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					</table><p>The <a href="https://www.maharashtra.gov.in/" target="_blank" rel="noopener">Maharashtra state government</a> has announced a range of incentives across categories for the purchase of electric vehicles (EVs) under the Maharashtra Electric Vehicle Policy for 2025.</p>
<p>The policy targets every one in three vehicles registered to be an EV by 2030.</p>
<p>It offers an incentive of a maximum of ₹2 million (~$23,502.8)/vehicle in the passenger bus/goods carrier category. Electric two-wheelers and three-wheelers will get a purchase incentive of ₹10,000 (~$117.52) and ₹30,000 (~$352.57) for the first 100,000 and 15,000 vehicles, respectively.</p>
<p>Electric cars will be eligible for a purchase incentive of ₹150,000 (~$1762.84) for the first 10,000 vehicles.</p>
<p><a href="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/image-4.png"><img loading="lazy" decoding="async" class="aligncenter wp-image-79987 size-full" src="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/image-4.png" alt="" width="604" height="470" srcset="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/image-4.png 604w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/image-4-300x233.png 300w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/image-4-600x467.png 600w" sizes="(max-width: 604px) 100vw, 604px" /></a></p>
<p>The policy, which will be valid for five years, aims to accelerate EV adoption across all vehicle segments and ensure widespread charging infrastructure to support it.</p>
<p>The policy also plans to reduce vehicular particulate matter (PM) 2.5 emissions in the state. It is estimated that Maharashtra will be able to reduce 325 tons of vehicular PM 2.5 emissions and approximately 1 million tons of greenhouse gas emissions from the transport sector by 2030.</p>
<p>The state’s Transport Department will be the designated nodal agency for the policy.</p>
<p>Under these targets, 40% of all new two-wheelers must be EVs, and electric four-wheelers will comprise 30% of all new four-wheeler registrations.<a href="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/image-1-1.png"><img loading="lazy" decoding="async" class="aligncenter wp-image-79989 size-full" src="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/image-1-1.png" alt="" width="633" height="339" srcset="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/image-1-1.png 633w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/image-1-1-300x161.png 300w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/image-1-1-624x334.png 624w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/image-1-1-600x321.png 600w" sizes="(max-width: 633px) 100vw, 633px" /></a></p>
<p>These incentives will be valid only for vehicles either manufactured for sale in Maharashtra or registered for sale in the state.</p>
<p>The original equipment manufacturer will avail the incentives and pass them on to the end consumer.</p>
<p>The incentives will be disbursed as a percentage of the vehicle’s ex-factory price. They will also be applicable for selling EVs without transferring battery ownership.</p>
<p>All EVs sold under the policy period will be completely exempted from motor vehicle tax.</p>
<p>There will also be a 100% toll tax exemption for passenger EVs commuting on state highways such as Yashwantrao Chavan Mumbai-Pune Expressway, Hindu Hrudaysamrat Balasaheb Thackeray Maharashtra Samruddhi Mahamarg, Atal Bihari Vajpayee Sewri–Nhava Sheva Atal Setu.</p>
<p>Phased toll waivers for electric vehicles on other state highways are currently under discussion.</p>
<p><strong>Charging Infrastructure</strong></p>
<p>The policy includes the installation of EV charging infrastructure every 25 km along state and national highways.</p>
<p>It mandates all existing and new fuel pumps on state and national highways to have at least one fast charging station. The same requirement also extends to all Maharashtra State Road Transport Corporation bus stations.</p>
<p>The state will also release viability gap funding for DC fast charging station installations to incentivize establishing EV charging infrastructure across highways.<a href="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/image-2.png"><img loading="lazy" decoding="async" class="aligncenter wp-image-79988 size-full" src="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/image-2.png" alt="" width="613" height="306" srcset="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/image-2.png 613w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/image-2-300x150.png 300w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/image-2-600x300.png 600w" sizes="(max-width: 613px) 100vw, 613px" /></a>The state’s Energy Department will create a nodal agency to develop an integrated EV charging infrastructure plan. It will categorize EV charging stations based on renewable energy usage and availability of battery energy storage systems.</p>
<p>The concessional tariff for all EV charging and battery swapping stations will follow the tariff structure issued by the Maharashtra Electricity Regulatory Commission.</p>
<p>The state government will establish a one-window online system/portal to provide charging infrastructure approvals.</p>
<p><strong>Building Code Amendments</strong></p>
<p>Under the Ministry of Housing and Urban Affairs guidelines, the state government has mandated that all new residential buildings have 100% EV-compliant parking spaces.</p>
<p>Each new residential building must allocate at least one dedicated community EV charging point.</p>
<p>Existing housing societies must allocate shared EV charging stations if at least 50% of the housing society members approve of this dedicated allocation.</p>
<p>Under these rules, all new commercial buildings must also allocate at least 50% of their parking spaces for EV charging.</p>
<p>The Mumbai – Pune Expressway and Mumbai – Nagpur Samruddhi will be built as a sustainable mobility corridor. It will comprise charging infrastructure for all EV types. Deploying hydrogen vehicles on the Pune-Mumbai Expressway on pilot routes is also targeted.</p>
<p><strong>Battery Recycling</strong></p>
<p>To attract investments for EV manufacturing, the state government will provide all benefits under the D+ category of mega projects/other categories for industries, including micro, small, and medium enterprises. These companies can be part of the EV battery and component manufacturing sector, irrespective of their manufacturing location in the state.</p>
<p>The state will encourage setting up EV battery recycling hubs closer to EV battery manufacturing hubs and EV charging infrastructure.</p>
<p>Urban local bodies will designate convenient drop-off points for used EV batteries. They will also identify and earmark the land for drop-off spots near the solid waste disposal and processing sites for battery segregation.</p>
<p>They can also collaborate with nearby and existing battery recycling facilities to bolster battery recycling.</p>
<p><strong>Research and Development </strong></p>
<p>To encourage R&amp;D in the state, at least three centers of excellence will be developed, focusing on EVs, charging infrastructure, and hydrogen-based technologies.</p>
<p>The government has earmarked ₹150 million (~$1.76 million) under the “CM EV R&amp;D Grant” to fund R&amp;D activities in the EV sector.</p>
<p>The Maharashtra government will also develop specialized courses for EV design, battery technology, charging infrastructure, power electronics, and energy management.</p>
<p>The Transport Department will establish a network of automated testing stations for EVs to conduct standardized safety assessments.</p>
<p>The state government will also develop a digital battery passport to track key parameters such as manufacturing details, real-time health status, usage history, and end-of-life diagnostics.</p>
<p>According to data <a href="https://mercomindia.com/electric-vehicle-sales-2024" target="_blank" rel="noopener">released</a> by the Ministry of Road Transport and Highways through its Vahan Dashboard in January 2025, Maharashtra had the second-highest EV sales in the country.</p>
<p>In September 2024, the Union Cabinet <a href="https://www.mercomindia.com/cabinet-pm-edrive-program" target="_blank" rel="noopener">approved</a> the PM Electric Drive Revolution in Innovative Vehicle Enhancement Program, with a total outlay of ₹109 billion (~$1.29 billion).</p>
<p>Subscribe to Mercom’s real-time <a href="https://www.mercomindia.com/product/mercoms-renewable-energy-regulatory-updates" target="_blank" rel="noopener">Regulatory Updates</a> to ensure you don’t miss any critical updates from the renewable industry.</p>


