” Hemetsberger told attendees, before adding that the combination of solar with storage and flexibility sources can lower energy system costs by €30 billion by 2030, while strengthening Europe’s security by removing dependency on foreign players.
Paula Dorado represented the European Commission via video call and told attendees work on an electrification action plan is underway, scheduled for adoption this year. The plan is expected to address barriers and provide a way forward on electrification for different sectors including companies, households and industrial processes, Dorado said.
Throughout the day, speakers were in agreement that storage and flexibility now play an integral role in Czechia’s electricity system. Panellists pointed out that solar-plus-storage projects can be implemented in a matter of months, offering companies the ability to save money or open new revenue streams. Other speakers stressed the idea that renewable sources are uncontrollable is now outdated, explaining that modern solar-plus-storage systems are not only manageable, offering the ability to respond to market prices and the needs of both transmission and distribution system operators, but are shifting from grid-following to grid-forming technologies and contribute to the stability of the electricity system.
Czechia appears ahead of the curve when it comes to deploying co-located storage with smaller-scale solar, with figures published by Czechia’s largest electricity distributor, ČEZ Distribuce, last September sharing 86% of solar plants connected during the first half of 2025 were equipped with energy storage. In contrast, the country’s large-scale solar market sits at a pivotal moment following the implementation of a legal framework for large-scale development and operation last year. During an afternoon session on opportunities and challenges related to storage and the grid, Rene Nedela from Czechia’s Ministry of Industry and Trade said up to 180 GW of BESS applications have been registered, although some are without any project readiness.
Several speakers advised Czechia to look to other countries further down the line of large-scale battery deployment, and in particular its neighbour Germany, whose favourable market environment for batteries has helped attract investors and move flexibility efforts forwards.
Attendees also said flexible solar-plus-storage projects could help to solve any power shortages that arise from the gradual shutdown of coal-fired power plants in Czechia. The Czech government has committed to phasing out coal-fired electricity generation by 2033 and the country’s last deep black coal mine shut down last month.
During the afternoon session, Alexandr Cerny from Czechia’s Energy Regulatory Office introduced proposed changes to Czechia’s energy tariffs, expected to come into force from the start of next year. The changes will restructure current tariff categories, particularly at the higher voltage levels, and are in part designed to reward flexibility in both consumption and generation, holding the potential to help ramp up the deployment of batteries while better integrating renewables to the grid.
Solar Flex Prague was SolarPower Europe’s second conference on flexibility following the inaugural Solar Flex Croatia held last March. A second edition of Solar Flex Croatia will take place in Zagreb on March 17 this year and Hemetsberger told pv magazine work is currently underway preparing the first Solar Flex Italy for later this year.
Brazil curtailed about one-fifth of its solar and wind generation in 2025, wasting an estimated BRL 6.5 billion ($1.23 billion), as grid constraints and demand mismatches pushed the power system close to operational safety limits on 16 days, according to a report from Volt Robotics.
Brazil failed to use roughly 20% of the solar and wind electricity it generated in 2025, resulting in an estimated loss of BRL 6.5 billion, according to Volt Robotics’ Annual Curtailment Report.
Volt Robotics said the scale of curtailment reflects an unprecedented period of renewable oversupply combined with operational constraints in Brazil’s national electricity system.
Average generation cuts reached 4,021 MW over the year, equivalent to the monthly output of a large hydroelectric plant. On at least 16 days in 2025, system operation approached the lower technical safety limit, a sharp increase from 2024, when only one comparable event was recorded.
Volt Robotics said the 2025 events were driven by excess electricity supply rather than scarcity, marking a structural shift in system risk dynamics.
Curtailment intensified between August and October, when historically high levels of generation coincided with transmission constraints and weaker demand. The report attributes the peak losses to a combination of operational limitations, grid congestion, and insufficient flexibility to absorb surplus power.
Sunday mornings emerged as the most frequent stress point for the grid. Volt Robotics said reduced economic activity during weekends lowers electricity demand, while solar output peaks and is often reinforced by strong wind generation. This recurring mismatch leads to network overloads, forced generation cuts, and system operation near the lower safety threshold.
