SJVN Issues Tenders for 7.15 MW Rooftop Solar Projects in Multiple States

Uttar Pradesh Regulator Approves 1,525 MW Solar Power Procurement

Andhra Pradesh Regulator Approves PPAs for 400 MW Wind-Solar Projects

Awareness of Energy Efficiency Benefits Among C&I Businesses Lacking: Interview

Daily News Wrap-Up: BPCL Announces 100 MW Wind Projects Auction Winners

Ballard Misses Revenue Expectations in Q1 2025 Despite 6% YoY Uptick

MNRE Lowers Module Efficiency Thresholds for Off-Grid Solar Projects

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

Gujarat Regulator Approves Tariff of ₹2.95/kWh for Solar Projects Under KUSUM

Suzlon and Integrum Bag BPCL’s 100 MW Wind Projects


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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>



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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>


Government Issues Green Hydrogen Certification Program


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					</table><p>REC Power Development and Consultancy (<a href="https://recpdcl.in/" target="_blank" rel="noopener">RECPDCL</a>) has invited bids to develop an interstate transmission system to evacuate power from Pumped Storage Projects (PSPs) in Sonbhadra district, Uttar Pradesh, under a build, own, operate, and transfer model.</p>
<p>Bids must be submitted by June 27, 2025. Bids will be opened on the same day.</p>
<p>Bidders must furnish an earnest money deposit of ₹380 million (~$4.43 million) and a tender document fee of ₹500,000 (~$5,835) plus 18% GST.</p>
<p>Successful bidders must pay success charges or acquisition price, notified by RECPDCL 20 days before the bid deadline.</p>
<p>The scope of work entails establishing the 765/400 kV Robertsganj pooling station, providing loop-in loop-out of the existing 765 kV Varanasi-Gaya transmission lines, constructing a new 765 kV double circuit transmission line to Prayagraj, installing switchable line and bus reactors, and developing future provision infrastructure.</p>
<p>Selected bidders must design a project to evacuate 3.25 GW of power injection and 3.7 GW of drawal capacity from three applications totaling 2,016 MW from <a href="https://www.greenkogroup.com/" target="_blank" rel="noopener">Greenko</a> and two applications totaling 1,716 MW from <a href="https://avaada.com/" target="_blank" rel="noopener">Avaada</a> for interstate distribution. They must also implement advanced 765/400 kV transmission infrastructure for seamless integration with the national grid.</p>
<p>Selected bidders will be responsible for the project’s survey, design, land acquisition, statutory clearances, construction, testing, and commissioning. They must also provide operation and maintenance services for 35 years.</p>
<p>The project must also incorporate public procurement preferences under the ‘Make in India’ guidelines. This compliance includes adhering to the Approved List of Models and Manufacturers and Renewable List of Models and Manufacturers for project components.</p>
<p>The project must be completed within 30 months from the agreemen date.</p>
<p>The 765/400 kV 1&#215;1500 MVA interconnecting transformer at Robertsganj pooling station must be completed by December 2030.</p>
<p>Bidders must have worked on infrastructure projects worth at least ₹19 billion (~$221.73 million), with a minimum cost of ₹3.8 billion (~$44.35 million)/project. Alternatively, they must have executed construction contracts of the same value over the last five years.</p>
<p>Bidders must have had a minimum net worth of ₹7.6 billion (~$88.70 million) in the last three financial years.</p>
<p>Recently, 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 interstate transmission system to evacuate 2,500 MW of renewable energy in Madhya Pradesh.</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 to Evacuate 3.7 GW Power from Pumped Storage Projects