Maharashtra Targets 30% EV Adoption by 2030, Announces Purchase Sops


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					</table><p>The real-time market on the <a href="https://www.iexindia.com/">Indian Energy Exchange</a> saw market clearing prices plunge to near-zero levels on Sunday due to a surge in power supply and a simultaneous dip in demand caused by unseasonal rains and thunderstorms.</p>
<p>Prices began falling from the 06:30–06:45 time block and remained low until 12:45–13:00, with the market clearing price remaining at nearly ₹0/kWh between 09:00–13:00 hours. During this period, supply far outpaced demand, with sell bids routinely outweighing purchase bids by five times.</p>
<p>The market clearing price during this period was lower than the exchange fees, which stood at ₹0.02 (~$0.00024)/kWh.</p>
<p><a href="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/IEX.png"><img loading="lazy" decoding="async" class="aligncenter wp-image-79954 size-full" src="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/IEX.png" alt="IEX" width="752" height="229" srcset="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/IEX.png 752w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/IEX-300x91.png 300w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/IEX-650x198.png 650w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/IEX-624x190.png 624w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/IEX-600x183.png 600w" sizes="(max-width: 752px) 100vw, 752px" /></a></p>
<p style="text-align: center;">Image credit: IEX</p>
<p>The decline in demand, which fell nearly 2% compared to the same period last year, resulted from thunderstorms and cooler-than-average temperatures across North and Central India, reducing the need for air conditioning. At the same time, all major power sources, including thermal, hydro, solar, and wind, remained operational. Coal projects were also running at full capacity, further adding to the surplus in supply.</p>
<p>Although buyers paid very little for electricity, solar developers missed the opportunity to earn revenue from clean energy generation. This development highlights the growing disconnect between the cost of generation and prevailing market prices. Unlike many other countries, India does not have a demand-side management market that allows commercial and industrial consumers to adjust usage based on real-time price signals.</p>
<p>Selling power at such low rates is not financially viable. Power generators could achieve better returns if this excess energy was stored in battery energy storage systems (BESS) and supplied during peak demand hours.</p>
<p>Mercom had previously <a href="https://www.mercomindia.com/battery-energy-storage-key-to-indias-renewable-energy-future/" target="_blank" rel="noopener">written</a> on the growing importance of BESS as a key solution for balancing power generation and consumption, especially as India’s grid becomes more complex with the increasing integration of renewable energy. BESS plays a vital role in stabilizing the grid by smoothing out fluctuations in renewable power output and enabling the use of surplus energy generated during the day to meet peak demand in the evening.</p>
<p>According to the National Electricity Plan released by the Central Electricity Authority, India will need nearly 74 GW/411 GWh of energy storage capacity by 2032. This requirement is crucial for supporting the integration of an estimated 364 GW of solar and 121 GW of wind energy capacity.</p>


Real-Time Power Prices on IEX Crash to Zero as Rains Dull Energy Demand


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					</table><p>REC Power Development and Consultancy (<a href="https://www.recpdcl.in/" target="_blank" rel="noopener">RECPDCL</a>) has invited bids to set up an interstate transmission system (ISTS) to integrate 3 GW of renewable energy at Ananthapuram-II Renewable Energy Zone (Phase-II) in Andhra Pradesh.</p>
<p>The work must be completed within 24 months from the allocation date.</p>
<p>Bids must be submitted by July 27, 2025. Bids will be opened on the same day.</p>
<p>Bidders must furnish a document fee of ₹500,000 (~$5,879) plus GST and a bid bond of ₹408 million (~$4.79 million).</p>
<p>Selected bidders must remit ₹1.02 billion (~$11.99 million) as a contract performance guarantee within ten days from the letter of intent.</p>
<p>The scope of work includes the augmentation of the Ananthapuram-II pooling station (PS) with a 400/220 kV, 1&#215;500 MVA interconnecting transformer (ICT), along with the provision of 220 kV and 400 kV line bays for the termination of dedicated transmission lines from renewable energy generation projects. Further augmentation at Ananthapuram-II PS will include the installation of two 765/400 kV, 1,500 MVA ICTs and six 400/220 kV, 500 MVA ICTs, and additional 220 kV line bays for renewable energy line terminations.</p>
<p>Successful bidders must also set up a new 765/400 kV substation at CN&#8217;Halli, equipped with three 1,500 MVA transformers and two 330 MVAr (765 kV) bus reactors. A 765 kV double-circuit transmission line will be constructed between Ananthapuram-II PS and CN&#8217;Halli, incorporating 330 MVAr switchable line reactors at the Ananthapuram-II end on both circuits.</p>
<p>It also includes creating a loop-in loop-out (LILO) of one circuit of the Talaguppa–Neelmangala 400 kV double-circuit line at CN&#8217;Halli. Additionally, either the LILO of the section already diverted to Hassan on one circuit will be extended to CN&#8217;Halli or the other circuit will be looped in and out at CN&#8217;Halli to establish a direct 400 kV double-circuit connection between it and Hassan.</p>
<p>This transmission infrastructure is part of India&#8217;s broader initiative to achieve 500 GW of non-fossil fuel-based power generation by 2030, with 51 GW potential identified in Andhra Pradesh alone. The proposed Phase II transmission system is required to accommodate additional renewable energy generation that exceeds the capacity of the under-implementation Phase I system at the Ananthapuram-II pooling station.</p>
<p>Bidders must have developed infrastructure projects with a minimum total capital expenditure of ₹20.4 billion (~$239.82 million) in the last five years, with each project having a capital expenditure of at least ₹4.08 billion (~$47.96 million).</p>
<p>Alternatively, bidders must have received total payments of at least ₹20.4 billion (~$239.82 million) from clients for construction works fully completed in the last five financial years. Each project must have generated minimum payments of ₹4.08 billion (~$47.96 million).</p>
<p>Bidders must have a minimum net worth of ₹8.16 billion (~$95.93 million) in any of the past three years, with no negative net worth reported during this period.</p>
<p>In March this year, RECPDCL <a href="https://www.mercomindia.com/recpdcl-invites-bids-for-2-5-gw-renewable-energy-transmission-projects/" target="_blank" rel="noopener">invited</a> bids for developing an ISTS to evacuate 2,500 MW of renewable energy in Madhya Pradesh.</p>
<p>In October last year, RECPDCL <a href="https://www.mercomindia.com/recpdcl-tenders-4-5-gw-ists-transmission-project-in-andhra-pradesh/" target="_blank" rel="noopener">invited</a> bids to establish an ISTS to evacuate 4.5 GW of power from Kurnool-IV Renewable Energy Zone Phase 1 in Andhra Pradesh.</p>


RECPDCL Invites Bids to Set Up Transmission System for Renewable Energy Integration