The report also highlights the risk of system instability caused by excess renewable generation. During the 16 critical days, Brazil’s National System Operator classified conditions as severe and implemented emergency measures, supported by the National Electric Energy Agency, including extraordinary generation curtailments.
Volt Robotics warned that without structural adjustments, surplus clean energy itself can become a source of operational risk.
The economic impact extends beyond immediate revenue losses. Frequent curtailment increases perceived investment risk, raises financing costs, and weakens Brazil’s appeal for new renewable energy projects, the report said. Both regulated and free-market projects were affected, with exposure to contractual penalties and the Settlement Price of Differences.
Regionally, Minas Gerais, Ceará, and Rio Grande do Norte recorded the highest levels of curtailed energy, forming what Volt Robotics described as Brazil’s “curtailment triangle.” Southern states experienced significantly lower losses.
Volt Robotics said the situation reflects a structural mismatch between rapid renewable capacity expansion, rising distributed generation, transmission bottlenecks, and tariff structures that do not adequately signal when electricity consumption is most valuable.
The report recommends the introduction of more dynamic time-of-use tariffs, stronger demand-side participation, and regulatory reforms to reduce curtailment and maintain the stability of Brazil’s electricity system.
With conventional renewable PPA momentum slowing, Europe’s flexibility market soared in 2025, driven by a surge in fixed-offtake agreements and BESS optimization structures. At the same time, co-located storage gained unprecedented traction, signaling a shift toward more integrated and flexible energy solutions.
In a record-breaking year for flexibility in Europe, nearly 12 GW/24 GWh of BESS capacity was contracted under flexibility purchase agreements (FPAs) and optimization agreements, triple the volume recorded in 2024, according to Pexapark’s Renewables Market Outlook 2026. FPAs have emerged as the backbone of BESS bankability, unlocking infrastructure-style capital and enabling rapid expansion beyond Great Britain into Germany, Italy, and the Netherlands.
Contract innovation accelerated, with tolls, floors, and financial structures such as day-ahead swaps becoming mainstream, while new buyer profiles – including traders, insurers, and hedge funds – entered the flexibility market. By contrast, traditional European PPA momentum cooled in 2025 as markets adjusted to lower capture expectations. Total disclosed contracted PPA capacity fell to 13.1 GW across 247 deals, down from 15.3 GW in 2024.
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After hitting an all-time high of $121.65/oz on Jan. 29, silver prices have tumbled to $79.44/oz, with analysts warning of a potential drop toward $50/oz.
After reaching an all-time high of $$121.65 per ounce (oz) on Jan. 29, silver prices have fallen sharply in recent days, dropping to $79.44/oz this morning.
The downturn had been anticipated by two analysts interviewed by pv magazine on Jan. 27, who warned that the steep rally seen in previous weeks could reverse abruptly in the days ahead.
One of the two analysts, Mike McGlone, senior commodity strategist at Bloomberg Intelligence, said the price could stabilize around $50/oz, although he did not provide a timeframe for when this new trend might materialize.
“Reversion toward $50 appears as a normal path for the commodity known as the ‘devil's metal' due to its volatility,” he told pv magazine.
Rhona O’Connell, head of market analysis for EMEA and Asia at StoneX, said on Jan. 27 that investors might soon rethink their rush into silver. She explained that speculative buying had pushed the metal into risky territory, making prices vulnerable to a sharp correction. O’Connell also said fears of potential U.S. tariffs fueled the recent rally, swelling COMEX inventories as metal flowed into the U.S. Further gains are unlikely, she added, dismissing even $100/oz as unsustainable and warning of a potentially severe price reversal.
Silver prices surged by approximately 130% in the past six months and around 243% over the past year. The average silver price was $28.27/oz in 2024, $23.38/oz in 2023, and $21.80/oz in 2022.