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					</table><p>Corporate funding for energy storage companies, including venture capital (VC), debt, and public market financing, totaled $2.2 billion across 31 deals in Q1 2025, according to Mercom Capital Group’s newly released <a href="https://mercomcapital.com/product/q1-2025-funding-ma-report-energy-storage/" target="_blank" rel="noopener">Q1 2025 Funding and M&amp;A Report for Energy Storage</a>.</p>
<p>This represents an 81% year-over-year (YoY) drop from the $11.7 billion raised in 29 deals in Q1 2024.</p>
<p>Raj Prabhu, CEO of Mercom Capital Group, commented, “Last year, we had a couple of huge deals that amounted to almost $10 billion, which was an anomaly. So, in comparison, the year-over-year dollars raised look low this quarter.”</p>
<p><a href="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/Energy-storage-funding-image-for-upload.png"><img loading="lazy" decoding="async" class="aligncenter wp-image-78892 size-full" src="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/Energy-storage-funding-image-for-upload.png" alt="Energy storage funding" width="1490" height="973" srcset="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/Energy-storage-funding-image-for-upload.png 1490w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/Energy-storage-funding-image-for-upload-300x196.png 300w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/Energy-storage-funding-image-for-upload-768x502.png 768w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/Energy-storage-funding-image-for-upload-650x424.png 650w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/Energy-storage-funding-image-for-upload-624x407.png 624w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/Energy-storage-funding-image-for-upload-600x392.png 600w" sizes="(max-width: 1490px) 100vw, 1490px" /></a></p>
<p>Prabhu emphasized that ongoing geopolitical and policy uncertainties are driving the downturn. “Since the elections and the new administration taking office, there’s been significant uncertainty around key policies, especially regarding the continuation of subsidies for the battery storage and EV sectors. On top of that, steep import tariffs have been imposed on China and several other countries.”</p>
<p>“All of this is disrupting the supply chain and driving up costs. As a result, there’s a lot of uncertainty about what comes next,” he added.</p>
<p>VC funding for energy storage declined moderately by 8% YoY, with $1.1 billion raised in 18 deals, compared to $1.2 billion raised in 23 deals a year ago. Companies in the Materials &amp; Components category secured the largest portion of funding, followed by those in the Energy Storage Downstream segment and Battery Recycling, Software, and Lithium-based Battery companies.</p>
<p>Top VC funding rounds in Q1 2025 included KoBold Metals with $537 million, green flexibility with $411 million, Equilibrium Energy with $28 million, Sonocharge Energy with $24 million, and ACCURE Battery Intelligence with $16 million. These top five deals comprised the bulk of the sector’s VC investment.</p>
<p><a href="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/energy-storage-funding-image-2-for-uploading.png"><img loading="lazy" decoding="async" class="aligncenter wp-image-78894 size-full" src="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/energy-storage-funding-image-2-for-uploading.png" alt="Energy storage funding 2" width="544" height="421" srcset="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/energy-storage-funding-image-2-for-uploading.png 544w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/energy-storage-funding-image-2-for-uploading-300x232.png 300w" sizes="(max-width: 544px) 100vw, 544px" /></a></p>
<p>Debt and public market financing activity in the energy storage sector saw a 90% YoY decline, with $1.1 billion raised from 13 deals in Q1 2025, compared to $10.5 billion from six deals in Q1 2024.</p>
<p>Corporate M&amp;A activity also dropped significantly. Only one company acquisition was reported in Q1 2025, down from eight in the same quarter last year.</p>
<p>However, energy storage project mergers and acquisitions (M&amp;A) activity showed positive growth, with 15 projects acquired in Q1 2025, compared to just six in Q1 2024.</p>
<p><strong>Smart Grid</strong></p>