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					</table><p>The Gujarat Electricity Regulatory Commission (<a href="https://gercin.org/" target="_blank" rel="noopener">GERC</a>) has issued a detailed draft procedure for renewable energy projects seeking connectivity to the state’s grid.</p>
<p>The procedure applies to multiple stakeholders, including applicants covered under Regulation (4) of the GERC Open Access Regulations 2011, developers of renewable energy projects with or without energy storage systems, standalone energy storage systems, and renewable energy parks.</p>
<p>It also applies to transmission and power distribution companies (DISCOMs), Gujarat Energy Transmission Corporation (GETCO), Gujarat Energy Development Agency (GEDA), load despatch centers, and other relevant state agencies.</p>
<p>It <a href="https://www.mercomindia.com/gujarat-rules-green-open-access" target="_blank" rel="noopener">aligns</a> with the GERC Green Energy Open Access Regulations, 2024, and other relevant policies of the Gujarat Government, including the Renewable Energy Policy 2023.</p>
<p>Stakeholders can submit their comments and suggestions by May 30, 2025.</p>
<p><strong>Application Process</strong></p>
<p>All connectivity applications must be submitted online through the Akshay Urja Setu Portal.  Applicants must complete a one-time registration with GEDA before submitting the application.</p>
<p>Applications can be submitted upon successful registration by paying a non-refundable fee online and uploading the required documents. Original documents must be submitted physically to GETCO, the state transmission utility (STU), or the concerned DISCOM within seven days. Failure to comply will be treated as a procedural violation.</p>
<p>A unique identification number is generated upon application submission. This identification number remains fixed and maintains application priority based on date and time stamps.</p>
<p><strong>Eligibility</strong></p>
<p>Eligibility for connectivity includes renewable energy developers, renewable energy projects, and renewable energy park developers willing to undertake construction and commissioning activities related to substations and transmission infrastructure.</p>
<p>Existing projects with already granted connectivity need not reapply. However, any capacity augmentation requires a new application.</p>
<p>Projects can switch to another renewable energy source if restrictions are imposed by authorities like the Forest or Defense Departments, provided GETCO, STU, or DISCOMs and the Commission approves the change.</p>
<p>Once granted, connectivity is non-transferable unless to wholly owned subsidiaries or parent companies. The developer must assume full responsibility for compliance, including payment of transmission or wheeling charges.</p>
<p>If the renewable energy project is not commissioned within the stipulated time, the developer and the transferee are jointly and independently liable for the charges. Non-completion can also lead to cancellation of connectivity and forfeiture of guarantees.</p>
<p><strong>Monthly Substation Updates</strong></p>
<p>GETCO publishes and updates a list of substations on the third of every month at 11 AM. The list includes indicative capacities and timelines for existing and planned substations. Applicants may select up to three substations in order of preference.</p>
<p><strong>Required Documents and Fees</strong></p>
<p>Applications must include a notarized affidavit, application form, non-refundable application fee, an infrastructure development charge of ₹100,000 (~$1,167)/MW, and various bank guarantees. These include a security bank guarantee and an associated transmission system bank guarantee of ₹2 million (~$23,346)/MW for certain applications. Applicants must also show land ownership or submit a land bank guarantee of ₹1 million (~$11,673)/MW.</p>
<p>For third-party or captive projects, further documentation related to ownership, equity, and place of consumption must be submitted.</p>
<p>All documents must be uploaded online and submitted physically within seven days.</p>
<p><strong>Processing and Grant of Connectivity</strong></p>
<p>Applications are processed per the GERC connectivity regulations. Deficiencies or clarifications are communicated online or via email, and applicants must respond within seven working days. Incomplete applications are rejected.</p>
<p>Feasibility studies are conducted in consultation with DISCOMs. Applicants are informed about the connectivity grants by the 30th of the subsequent month. Provisional connectivity may be granted subject to system strengthening if no capacity exists. The associated transmission system bank guarantee must be submitted within 15 days of provisional approval. Failure to do so results in application closure and fee forfeiture.</p>
<p>Priority is determined first by whether the applicant holds a letter of award or power purchase agreement with a DISCOM, followed by applicants with land documents over those with land bank guarantees.</p>
<p>A committee constituted by the Energy and Petrochemicals Department reviews the application for projects in non-listed areas. If feasibility is established, provisional connectivity is granted with a timeline for infrastructure development.</p>
<p>The associated transmission system bank guarantee must be valid six months beyond the projected completion date. Non-commissioning of projects within this window results in revocation of connectivity and encashment of guarantees.</p>
<p>The power carrying capacity of the dedicated transmission line will be as follows:</p>
<p><a href="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/GERC-Transmission.png"><img loading="lazy" decoding="async" class="aligncenter wp-image-79922 size-full" src="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/GERC-Transmission.png" alt="GERC Transmission" width="658" height="273" srcset="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/GERC-Transmission.png 658w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/GERC-Transmission-300x124.png 300w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/GERC-Transmission-650x270.png 650w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/GERC-Transmission-624x259.png 624w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/GERC-Transmission-600x249.png 600w" sizes="(max-width: 658px) 100vw, 658px" /></a></p>
<p><strong>Technical Requirements</strong></p>
<p>Renewable energy developers must comply with the central and state technical standards and regulations, including those from the Central Electricity Authority, the Central Electricity Regulatory Commission, and the GERC. These requirements cover project construction, safety, metering, grid code compliance, cybersecurity, and forecasting.</p>
<p>Dedicated transmission or distribution infrastructure must meet minimum power transfer capacities based on voltage levels. The same applies to pooling stations and line bay equipment. Infrastructure sharing is permitted under an agreement between multiple generators, with costs and maintenance shared proportionately.</p>
<p><strong>Monitoring and Commissioning</strong></p>
<p>The developer must submit quarterly progress reports in a specified format. Failure to report progress can lead to connectivity revocation.</p>
<p>At least 10% of the allotted capacity must be commissioned within one month of the line energization. The rest must be completed within the timelines specified by the Commission. Delays result in bank guarantee forfeiture and connectivity cancellation. Spare capacity is made available to other applicants.</p>
<p>Renewable energy park developers must commission their projects per the power purchase agreements, GERC orders, and renewable energy policy timelines. If not, they may seek an extension from the Commission. Similarly, transmission licensees must complete their infrastructure in time or seek extensions in case of delays.</p>
<p>A certificate from the Chief Electrical Inspector must be submitted within ten days of receipt.</p>
<p>STU or DISCOMs can shift connectivity to optimize infrastructure use, but the applicant must bear the cost. Spare feeder bays can be used temporarily with associated charges.</p>
<p><strong>Infrastructure Sharing</strong></p>
<p>Lead generators can share transmission lines, bays, and pooling stations with other entities for optimal infrastructure use. Agreements must be submitted, and energy metering should be in place for accurate accounting. In case of underutilization, STU can seek justification and escalate the matter to GERC.</p>
<p>Subscribe to Mercom’s real-time <a href="https://mercomindia.com/product/mercoms-renewable-energy-regulatory-updates/" target="_blank" rel="noopener">Regulatory Updates </a>to ensure you don’t miss any critical updates from the renewable industry.</p>


Gujarat Proposes Intrastate Grid Connectivity Rules for Renewable Energy Projects


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					</table><p>The U.S. Department of Commerce (<a href="https://www.commerce.gov/" target="_blank" rel="noopener">Commerce</a>) has determined preliminary countervailing duties of up to 721% on imports of active anode material from China, which is crucial to battery manufacturing.</p>
<p>Countervailing duties were imposed on the following Chinese companies:</p>
<p><a href="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/countervailing.png"><img loading="lazy" decoding="async" class="aligncenter wp-image-79908 size-full" src="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/countervailing.png" alt="" width="524" height="251" srcset="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/countervailing.png 524w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/05/countervailing-300x144.png 300w" sizes="(max-width: 524px) 100vw, 524px" /></a></p>
<p>The U.S. is conducting an anti-dumping investigation, along with investigations on countervailing duties. The final determinations for both investigations will be issued on November 13, 2025.</p>
<p>In February 2025, the United States International Trade Commission (USITC) <a href="https://www.mercomindia.com/us-anti-dumping-investigations-anode-material-china" target="_blank" rel="noopener">determined</a> that imports of active anode material from China were being sold at unfairly low prices because of subsidies by the Chinese government.</p>
<p>The investigations commenced with the American Active Anode Material Producers <a href="https://mercomindia.com/us-anode-material-producers-seek-920-tariff-on-graphite-imports-from-china" target="_blank" rel="noopener">filing</a> petitions with Commerce and USITC seeking the imposition of 920% tariffs on imports of natural and synthetic graphite from China to make lithium-ion battery anode material.</p>
<p>Active anode material is one of the primary components in lithium-ion batteries, which power electric vehicles, consumer electronics, medical equipment, and various other applications.</p>
<p>According to the petitioners, the demand for higher tariffs on graphite imports from China comes from years of significant volumes of imports from China. While most graphite from China is currently subject to 25% tariffs, the imposition of duty is inadequate.</p>
<p>In September 2024, the Office of the U.S. Trade Representative <a href="https://www.mercomindia.com/us-tariff-increases-on-solar-ev-imports-from-china-to-start-september-27-2024" target="_blank" rel="noopener">announced</a> that Chinese-manufactured electric vehicles would carry a 100% tariff and a 50% tariff on solar cells. A 25% tariff applies to EV batteries, critical minerals, aluminum, and steel.</p>
<p>According to recent data, China’s battery industry overcapacity has <a href="https://www.mercomindia.com/us-anti-dumping-investigations-anode-material-china" target="_blank" rel="noopener">surged</a> to four times the demand, driven by state-sponsored industrial policies, low or non-existent wage protections, and weak environmental regulations.</p>
<p>China’s battery industry overcapacity has <a href="https://www.mercomindia.com/us-anti-dumping-investigations-anode-material-china" target="_blank" rel="noopener">surged</a> to four times the demand, driven by state-sponsored industrial policies, low or non-existent wage protections, and weak environmental regulations. The American Active Anode Material Producers alleged that China’s ability to overproduce goods is part of a deliberate strategy enabled by extensive subsidies and financial incentives provided by the Chinese government.</p>