Renewables and storage could reliably power data centers, but success requires active grids, coordinated planning, and the right mix of technologies. Hitachi Energy CTO, Gerhard Salge, tells pv magazine that holistic approaches ensure technical feasibility, economic viability, and energy system resilience.
As data centers grow in size and complexity, supplying them with cheap and reliable power has never been more pressing. Gerhard Salge, chief technology officer (CTO) at Hitachi Energy, a unit of Japanese conglomerate Hitachi, shed light on the relationship between renewable energy and data center operations, noting that while technically feasible, success requires careful planning, the right infrastructure, and a holistic approach.
“When we look at what's happening in the grids, then renewables are an active element on the power generation side, and the data centers are an active element on the demand side,” Salge told pv magazine. “What you need in addition to that is in the dimensions of flexibility, for which we need storage and a grid that can actively act also here in order to bring all these elements together.”
Want to learn more about matching renewables with data center demand?
The event will spotlight how solar and energy storage solutions are driving sustainable and reliable infrastructure, with a particular focus on powering the country’s rapidly growing data center sector.
According to Salge, the key is active grids, not passive systems that simply react to conditions. With more renewables, changing demand patterns, new load centers, and storage options like batteries and existing facilities such as pumped hydro, it is crucial to coordinate these resources actively to maintain supply security, power quality, and cost optimization.
“But when you talk about the impact and the correlation between renewables and data centers, you need always to consider this full scope of the flexibility in a power system of all the elements—demand side, generation side, storage side, and the active grid in between,” he said, noting that weak or congested grids would not serve this purpose.
AI data centers
Salge warned that not all data centers are the same. “There are conventional data centers and AI data centers,” he said. “Conventional data centers are essentially high-load systems with some fluctuations on top. They contain many processors handling requests—from search engines or other applications—so the workload is distributed stochastically across them. This creates a baseline load with random ups and downs, which is the typical load pattern of a conventional data center.”
AI workloads, in contrast, rely heavily on GPUs or AI accelerators, which consume significant power continuously. Unlike conventional data centers, AI data centers often run at sustained high load, sometimes close to maximum capacity for long periods.
Htitachi Energy CTO Gerhard Salge
Image: Hitachi Energy
“AI data centers are specifically good in doing parallel computing,” Salge explained. “So many of them are triggered with the same demand pattern at the same time, which creates these spikes up and down in the demand profile, and they come in parallel all together.”
These fluctuations challenge both the power supply and the voltage and frequency quality of the connected grid. “So, you need to transport active power from an energy storage system or a supercapacitor to the demand of the AI data center. And that then needs to involve really the control of the data center’s active power. What you need is the interaction between the storage unit and then the AI data center to provide active power or to absorb it afterwards when the peak goes down. That can be also done by a supercapacitor.”
Batteries can store much more energy than supercapacitors, but the latter can ramp smaller energies more frequently. “However, if you put a battery that is smaller than the load, and you really need to cycle the battery through its full capacity, the battery will not survive very long with your data center, because the frequency of these bursts is so high, then you are aging the battery very, very quickly, yeah, so supercapacitors can do more cycles,” Salge emphasized.
He also noted that batteries and supercapacitors are both mature technologies, but the optimal setup—whether one, the other, or a combination with traditional capacitors—depends on storage size, number of racks, voltage levels, and overall system design.
Managing AI training bursts
Salge stressed the importance of complying with grid codes across geographies. “You need to become a good citizen to the power system,” he said. “You have to collaborate with local utilities to make sure that you are not infringing the grid codes and you are not disturbing with the data center back into the grid. A good way to do this, when renewables and data centers are co-located, is to manage renewable energy supply already inside the data center territory. Moreover, having a future-fit developed grid is a clear advantage. Because you have much more of these flexibility elements and the active elements to manage storage and renewable integration and to manage the dynamic loads of the data centers.”
If the grid is not future-fit with modern, actively operating equipment, operators will see significantly more stress. “With holistic planning, instead, you can even use some of the data center flexibility as a controllable and demand response kind of feature,” Salge said, adding that data center operators could coordinate AI training bursts to periods when the power system has more available capacity. This makes the data center a predictable, controllable demand, stressing the grid only when it is prepared.