<p>Corporate funding for smart grid companies decreased by 23% YoY, with $530 million in 21 deals in Q1 2025 compared to $686 million raised in 14 deals during Q1 2024, according to Mercom Capital Group’s <a href="https://mercomcapital.com/product/q1-2025-funding-ma-report-smart-grid/" target="_blank" rel="noopener">Q1 2025 Funding and M&amp;A Report for Smart Grid</a>.</p>
<p>VC funding in the smart grid segment fell sharply by 47% YoY, with companies securing $346 million across 18 deals, compared to $656 million in 12 deals in the same quarter last year.</p>
<p>Smart charging companies drew the most VC investment within the segment during the quarter, underscoring continued interest in electric mobility infrastructure.</p>
<p><a href="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/smart-grid-funding-for-uploading.png"><img loading="lazy" decoding="async" class="aligncenter wp-image-78895 size-full" src="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/smart-grid-funding-for-uploading.png" alt="Smart grid funding" width="1455" height="960" srcset="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/smart-grid-funding-for-uploading.png 1455w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/smart-grid-funding-for-uploading-300x198.png 300w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/smart-grid-funding-for-uploading-768x507.png 768w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/smart-grid-funding-for-uploading-650x429.png 650w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/smart-grid-funding-for-uploading-624x412.png 624w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/smart-grid-funding-for-uploading-600x396.png 600w" sizes="(max-width: 1455px) 100vw, 1455px" /></a></p>
<p>Other key segments attracting funding included Grid Optimization, Data Analytics, Demand Response, Distributed Generation and Integration, and Smart Grid Communications.</p>
<p>The largest smart grid VC deal in Q1 2025 was Connected Kerb’s $81 million raise. This was followed by Smart Wires with $65 million, GreenWay with $54 million, Gridware with $26 million, and ecoplanet with $16 million. These top five deals accounted for over 70% of total smart grid VC funding during the quarter.</p>
<p><a href="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/smart-grid-funding-2-for-uploading.png"><img loading="lazy" decoding="async" class="aligncenter wp-image-78896 size-full" src="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/smart-grid-funding-2-for-uploading.png" alt="Smart grid funding 2" width="544" height="379" srcset="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/smart-grid-funding-2-for-uploading.png 544w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/smart-grid-funding-2-for-uploading-300x209.png 300w" sizes="(max-width: 544px) 100vw, 544px" /></a></p>
<p>In the area of debt and public market financing, smart grid companies raised $184 million from three deals in Q1 2025, significantly higher than the $30 million raised from two deals in Q1 2024.</p>
<p>On the M&amp;A front, three undisclosed transactions were reported in Q1 2025. This marked an increase from the single undisclosed M&amp;A transaction reported in Q1 2024.</p>
<p>On the outlook for the coming quarters, Prabhu noted, “Everything hinges on government action. Once trade deals are negotiated and tariffs are finalized, companies will have the clarity they need to move forward. Until then, the market remains in a wait-and-see mode.”</p>
<p>He added that uncertainty around the U.S. Inflation Reduction Act (IRA) and possible changes to investment tax credits are also fueling investor hesitation. “If those subsidies are reduced or removed, many projects simply won’t be viable. The market needs clarity before companies can commit to deals and move ahead.”</p>
<p>To learn more about the energy storage report, visit: <a href="https://mercomcapital.com/product/q1-2025-funding-ma-report-energy-storage/" target="_blank" rel="noopener">https://mercomcapital.com/product/q1-2025-funding-ma-report-energy-storage/</a></p>
<p>To learn more about the smart grid report, visit: <a href="https://mercomcapital.com/product/q1-2025-funding-ma-report-smart-grid/" target="_blank" rel="noopener">https://mercomcapital.com/product/q1-2025-funding-ma-report-smart-grid/</a></p>