US Sets Preliminary Countervailing Duties on Chinese Active Anode Material


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					</table><p>The increasing integration of renewable energy continues to stress India’s electricity grid, causing repeated frequency fluctuations. The grid has seen persistent high frequency above the ceiling on 39 days in the third and fourth quarters of the financial year 2024-25, triggering concerns among grid operators and regulators.</p>
<p>The frequency was above the Indian Electricity Grid Code (IEGC) band of 49.90-50.05 Hz for over 20% of the time on these days during the two quarters.</p>
<p>The high-frequency periods were attributed to increased levels of solar power injection and the limited flexibility to reduce thermal generation to accommodate renewable energy production. On certain days, the down reserves during solar hours were completely depleted.</p>
<p>Adding to the challenge is the requirement that thermal power projects run during non-solar hours to ensure resource adequacy. These projects cannot be taken out of service during the high-frequency operation period.</p>
<p>According to a presentation made by <a href="https://posoco.in/en/" target="_blank" rel="noopener">Grid-India</a> to the National Committee on Transmission in April this year, the current maximum instantaneous penetration of variable renewable energy has touched ~37%. It is expected to cross 40% in February-March 2026, likely exacerbating the situation.</p>
<p>Another challenge being faced is meeting the ramping requirement during evening hours. During this period, flexibility requirements increased significantly due to the increasing demand ramp and the simultaneous decline in solar generation.</p>
<p>The grid has recently experienced many high-frequency operations. For three days in August 2024, high frequency above the ceiling of 50.05 Hz was witnessed 26% to 38% of the time. All three days were Sundays, when power demand usually drops. The contributing factors were the over-injection of solar and wind energy, limited flexibility from hydropower stations, and pumped storage projects.</p>
<p>These high-frequency episodes prompted the Central Electricity Regulatory Commission (CERC) to issue directions to the national, regional, and state load despatch centers to ensure grid frequency remains close to 50 Hz. It said all users must adhere to their schedule of injection or drawal.</p>
<p>Power generator NTPC had told CERC that under IEGC-2023, generators have a supply obligation. However, beneficiaries have no corresponding obligation to give equal to or more than the minimum turndown level (MTL) schedules required for safe and reliable operations of the thermal power generating stations.</p>
<p>This has allowed beneficiaries to give schedules based on their consideration and ignore the technical requirement of the thermal units, resulting in stations continuing to receive infeasible schedules (full schedule during peak hours and negligible or less than MTL schedule during off-peak hours).</p>
<p>The central regulator noted that thermal station over-injection in a time block reached as high as 2,200 MW last August.</p>
<p>It suggested that a two-shift operation of some thermal plants be considered to address the challenges faced in meeting the demand during evening hours with thermal power and low demand for such power during solar hours.</p>


Operators Struggle to Balance Solar with Thermal Power as Grid Woes Rise


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					</table><p>The Kerala State Electricity Regulatory Commission (<a title="https://www.erckerala.org/" href="https://www.erckerala.org/" target="_blank" rel="noreferrer noopener">KSERC</a>) has approved a time-of-day tariff for electric vehicle (EV) charging stations during solar hours, from 9 AM to 4 PM, which will be 30% lower than the ruling tariff.</p>
<p>This update aims to encourage EV users to charge their vehicles during solar hours. The tariff during solar hours is 0.7 times the average ruling tariff, while the tariff during non-solar hours is 1.3 times the average.</p>
<p>The Commission also approved single-part tariffs for EV charging stations with exemption from fixed or demand charges.</p>
<p>EV charging stations will be allowed to adjust the energy exported from the solar installations between 9 AM and 4 PM against the electricity imported within the same timeframe during a billing cycle without any charges, including fixed and grid support charges, energy adjustment, etc., until further notice.</p>
<p>The electricity exported during non-solar hours will be adjusted against electricity imported during this period in a billing cycle without any charges, including fixed and grid support charges and energy adjustments.</p>
<p>If surplus solar energy is exported during solar hours that has not been utilized for offsetting imports in the same period, this surplus can be used to offset imports during non-solar hours.</p>
<p>However, this cross-time adjustment is subject to a conversion factor. For every 13 units of surplus solar energy exported during solar hours, only seven units can offset imports during non-solar hours. This adjustment will also incur no additional charges.</p>
<p>Any surplus energy at the end of the billing period after the adjustments mentioned above will be banked and carried forward to the subsequent periods up to the settlement period (April 1 to March 31). This surplus can be used for adjusting against the energy consumption on payment of 5% banking charges of the total energy banked and grid support charges.</p>
<p>Any net surplus energy from solar may be settled at the average pooled power purchase cost or other rates approved by the Commission.</p>
<p>EV charging stations with solar systems can also install a battery energy storage system to store the surplus available solar power.</p>
<p>The Ministry of Power <a href="https://www.mercomindia.com/ministry-of-power-releases-ev-charging-infrastructure-guidelines" target="_blank" rel="noopener">released</a> guidelines for installing and operating EV charging stations. According to the guidelines, any entity can establish a charging infrastructure, and setting up and operating EV charging stations is a de-licensed activity.</p>
<p>Subscribe to Mercom&#8217;s real-time <a href="https://www.mercomindia.com/product/mercoms-renewable-energy-regulatory-updates" target="_blank" rel="noopener">Regulatory Updates</a> to ensure you do not miss any critical updates from the renewable industry.</p>


Kerala Updates Solar Hour Tariffs for EV Charging Stations


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					</table><p>Premier Energies (<a href="https://www.premierenergies.com/" target="_blank" rel="noopener">PEL</a>) has entered into a joint venture agreement with Taiwan-based Sino-American Silicon Products (<a href="https://www.saswafer.com/en/" target="_blank" rel="noopener">SAS</a>) to manufacture and sell silicon solar wafers in India.</p>
<p>Premier will hold a 74% equity stake in Premier Energies GWC, and SAS will hold the remaining 26%. Premier Energies GWC is currently Premier’s wholly owned subsidiary with an authorized share capital of ₹1 million (~$11,740).</p>
<p>The joint venture will establish a 2 GW manufacturing facility in India to produce advanced solar wafers for domestic and global markets. It will cut polysilicon ingots into silicon wafers for manufacturing photovoltaic cells and modules. This partnership leverages Premier’s manufacturing capacity with SAS’s semiconductor wafer technology.</p>
<p>The board of directors will have four members, with Premier nominating three and SAS one.</p>
<p>Premier Energies has also entered into a joint venture with <a href="https://www.nuevosol.co.in/" target="_blank" rel="noopener">Nuevosol Energy</a> to form Premier-Green Aluminium, focusing on the foundry and extrusion of aluminum frames specifically for solar modules. This Telangana-based initiative is expected to have a production capacity of 36,000 million tons per annum.</p>
<p>The aluminum frames joint venture’s authorized share capital is ₹1 million (~$11,740). It aims to serve the Indian market by establishing a state-of-the-art manufacturing facility to meet domestic and captive requirements.</p>
<p>Premier’s equity stake in Premier-Green Aluminium, currently its wholly owned subsidiary, will change to 80% after the agreement. Nuevosol Energy will hold the remaining 20% in the joint venture.</p>
<p>The joint venture’s board of directors will comprise five members, with Premier  nominating four and Nuevosol one. This collaboration aims to provide Premier with better control over module component quality and ensure supply chain reliability to strengthen its position in the solar energy sector.</p>
<p>Capital contributions for both joint ventures will be made per the agreed shareholding ratios during project implementation.</p>
<p>In December 2024, Premier Energies Global Environment, a subsidiary of Premier Energies, <a href="https://www.mercomindia.com/premier-energies-to-set-up-1-gw-solar-module-facility-in-telangana" target="_blank" rel="noopener">announced</a> the setting up of a 1 GW solar module manufacturing facility at the EMC Maheshwaram industrial zone in Telangana.</p>
<p>In August 2024, North America-based solar module manufacturer Heliene <a href="https://www.mercomindia.com/heliene-premier-energies-to-manufacture-solar-cells-in-the-u-s" target="_blank" rel="noopener">announced</a> a joint venture with Premier Energies to establish a solar cell manufacturing facility in the U.S.</p>