“In conclusion, regarding technical feasibility: yes, it’s possible, but it requires the right configuration,” Salge said.
Economic feasibility
On economics, Salge believes solar and wind remain the cheapest power sources, even when accounting for the grid flexibility needed to integrate them with data centers. Solar is fastest to deploy, wind complements it well, and both can be scaled in parallel.
“Any increase in data center demand requires investment, whether from renewables or conventional power. Economics depend on the market, and market mechanisms, regulations, and technical grid planning are interconnected, influencing energy flow, pricing, and system stability,” he said.
“We recommend developers to work with all stakeholders—utilities, technology providers, and planners—from the start to ensure reliability, affordability, and social acceptance. Holistic planning avoids reactive fixes and leads to better long-term outcomes,” Salge concluded.
Bulgaria installed over 1 GW of solar for the third consecutive year in 2025 and is forecast to add over 2 GW this year thanks to a large pipeline of utility-scale projects.
Bulgaria added 1,416 MW of solar last year, according to official data published on the ENTSO-E Transparency Platform. The result marks the third consecutive year Bulgaria has deployed over 1 GW of solar and takes the country’s cumulative capacity to 5,984 MW.
Desislava Mateva, project manager at the Sofia-based Association for Production, Storage and Trading of Electricity (APSTE) told pv magazine that Bulgaria’s solar market is currently dominated by ground-mounted, utility-scale solar plants, reflecting the availability of land, strong developer activity and increasing access to project finance.
Utility-scale solar made up around 90% of Bulgaria’s new capacity last year. Mateva said the market was driven by the strong commercial competitiveness of solar, making projects viable without direct subsidies, as well as active support from local and international banks and a large pipeline of development projects that reached the ready-to-build stage or financial close over the past 18 months.
Mateva also noted that Bulgaria is experiencing a wave of standalone battery energy storage system (BESS) deployments and the hybridization of both existing and new solar assets with BESS, as developers look to deal with price cannibalization and declining solar capture rates.
“These developments are expected to reduce price volatility, improve system flexibility, and mitigate capture-price pressure for solar producers,” she explained. “As a result, industry expectations remain positive.”
Among the largest projects to be commissioned in Bulgaria last year was the first phase of the 315 MW/760 MWh Tenevo hybrid project, with a second phase scheduled for commissioning early this year, and the Selanovtsi hybrid project, a 59.8 MW solar plus 107.3 MWh storage site in the northwestern Vratsa region. Bulgaria also commissioned one of the EU's largest standalone BESS facilities last year, located adjacent to a 107 MW solar park.
Bulgaria’s C&I solar market is showing steady momentum, particularly among projects designed for self-consumption, Mateva added, with rising electricity costs incentivizing businesses to invest in on-site solar, often in combination with storage.
In contrast, Bulgaria’s residential solar sector remains underdeveloped in capacity terms. Mateva said interest among households exists but the market segment has been constrained by regulatory complexity and limited incentives.
She added that the residential sector would benefit from the full liberalization of Bulgaria’s electricity market, as currently household electricity prices remain regulated, accounting for roughly 40% of national electricity demand. “Full liberalization would stimulate demand-side participation and unlock the residential solar and storage market,” she explained.
Looking ahead, Mateva predicted Bulgaria is on course for a record year in solar deployment in 2026. “An estimated 2.5 GW of additional solar projects are either under construction or at an advanced stage of development and expected to start construction soon,” she said. “This pipeline suggests that most of this capacity will be commissioned by the end of 2026.”
Bulgaria’s storage pipeline is looking equally healthy, with 15 GWh expected to be commissioned by half way through the year, supported by the country’s National Recovery and Resilience Plan.
Mateva added that the most significant policy change last year was a sharp increase in eco-taxes and recycling fees for solar panels and batteries. She explained that these fees are currently five to ten times higher than in comparable EU countries, in turn artificially inflating PV and BESS project costs.