Energy Storage Funding Declines Sharply in Q1 2025


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					</table><p>Santosh Kumar Sarangi, a 1994-batch Indian Administrative Service (IAS) officer from the Odisha cadre, has taken over as the new Secretary in the Ministry of New and Renewable Energy (<a href="https://mnre.gov.in/" target="_blank" rel="noopener">MNRE</a>).</p>
<p>He succeeds Nidhi Khare, a 1992-batch IAS officer who had been holding the additional charge of the post since January 2025. The Appointments Committee of the Cabinet approved Sarangi&#8217;s appointment.</p>
<p>Before this role, Sarangi served as the Director General in the Directorate General of Foreign Trade under the Ministry of Commerce and Industry. His administrative experience includes positions such as district magistrate in three districts of Odisha and leadership roles in departments related to education, tourism, mining, tribal affairs, and science and technology.</p>
<p>At the central level, he was a Joint Secretary in the Ministry of Commerce and Industry from 2013 to 2019. He also served as Chairman of the Agricultural and Processed Food Products Export Development Authority and the Tea Board of India.</p>
<p>More recently, he was the Additional Secretary in the Department of School Education and Literacy and concurrently chaired the National Council for Teacher Education.​</p>
<p>Sarangi holds a Master of Arts in Political Science from the University of Delhi and a Master&#8217;s in Public Policy from Duke University in North Carolina, USA.</p>
<p>Sarangi took over as MNRE Secretary when the Indian government set an agenda to install 500 GW of non-fossil fuel-based energy capacity by 2030. India added 25.2 GW of solar capacity in the calendar year 2024, a 204% increase compared to the 8.3 GW added in 2023. According to Mercom India&#8217;s latest <a href="https://www.mercomindia.com/product/q4-2024-india-solar-market-update" target="_blank" rel="noopener">Q4 and Annual 2024 India Solar Market Update Report</a>, this marks the highest annual capacity addition in the country&#8217;s history.</p>
<p>By the end of 2024, India&#8217;s total installed solar capacity stood at 98.7 GW, with large-scale solar projects making up 86% and rooftop solar installations contributing 14%. Solar energy represented over 21% of India&#8217;s total installed power capacity and nearly 47% of the country&#8217;s total renewable capacity.</p>