Premier Energies Partners with Sino-American for Solar Wafer Manufacturing


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					</table><p>REC Power Development and Consultancy (<a href="https://www.recpdcl.in/" target="_blank" rel="noopener">RECPDCL</a>) has invited bids to establish an interstate transmission system (ISTS) in Davanagere and Chitradurga, Karnataka, to integrate renewable energy generation. The project will be executed on a build, own, operate, and transfer basis.</p>
<p>Bids must be submitted by July 18, 2025. Bids will be opened on the same day.</p>
<p>The Ministry of New and Renewable Energy has identified a renewable energy potential of 4 GW in Davanagere/ Chitradurga. The transmission system for integrating 2 GW of renewable energy is already under implementation. Connectivity of about 1,850 MW has been granted/agreed for grant at Davanagere PS with the transmission system.</p>
<p>Additionally, applications for connectivity of about 1,325 MW have been received at Davanagare PS. In light of this, additional system strengthening at Davanagare is required to grant connectivity.</p>
<p>Bidders must furnish a document fee of ₹500,000 (~$5,870) plus GST and a bid bond of ₹78 million (~$915,720).</p>
<p>Successful bidders must submit a performance guarantee of ₹195 million (~$2.29 million).</p>
<p>Selected bidders must install four 500 MVA, 400/220 kV ICTs (5th-8th) at Davanagere pooling station (PS), along with associated 400 kV and 220 kV ICT bays. They must also augment Davanagere/Chitradurga PS with one 1500 MVA, 765/400 kV ICT, complete with its 765 kV and 400 kV ICT bays.</p>
<p>Two 220 kV line bays will also be added at Davanagere/Chitradurga PS to terminate dedicated transmission lines from renewable energy generation projects.</p>
<p>The scheduled commercial operation date (COD) for the 765/400 kV, 1&#215;1500 MVA ICTS augmentation is 24 months.</p>
<p>The scope of work also includes the engineering, procurement, construction, financing, and commissioning of the ISTS. Additionally, it involves providing operation and maintenance (O&amp;M) services for 35 years from COD.</p>
<p>After the O&amp;M period, all project assets, including the substation land, right of way, and clearances, will be transferred to the Central Transmission Utility or its successors at zero cost and free from encumbrance.</p>
<p>Bidders must have completed projects worth at least ₹5 billion (~$11.74 million) in the last five years. Each project must have had a minimum value of ₹1 billion (~$58.7 million). Alternatively, construction payments received for these projects must have exceeded ₹5 billion (~$ 11.74 million) in the same period.</p>
<p>Bidders must have a minimum net worth of ₹2.5 billion (~$29.35 million) in any of the last three years, with no negative net worth reported in those years.</p>
<p>Recently, RECPDCL <a href="https://www.mercomindia.com/recpdcl-tenders-intrastate-transmission-line-for-400-kv-substation-in-karnataka" target="_blank" rel="noopener">invited</a> proposals to set up an intrastate transmission system to establish a 400 kV substation and associated transmission lines in Karnataka’s Belagavi district on a build, own, operate basis.</p>
<p>Subscribe to Mercom’s <a href="https://mercomindia.com/product/india-solar-tender-tracker/" target="_blank" rel="noopener">India Solar Tender Tracker</a> to stay on top of tender activity in real-time.</p>


RECPDCL Invites Bids for Transmission System Augmentation in Karnataka


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					</table><p><a href="https://www.pfcclindia.com/" target="_blank" rel="noopener">PFC Consulting</a> has invited bids to establish an interstate transmission system to evacuate 3 GW from Kurnool IV Renewable Energy Zone Phase II, Andhra Pradesh.</p>
<p>The last date to submit bids is July 8, 2025. Bids will be opened on the same day.</p>
<p>Bidders must submit a bid bond of ₹434 million (~$5.14 million) and a contract performance guarantee of ₹1.08 billion (~$12.79 million).</p>
<p>They must submit a bid document fee of ₹500,000 (~$5,921).</p>
<p>The scope of work covers establishing 4&#215;1500 MVA, 765/400 kV &amp; 4&#215;500 MVA, 400/220 kV Kurnool-IV Pooling Station (PS) near Kurnool, along with 2&#215;330 MVAr 765 kV bus reactors at Kurnool-IV PS. It includes a provision for two sections of 4500 MVA each at the 400 kV level.</p>
<p>It also entails setting up 765 kV D/C line dedicated lines from Kurnool-IV – Bidar with 330 MVAr SLR. Additionally, a 765 kV D/C line from Kurnool-IV – Kurnool-III PS with 240 MVAr SLR must be set up.</p>
<p>Bidders must construct a 300 MVAr static synchronous compensator at Kurnool-IV, and 2&#215;125 MVAr monitoring and system response.</p>
<p>The project covers the augmentation of a 1500 MVA and a 765/400 kV transmission system utilizing information and communication technology at C’Peta.</p>
<p>Successful bidders are responsible for the project&#8217;s establishment, operation, and maintenance on a build, own, operate, and transfer basis.</p>
<p>They must complete all the activities for the project, including a survey, detailed project report formulation, arranging finance, and project management.</p>
<p>Bidders must procure consents, clearances, and permits, and pay the land compensation for the project.</p>
<p>The project will be completed within 30 months.</p>
<p>The Indian government has identified 51 GW of renewable energy potential in Andhra Pradesh and 23 GW in Kurnool.</p>
<p>The transmission capacity of Kurnool is being augmented in two phases. Phase one of the augmentation works is already in progress.</p>
<p>Andhra Pradesh has received approval for connectivity for 4.3 MW under Phase I and a request for another 3.2 GW.</p>
<p>Successful bidders must have developed infrastructure projects with aggregate capital expenditure of at least ₹21.7 billion (~$257 million) in the last five years. The capital expenditure for each project must be at least ₹4.34 billion (~$51.4 million).</p>
<p>Alternatively, they must have constructed infrastructure projects with an aggregate payment of at least ₹21.7 billion (~$257 million) in the last five years. The aggregate payment for each project must be at least ₹4.34 billion (~$51.4 million).</p>
<p>Successful bidders must have a network of at least ₹8.68 billion (~$102.8 million).</p>
<p>In September 2024, the company <a href="https://www.mercomindia.com/pfc-tenders-transmission-system-for-renewable-energy-evacuation" target="_blank" rel="noopener">issued</a> a request for proposal to select a transmission service provider to establish an interstate transmission System at Kurnool-III PS, Andhra Pradesh, to integrate an additional 4.5 GW of renewable energy.</p>
<p>In April 2025, Resonia (Sterlite Power) <a href="https://www.mercomindia.com/sterlite-power-bags-transmission-project-to-evacuate-4-5-gw-renewable-energy" target="_blank" rel="noopener">bagged</a> PFC Consulting’s transmission works to augment the interstate transmission system at the Ananthapur-II Renewable Energy Zone (Phase I) in Andhra Pradesh to evacuate 4.5 GW of renewable energy.</p>
<p>Subscribe to Mercom’s <a href="https://www.mercomindia.com/product/india-solar-tender-tracker" target="_blank" rel="noopener">India Solar Tender Tracker</a> to stay on top of real-time tender activity.</p>