“Unless addressed, this issue risks becoming a major bottleneck for new PV and BESS procurement,” Mateva told pv magazine. “Resolving this will require action from the Ministry of Ecology to align recycling fees with real-world costs and EU norms, ensuring that Bulgaria’s strong solar momentum is not undermined by avoidable regulatory distortions.”
Bulgaria opened a new grant program late last year targeting micro, small and medium-sized enterprises looking to deploy PV systems and storage, with a particular focus on those located in the country’s coal regions. The call is set to close next month.
Tesla and Chint Power rank first and second in a new long-duration energy storage leaderboard from Sightline Climate, while mechanical storage providers such as Italy’s Energy Dome feature prominently as post–final investment decision projects begin to reshape the competitive landscape.
An analysis of the long-duration energy storage (LDES) scene, focusing on technologies with at least eight-hour durations, shows the top two providers today globally are lithium-ion battery makers Tesla and Chint Power.
The new leaderboard by Sightline Climate, being developed over the past 15 months, according to the firm, gives a snapshot right now of leaders in LDES across factors including technology performance, financial profile, deployment track record, and economics and cost.
Lukas Karapin-Springorum, a research analyst at Sightline who introduced the LDES leaderboard to ESS News, said efforts to accurately rank players have been focusing on the core factors that matter to find the names that stakeholders like utilities, banks, and investors need to know right now.
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Bhutan’s Druk Green Power Corporation and India’s Carbon Resources Private Limited have agreed to collaborate on new solar and hydropower projects in Bhutan with capacities between 100 MW and 250 MW.
Bhutan’s leading renewables company Druk Green Power Corporation (DGPC) has signed a memorandum of understanding with Kolkata-based Carbon Resources Private Limited (CPRL) to jointly pursue renewable energy projects.
Under the terms of the partnership, DGPC and CPRL will collaborate on developing new solar and hydropower projects in Bhutan with capacities ranging between 100 MW and 250 MW.
DGPC will be responsible for sharing project information, past studies and regulatory frameworks to assist CRPL in undertaking required technical, commercial and financial assessments of potential projects.
Identified sites will then be developed through one or more special purpose vehicles incorporated in Bhutan as joint ventures between the two parties. The memorandum of understanding proposes a debt-equity financing structure of 70:30 between DGPC and CPRL.
The signing ceremony was attended by Bhutan’s Minister for Energy and Natural Resources, Lyonpo Gem Tshering, who said memorandums of understanding for more than 12 GW of generation capacity have been signed in the country to date.
Bhutan has a target of reaching 25 GW of installed generation capacity by 2040. A World Bank report published last June reported the country’s total generation capacity stood at 2.5 GW by the end of 2024, made up almost entirely of hydropower plants.
Bhutan’s first utility-scale solar plant, a 17.38 MW array located towards the centre of the country, was commissioned last July. A month later, a consortium consisting of local firm Rigsar Construction and India’s HILD Energy was awarded a contract to develop the 120 MW Jamjee solar project.
In December, DGPC opened a tender for the 120 MW Wobthang solar project. The project’s feasibility study and consultation meetings have since been completed, with DGPC planning to award the contract by June. The project is scheduled to begin construction this September and with the build expected to take around 18 months, is pencilled for operations during the first half of 2028.
Bhutan’s current national energy policy, published last year, aims to add 5 GW of solar capacity by 2040.
India’s renewable energy industry is urging the government to use Union Budget 2026 to unlock stalled projects, lower financing costs, and accelerate domestic manufacturing across solar, storage, and grid infrastructure.
The upcoming budget must prioritize in-house technology and equipment development, provide clarity on delayed power purchase agreements (PPAs) and power sale agreements (PSAs), increase budgetary allocation and policy support for Green Energy Corridors, introduce production-linked incentives for battery energy storage system (BESS) manufacturing, establish an Approved List of BESS Integrators (ALBI), lower the cost of capital through priority sector lending, extend ALMM for solar cells, and continue the ISTS waiver, among other measures.