PFC Consulting Invites Bids to Evacuate 3 GW Renewable Energy from Kurnool


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					</table><p>Distribution companies (DISCOMs) owed power generators ₹717.5 billion (~$8.51 billion) in total dues for the monthly billing cycle in April 2025, according to the <a href="https://powermin.gov.in/" target="_blank" rel="noopener">Ministry of Power</a>’s payment ratification and analysis portal <a href="https://praapti.in/" target="_blank" rel="noopener">PRAAPTI</a>.</p>
<p>The DISCOMs owed power generators ₹528.6 billion (~$6.17 billion) in March.</p>
<p>The outstanding dues, excluding the latest monthly dues of ₹444.42 billion (~$5.27 billion), are ₹273.07 billion (~$3.24 billion).</p>
<p>The overdue before the trigger date is ₹272.72 billion (~$3.23 billion), after which the amount will increase by ₹343.3 million (~$4.07 million) because of the late payment surcharge.</p>
<p>The trigger date is one month after the payment due date or two and a half months after the generating company presents the bill, whichever is later.</p>
<p>The DISCOMs are allowed to pay the outstanding amount in up to 48 installments.</p>
<p>Uttar Pradesh DISCOMs had the highest dues at ₹98.41 billion (~$1.16 billion), followed by Maharashtra at ₹65.64 billion (~$779.2 million) and Andhra Pradesh at ₹60.04 billion (~$712.72 million).</p>
<p>Gujarat’s DISCOMs <a href="https://www.mercomindia.com/gujarat-discoms-continue-to-top-annual-ratings-telangana-lags-behind/" target="_blank" rel="noopener">continued</a> to top the Ministry of Power’s thirteenth annual integrated ratings, with all four DISCOMs retaining their A+ ratings. Four of the top-rated DISCOMs are from Gujarat, three from Odisha, two from Haryana, and one each from Maharashtra and Uttar Pradesh. All Andhra Pradesh and Telangana DISCOMs were downgraded in the latest ratings.</p>
<p>In November last year, the Grid Controller of India <a href="https://www.mercomindia.com/update-rules-late-payment-surcharge/" target="_blank" rel="noopener">released</a> an updated procedure to implement the Electricity (Late Payment Surcharge and Related Matters) Rules 2022 and subsequent amendments. The procedure applies to intra-state and inter-state generators, licensees, and distribution entities, focusing on payment security, power scheduling, and addressing non-payment scenarios.</p>
<p>In October last year, the Ministry of Power <a href="https://www.mercomindia.com/rules-strengthen-discoms-financial-disclosure" target="_blank" rel="noopener">issued</a> the Electricity Distribution (Accounts and Additional Disclosure) Rules to improve transparency in financial disclosures and support regulatory compliance for DISCOMs. The rules aim to ensure financial safeguards against long-term defaults by mandating provisions for receivables and enforcing the reporting of trade receivable days.</p>


DISCOM Dues to Power Generators Rise to ₹717 Billion in April 2025


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					</table><p>The Central Electricity Regulatory Commission (<a href="https://cercind.gov.in/" target="_blank" rel="noopener">CERC</a>) has issued directions to power exchanges, focusing on reforming contract design, trading mechanisms, and operational transparency.</p>
<p>The principal trigger for this order was the consistent price deviation in day-ahead contingency (DAC) contracts from the day-ahead market (DAM), alongside concerns of potential manipulation and market fragmentation caused by overly flexible contract structures.</p>
<p>The need for intervention became particularly pressing after stakeholders and the Ministry of Power flagged steep and sustained price premiums in DAC contracts beginning in October 2023. These deviations were seen as a digression from their intended role of addressing short-term grid imbalances following the closure of DAM rather than becoming a parallel price discovery platform with distorted outcomes.</p>
<p>The power exchanges had, over time, introduced a variety of new contracts beyond their original offerings. While day-ahead contracts were the only available option in 2008, the regulatory framework evolved to permit additional instruments such as the day-ahead contingency, intra-day, real-time market (RTM), term ahead (daily, weekly, monthly), green contracts, and any-day single sided (ADSS) contracts. These additions were made to accommodate the increasing complexity of grid operations, including higher renewable energy penetration, and to cater to the procurement flexibility needed by distribution companies (DISCOMs) and large consumers.</p>
<p>However, this evolution had unintended consequences. One central issue CERC <a href="https://www.mercomindia.com/cerc-changes-price-discovery-mechanisms" target="_blank" rel="noopener">identified</a> was the excessive granularity in term ahead market (TAM) contracts. The exchanges had introduced overlapping and user-defined delivery slots, which fragmented market liquidity and undermined the standardization essential for robust competition.</p>
<p>In some cases, buyers were effectively crafting bespoke contracts, which ran counter to the regulatory intent of having pre-specified time blocks to consolidate trading volumes. The Commission concluded that while customization offers flexibility, it also increases price manipulation risks and reduces the depth of each trading window.</p>
<p>Consequently, it directed all power exchanges to cease offering user-defined time slots and restrict trading to a set of standardized contracts, including those based on established blocks like round-the-clock (RTC), peak, off-peak, and night.</p>
<p>Similar concerns were raised about the operation of ADSS contracts. Originally introduced to allow buyers to specify delivery days and time blocks for purchase requests, the ADSS mechanism had, in practice, become prone to inefficiencies. Buyers were found to be issuing multiple requisitions across different exchanges for the same demand, often with extended acceptance windows of up to 28 days.</p>
<p>This practice led to uncertainty and sellers&#8217; artificial blocking of capacity as they awaited confirmation or rejection from buyers. Additionally, some exchanges offered rebates or waived auction initiation fees if trades failed to materialize, further encouraging non-serious participation.</p>
<p>To curb these issues, CERC mandated strict timeframes for each stage of the ADSS contract process: a bid receiving window capped at 48 hours, an initial public offering auction not exceeding two hours, a reverse auction lasting a minimum of two hours (extendable until midnight), and a final acceptance window also capped at 48 hours, excluding the reverse auction date. Exchanges were also instructed to collect a declaration from buyers if they had listed similar requisitions on other platforms and to discontinue any practice of waiving auction fees, thus ensuring only serious bids reach the trading floor.</p>
<p>A significant structural change ordered by the Commission relates to the price discovery mechanism used in DAC contracts. Until now, DAC contracts used a continuous matching model, where trades were executed as and when matching bids were found. This simple model allowed for disparities in the price paid by different participants for the same time block, introducing inefficiency and the potential for abuse. Given the increased liquidity in the DAC segment over recent years, CERC has called for a shift to a uniform price-step auction model.</p>
<p>This mechanism aggregates all bids and clears them at a single market price to enhance transparency and fairness. The Commission reasoned that such an auction-based model would prevent anti-competitive practices and support more predictable pricing. While stakeholders had mixed reactions—some preferring the predictability of continuous matching—the regulator determined that the benefits of unified pricing outweighed the operational trade-offs.</p>
<p>The Commission also acknowledged the potential challenges of migrating to an auction-based mechanism, especially regarding the time required for bid finalization. To mitigate these issues, it supported a proposal to split the DAC trading window (currently from 13:00 to 23:30 hours) into multiple smaller auction sessions to preserve market responsiveness.</p>
<p>Additionally, it rejected a proposed interim mechanism requiring the display of bids for ten minutes before matching, citing the technical and financial burden on exchanges. Instead, it asked power exchanges to formally propose system changes, following which CERC would review and approve the new contract specifications.</p>
<p>In contrast to the changes in DAC, the intra-day market was spared withdrawal despite longstanding concerns about its low liquidity. Stakeholders, including DISCOMs and green energy producers, defended the utility of intra-day contracts, noting that they complement RTM by offering alternative paths for energy procurement when real-time prices spike or bids go unfulfilled. Recognizing this, the Commission retained intra-day contracts but required delivery timeline standardization across exchanges.</p>
<p>It also encouraged using &#8220;market&#8221; order types—where participants agree to transact at prevailing best prices—instead of fixed-price bids to streamline operations and increase the likelihood of successful trades. Simultaneously, the Commission ordered Power Exchange India to discontinue its &#8220;dynamic&#8221; contracts in the intra-day and DAC segments, as they deviated from the standardized design essential for a competitive marketplace.</p>
<p>Lastly, to bolster market transparency, the CERC directed all power exchanges to publicly display the number and volume of buy and sell bids submitted for all contingency and term ahead contracts alongside the usual data on executed trades. This initiative aims to equip stakeholders with better market intelligence and foster greater accountability in trading behavior.</p>
<p>In April this year, CERC <a href="https://www.mercomindia.com/cerc-seeks-feedback-on-iexs-proposal-for-real-time-green-energy-trading" target="_blank" rel="noopener">invited</a> stakeholder feedback by April 23, 2025, on a proposal by the Indian Energy Exchange to introduce real-time trading in renewable energy.</p>
<p>Subscribe to Mercom&#8217;s real-time <a href="https://www.mercomindia.com/product/mercoms-renewable-energy-regulatory-updates" target="_blank" rel="noopener">Regulatory Updates</a> to ensure you don&#8217;t miss any critical updates from the renewable industry.</p>


CERC Cracks Down on Flexible Power Contracts to Curb Market Manipulation


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					</table><p>Japan-based multinational electronics manufacturer <a href="https://na.panasonic.com/" target="_blank" rel="noopener">Panasonic</a>&#8216;s North American division has announced discontinuing its solar and battery storage business.</p>
<p>&#8220;We have made the decision to discontinue our solar and battery storage business line. This change allows us to focus on areas where we can have the greatest strategic impact,&#8221; Panasonic said on its website.</p>
<p>Despite this closure, the company has emphasized its commitment to a smooth transition, assuring continued customer support for existing and future installations.</p>
<p>Panasonic stated that all warranties will be honored for both installed products and those not yet installed. In cases where third-party warranties apply, the company will provide clear guidance and points of contact to assist customers.</p>
<p>​However, Panasonic Life Solutions India has clarified that the restructuring in the U.S. has no impact on its India operations. It said India will continue to be a key strategic growth market. The company will remain focused on scaling its solar business to meet the country&#8217;s increasing demand for clean and sustainable energy.</p>
<p>Panasonic&#8217;s solar and battery storage portfolio has been centered around the EVERVOLT product line, which includes the EVERVOLT Black Series solar modules, EVERVOLT Home Battery, EVERVOLT SmartBox energy storage systems, and the EVERVOLT hybrid inverter.</p>
<p>The company&#8217;s entry into the solar space began in the 1970s, focusing on research and development. A significant milestone occurred in 2009 when Panasonic acquired Sanyo Electric. Sanyo had developed solar cell technology known as Heterojunction with Intrinsic Thin layer (HIT), which became the foundation of Panasonic&#8217;s solar modules.</p>
<p>Leveraging HIT technology, Panasonic established itself as a player in the residential and commercial solar markets, particularly in Japan, North America, and Europe.​</p>
<p>Throughout the 2000s and 2010s, Panasonic continued to invest in the solar energy sector, launching solar solutions that included battery storage, energy management systems, and smart home integrations. The company also partnered with Tesla to produce solar cells at the Gigafactory in Buffalo, New York.</p>
<p>In 2021, Panasonic <a href="https://www.mercomindia.com/panasonic-to-wind-up-solar-business" target="_blank" rel="noopener">announced</a> plans to wind down its solar manufacturing operations in Malaysia and Japan, with production ceasing by March 2022. The decision was driven by mounting price competition, especially from Chinese manufacturers, combined with declining profitability and rapid technological shifts in the global solar market.</p>
<p>After shutting down its own factories, Panasonic transitioned to an original equipment manufacturer model, outsourcing production while continuing to market solar products under the Panasonic EVERVOLT brand.</p>
<p>However, increasing market competition and falling panel prices led Panasonic to exit in-house solar manufacturing in 2022, transitioning to an OEM model while maintaining the EVERVOLT product line through partnerships.</p>
<p><em>(The article has been updated with Panasonic clarifying that there will be no impact of the decision on its India operations)</em></p>


Panasonic North America Exits Solar and Battery Storage Business


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					</table><p>Electric two-wheeler company <a href="https://www.google.com/aclk?sa=l&amp;ai=DChcSEwiYhqzjyv-MAxULqWYCHSmEH8cYABAAGgJzbQ&amp;co=1&amp;gclid=Cj0KCQjwlMfABhCWARIsADGXdy_UTvUOwtyAb1xCJX-u6mAcgrWekJhwzU-IE3Ji1LZcbidUEkxe4bUaAq-BEALw_wcB&amp;ei=QQASaILJKMjG4-EPy575-AE&amp;sig=AOD64_3o0gk1TGEnHQeafVjf61QTaYFbLw&amp;q&amp;sqi=2&amp;adurl&amp;ved=2ahUKEwjC7afjyv-MAxVI4zgGHUtPHh8Q0Qx6BAgXEAE" target="_blank" rel="noopener">Ather Energy’s </a>₹31 billion (~$363.92 million) initial public offering (IPO) was oversubscribed 1.43 times at the end of the bidding window on April 30, 2025.</p>
<p>The price band was set at ₹304-₹321 (~$3.56-$3.76) per equity share. The IPO saw bids for shares exceeding the shares on offer.</p>
<p>The IPO had an issue size of 53.36 million shares.</p>
<p>Retail investors led the demand, with a subscription rate of 1.78, followed by qualified institutional buyers at 1.7. The non-institutional investors’ portion was subscribed 0.66 times, and the employees’ portion 5.43 times.</p>
<p>The IPO saw an allocation of ₹41.75 million shares at an anchor investor allocation price of ₹321 (~$3.76) to 36 anchor investors and seven domestic mutual funds</p>
<p>The shares will likely be listed on the BSE and NSE on May 6, 2025.</p>
<p>Ather <a href="https://www.mercomindia.com/electric-two-wheeler-firm-ather-energy-files-ipo-to-raise-%E2%82%B9370-million" target="_blank" rel="noopener">filed</a> its draft red herring prospectus (DRHP) in September 2024.</p>
<p>The company will utilize ₹9.27 billion (~$108.82 million) from the net proceeds towards constructing a factory with a capacity of manufacturing 1 million electric two-wheelers/year at Chhatrapati Sambhajinagar, Maharashtra. The manufacturing plant is expected to be commissioned in March 2027.</p>
<p>It will also utilize ₹7.5 billion (~$88.04 million) from the net proceeds towards research and development works, including designing and developing key electric two-wheeler components, a new motorbike platform, Atherstack, accessories, and charging technology.</p>
<p>It will utilize ₹3.78 billion (~$44.37 million) towards repayment/prepayment of borrowings. According to the DRHP, the company has a total outstanding borrowing of ₹6.7 billion (~$78.65 million) as of July 31, 2024.</p>
<p>Additionally, ₹3 billion (~$35.21 million) of the net proceeds will be used for marketing initiatives, and the remaining will be used for corporate purposes.</p>
<p>In April 2025, solar engineering, procurement, and construction company Prozeal Green Energy <a href="https://www.mercomindia.com/prozeal-green-energy-files-draft-papers-for-7-billion-ipo" target="_blank" rel="noopener">filed</a> its DRHP for a ₹7 billion (~$81.81 million) IPO with the market regulator, the Securities and Exchange Board of India.</p>
<p>In December 2024, green power producer Continuum Green Energy <a href="https://mercomindia.com/continuum-green-energy-files-draft-papers-for-%E2%82%B936-5-billion-ipo" target="_blank" rel="noopener">filed</a> its DRHP to raise over ₹36.5 billion (~$430.10 million) through an IPO.</p>
<p>In November 2024, NTPC Green Energy’s ₹100 billion (~$1.19 billion) IPO was <a href="https://www.mercomindia.com/ntpc-green-energy-ipo-oversubscribed" target="_blank" rel="noopener">oversubscribed</a> 2.42 times at the end of the bidding window on November 22, 2024.</p>