1. Focus on In-House Technology & Equipment Development
The government should place strong emphasis on in-house development of cutting-edge solar technologies, enabling India to achieve self-reliance in a shorter timeframe and indigenize next-generation technologies.
In addition to this critical, solar, cell & module manufacturing equipment should be brought und er the PLI framework. This support may subsequently be extended in a phased and structured manner to wafer and ingot manufacturing equipment. India already possesses strong equipment manufacturing capabilities across multiple industrial sectors. Leveraging these capabilities, coupled with indigenous technology development, can rapidly position India as a globally competitive and self-reliant solar manufacturing hub.
2. Clarity on Delayed PPAs and PSAs
As of January 2026, over 45 GW of renewable energy capacity in India is facing large delays in signing Power Purchase Agreements (PPAs) and Power Sale Agreements (PSAs), with developers. This uncertainty has raised serious concerns among investors and lenders. The industry requests the government to provide clear confirmation in the budget that these PPAs and PSAs will be signed expeditiously. Such assurance will significantly improve sectoral sentiments and catalyse increased inflows of both equity and debt into India’s renewable energy sector.
3. Strengthening Green Transmission Infrastructure
The industry appreciates the increased budgetary allocation and policy focus on Green Energy Corridors. Continued emphasis with higher allocations and faster execution is critical to ensure timely grid connectivity for upcoming renewable capacity.
Additionally, procedures and guidelines at the state level for grid connectivity and charging infrastructure should be further streamlined to ensure faster approvals, seamless evacuation, and immediate power injection upon physical commissioning of projects.
4. PLI for BESS Manufacturing
“Solar and BESS Manufacturing” to be re-categorized into “Infrastructure” category of RBI for ease of financing and re-financing. A dedicated PLI scheme for BESS manufacturing—similar to solar—should be introduced, encouraging local integration of components such as Containers, HVAC systems, Cabling, Fire-fighting systems. Only Lithium-ion cells, which are currently not manufactured at scale in India, should be permitted for import under this scheme.
5. Approved List of BESS Integrators (ALBI)
An Approved List of BESS Integrators, on the lines of ALMM for solar modules, should be introduced. This will ensure grid-connected BESS assets meet quality and safety standards, minimize systemic risks to the electricity grid and Improve investor and lender confidence.
6. Lower Cost of Capital & Priority Sector Lending
India is estimated to require USD 200+ billion in investments by 2030 to meet its clean energy targets. Access to competitively priced capital will be critical. The industry requests the inclusion of renewable energy projects under Priority Sector Lending and Re-introduction of lower TDS rates on interest for ECBs and Rupee-denominated bonds. These measures will materially reduce financing costs and accelerate project deployment.
7. Extension of ALMM for Solar Cells
Considering manufacturing of solar cells in the country is still picking up and with an increasing demand for Solar cells &supply demand mismatch, government should consider exceeding its target to introduce ALCM for cells for a further period of 2 years.
8. Extension of ISTS Waiver
Interstate charges on power transmission through ISTS connectivity are waived till 2025. This should be further extended over the next 5 years to give a steeper boost to C&I segment which has large ISTS opportunities.
9. Concessional Corporate Tax Rate for Manufacturing
The concessional 15% income tax rate for new manufacturing entities in the renewable energy sector should be reintroduced in Budget 2026 and to be extended for a minimum of five years.
10. Exclusion from Deemed Dividend Tax
Renewable energy companies should be excluded from deemed dividend tax provisions in cases where loans or advances are provided by SPVs to shareholders. This will enable optimal capital utilization within project groups.
11. Reduction of GST on BESS
Lower GST on BESS and related products from existing18% to 5%. BESS enables grid stability and allows more RE to be integrated into the grid. Lower GST will accelerate adoption, encourage domestic manufacturing, support job creation, exports, and emissions reduction.
12. GST Exemption on Corporate Guarantees
Exemption of GST on Corporate Guarantee for renewable energy companies wherein Corporate Guarantee is provided by Holding Company to lenders in respect of funding obtained by SPVs.
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