Ather Energy’s ₹31 Billion IPO Oversubscribed By 1.43 Times


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					</table><p>Hydrogen can be officially recognized as &#8220;green&#8221; only if its non-biogenic greenhouse gas emissions do not exceed 2 kg of CO₂ equivalent (CO₂e)/kg of hydrogen, averaged over 12 months, under the newly introduced Green Hydrogen Certification Scheme of India (GHCI).</p>
<p>The GHCI, a critical component of the <a href="https://www.mercomindia.com/cabinet-approves-%E2%82%B9197-billion-hydrogen-mission" target="_blank" rel="noopener">National Green Hydrogen Mission</a>, aims to establish rigorous standards for GHG emissions, with robust monitoring and transparent verification procedures. By ensuring credibility and environmental integrity, the certification program targets building stakeholder confidence, attracting domestic and international investment, and advancing India&#8217;s policy objectives for carbon neutrality and global climate leadership.</p>
<p><strong>Types of Certificates </strong></p>
<p>The GHCI provides two categories of certification for hydrogen production facilities. The first is the concept certificate, a voluntary document confirming that the hydrogen production facility’s design meets the prerequisites under the GHCI&#8217;s monitoring, reporting, and verification framework. This certificate can be applied after the facility&#8217;s design or front-end engineering design is approved.</p>
<p>In contrast, the facility-level certificate is mandatory for facilities seeking provisional or final certificates for the hydrogen produced. This certificate confirms that the facility has fulfilled the monitoring, reporting, and verification framework requirements and has received the statutory &#8220;consent to operate.&#8221;</p>
<p>GHCI offers two types of certificates to certify actual hydrogen production. The provisional certificate is auto-generated and voluntary. It is issued based on the production data submitted by the producer and covers durations ranging from one to eleven months. However, the final certificate is compulsory in specific cases. These include instances where the producer receives government incentives, subsidies, or concessions, where the hydrogen is sold or used within India, and where the facility serves domestic and export markets.</p>
<p>Final certification is not required for small facilities producing less than ten tons annually, nor for producers who export 100% of their output without claiming government incentives. However, such producers must still report emissions per the destination country&#8217;s standards.</p>
<p><strong>System Boundaries and Emission Accounting</strong></p>
<p>The system boundaries defined under GHCI include all direct and indirect emissions from processes within the production facility. These encompass emissions from water treatment, electrolysis, purification, compression, onsite storage in the case of electrolysis, and additional steps such as biomass processing and steam generation for biomass-based pathways.</p>
<p>Offsite emissions from water treatment may be accounted for using default values, while emissions related to capital goods and construction are excluded.</p>
<p>The emission calculation also incorporates input materials such as water, oxygen, and solvents, provided they are sourced externally. The certificate must also document the final hydrogen composition and production pressure.</p>
<p><strong>Production Pathways</strong></p>
<p>Only two hydrogen production pathways are eligible under GHCI: electrolysis and biomass conversion, including biogas reforming and gasification. However, stakeholders may propose additional pathways, which the technical committee will review.</p>
<p><strong>Renewable Energy Usage </strong></p>
<p>Renewable electricity is a cornerstone of green hydrogen production under this program. The GHCI requires that producers demonstrate the use of renewable electricity via verifiable mechanisms such as power purchase agreements and load dispatch certificates. Renewable energy must be physically sourced, either stored or banked with the grid and cannot be claimed based on renewable energy certificates or carbon credits.</p>
<p><strong>Data Recording and Monitoring Protocols</strong></p>
<p>To maintain transparency, GHCI mandates detailed record-keeping for at least five years. These records must include daily hydrogen production logs, physical and chemical parameters, energy consumption data, feedstock usage, and other production-related inputs. Producers must also maintain information on sales and whether the hydrogen was further processed into carriers. Although commercial data such as offtake contracts is exempt from certification documentation, all data is subject to verification by accredited carbon verification (ACV) agencies.</p>
<p><strong>GHG Emission Quantification</strong></p>
<p>GHG emissions must be calculated using the methodology defined in the GHCI or, where unspecified, using Indian or ISO standards such as ISO 14064 or ISO 19870:2023. Emission intensities must be rounded to one decimal place, and emissions from non-renewable sources are to be calculated using the grid emission factor published by the Central Electricity Authority. Transmission and distribution losses must also be factored into the emission intensity. The methodology supports the allocation of emissions to co-products using the energy content allocation method and addresses situations involving waste heat or externally sourced heat.</p>
<p><strong>Role of ACV Agencies</strong></p>
<p>ACV agencies, accredited by the <a href="https://beeindia.gov.in/en" target="_blank" rel="noopener">Bureau of Energy Efficiency</a>, play a critical role in the certification process. Their responsibilities include conducting independent audits, ensuring accurate GHG emission reporting, and promoting transparency and compliance. They help to uphold the certification’s credibility and support India&#8217;s broader climate goals by enabling projects to qualify for carbon credits under India&#8217;s Carbon Credit Trading Scheme (CCTS).</p>
<p><strong>ISO 19870:2023 </strong></p>
<p>ISO 19870:2023 is a significant reference in GHCI for assessing lifecycle GHG emissions. It provides a standardized framework for evaluating hydrogen production from resource extraction to consumption and supports attributional and consequential approaches. The standard facilitates policy formulation and investor confidence and supports global benchmarking and comparability of certification programs.</p>
<p><strong>Certification Timeline and Compliance Enforcement</strong></p>
<p>The certification process involves a structured timeline. Provisional certificates may be applied monthly, and final certificates must be applied by June 30 following the financial year. Issuance follows a thorough review by the technical committee, with final decisions due by September 30. In cases of discrepancy or non-compliance, extensions and penalties may apply. Certificates may be withdrawn if the verified emissions exceed the threshold or the producer fails to apply for the final certificate in time. Repeat violations within a three-year window can result in disqualification from applying in the next cycle. Continued non-compliance may lead to further sanctions.</p>
<p><strong>Features and Certification Validity</strong></p>
<p>Each certificate issued under GHCI carries a unique identifier for every 100 kg of hydrogen, along with the production year, project information, and emission intensity. While the certificates serve as proof of origin and ensure chain of custody, they also enable the producer to claim carbon credits, provided additional CCTS requirements are met. A fee of ₹5 (~$0.059)/100 kg is applicable for final certification. Other certificates are free of charge.</p>
<p>Monitoring of the programs&#8217;s implementation is conducted by a program monitoring committee chaired by MNRE’s secretary, with participation from other ministries and domain experts. The committee may recommend policy adjustments and help resolve implementation challenges. The program itself may be modified in the future with approval from the Minister of New and Renewable Energy.</p>
<p>In November last year, MNRE <a href="https://www.mercomindia.com/mnre-issues-innovation-in-green-hydrogen/" target="_blank" rel="noopener">unveiled</a> a program to support pilot projects exploring novel methods and pathways for green hydrogen production and use, particularly in residential, commercial, and decentralized applications.</p>


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