Santosh Kumar Sarangi Appointed as the New MNRE Secretary


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					</table><p>The Odisha Electricity Regulatory Commission (<a href="https://orierc.org/" target="_blank" rel="noopener">OERC</a>) has determined the aggregate revenue requirement (ARR), wheeling tariff, and retail supply tariff (RST) for the financial year (FY) 2025-26, retaining the existing tariff structure across all consumer categories.</p>
<p>The order applies to the four private distribution companies in Odisha- TP Central Odisha Distribution (TPCODL), TP Northern Odisha Distribution (TPNODL), TP Western Odisha Distribution (TPWODL), and TP Southern Odisha Distribution (TPSODL).</p>
<p>The Commission stated that the FY 2024–25 tariffs would continue unchanged because of inflationary pressures and the need to protect consumers from additional financial burden.</p>
<p>Alongside maintaining tariff stability, the Commission introduced new reconnection charges and application processing fees.</p>
<p><strong>Application Processing Fees</strong></p>
<p>The application processing fees have been standardized to streamline service-related requests. For low tension (LT) consumers, an application fee of ₹50 (~$0.60) will be applicable for services such as change of category, change of contract demand, or any correction in the consumer&#8217;s name, address, or ownership details (excluding changes to email ID or mobile number).</p>
<p>For high-tension (HT) and extra-high-tension (EHT) consumers, the same set of requests will attract a higher application fee of ₹1000 (~$12).</p>
<p><strong>Reconnection Charges</strong></p>
<p>For domestic LT single-phase consumers, the reconnection charge has been fixed at ₹300 (~$3.60), while for the other LT single-phase consumers, it will be ₹800 (~$9.65). LT three-phase consumers must pay ₹1200 (~$14.45).</p>
<p>For HT consumers, the reconnection charge is ₹6000 (~$72.30), and for EHT consumers, it is ₹10,000 (~$120.50).</p>
<p>These reconnection charges will not apply to consumers equipped with smart meters unless the disconnection occurs due to the meter&#8217;s tampering.</p>
<p>The order will be effective from April 1, 2025, to March 31, 2026.</p>
<p><strong>Fixed and Monthly Minimum Fixed Charges (MMFC)</strong></p>
<p>The MMFC for LT consumers have been retained. Domestic consumers will pay ₹20 (~$0.23)/kW for the first kW and each additional kW, while general-purpose LT consumers will pay ₹30 (~$0.35)/kW.</p>
<p>LT industrial (small) consumers will pay ₹80 (~$0.93) for the first kW and ₹35 (~$0.41) for each additional kW, while medium industrial consumers will pay ₹100 (~$1.16) for the first kW and ₹80 (~$0.93) for each additional kW.</p>
<p><strong>Demand and Customer Service Charges for HT and EHT Consumers</strong></p>
<p>For HT and EHT consumers, the demand charge remains ₹250 (~$2.90)/kVA. Additionally, these consumers must pay a customer service charge of ₹700 (~$8.12)/month. These charges help recover the fixed costs incurred by the DISCOMs in maintaining infrastructure and system reliability.</p>
<p><strong>LT Category Energy Charges</strong></p>
<p>LT consumers will be billed at a flat rate of ₹6.20 (~$0.072)/kWh for most categories, including public utilities and industrial services.</p>
<p>For HT and EHT consumers, the energy charges follow a slab tariff structure based on the load factor. Consumers with load factors up to 60% are charged ₹5.85 (~$0.068)/kVAh for HT and ₹5.80 (~$0.067)/kVAh for EHT. Those with load factors above 60% are charged ₹4.75 (~$0.055)/kVAh for HT and ₹4.70 (~$0.054)/kVAh for EHT.</p>
<p><strong>Wheeling Charges and Cross-Subsidy Surcharge (CSS)</strong></p>
<p>Wheeling charges differ across the four DISCOMs. TPSODL has the highest charge at ₹1.74 (~$0.020)/kWh, followed by TPNODL at ₹1.56 (~$0.018)/kWh, TPWODL at ₹1.04 (~$0.012)/kWh, and TPCODL at ₹1.02 (~$0.012)/kWh.</p>
<p>The CSS levied on open access consumers also varies. For HT consumers, TPCODL charges 1.06 (~$0.020)/kWh, TPNODL ₹0.03 (~$0.00035)/kWh, TPWODL ₹0.28 (~$0.0033)/kWh, and TPSODL ₹1.71 (~$0.020)/kWh. For EHT consumers, the surcharge ranges from ₹1.61 (~$0.019)/kWh for the TPWODL to ₹3.56 (~$0.041)/kWh for TPSODL.</p>
<p><strong>Electric Vehicle Charges</strong></p>
<p>Electric Vehicle charging stations will be billed at a uniform rate of ₹5 (~$0.058)/kWh. This rate applies to public charging stations as well as dedicated EV charging units in group housing societies, provided these are equipped with *separate metering connections.</p>
<p>No demand charges will be levied on EV charging infrastructure, ensuring affordability and ease of access for both private operators and residential complexes looking to set up EV charging points</p>
<p><strong>Retail Supply Tariff and Rebates</strong></p>
<p>The RST structure remains unchanged for FY 2025-26. LT consumers are billed on a per kWh basis, while HT and EHT consumers are billed on a kVAh basis to account for the power factor.</p>
<p>The Commission confirmed that no additional surcharge would be imposed on open access users beyond the CSS. It has also approved rebates, including a 20% reduction for HT consumers maintaining a load factor above 85% and a ₹2 (~$0.023)/kWh rebate for mega lift irrigation projects.</p>
<p><strong>Renewable Energy Incentives</strong></p>
<p>The Commission reaffirmed incentives under the Odisha Renewable Energy Policy 2022 to promote renewable energy. Consumers using power from in-state renewable energy projects commissioned during the policy period will receive a 50% CSS exemption, a 25% exemption on wheeling charges, and a ₹0.20 (~$0.0023)/kWh exemption on transmission charges by OPTCL.</p>
<p>These benefits are valid for 15 years and will be extended by five years for projects commissioned before March 31, 2026.</p>
<p>In August 2024, OERC <a href="https://www.mercomindia.com/odisha-draft-rpo-regulations" target="_blank" rel="noopener">proposed</a> new regulations to promote energy procurement from renewable sources within the state until the financial year 2029-30.</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>


Odisha Regulator Retains Existing Power Tariffs for FY 2026


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					</table><p>The Ministry of Power (<a href="https://powermin.gov.in/" target="_blank" rel="noopener">MoP</a>) has launched an indigenously developed resource adequacy model STELLAR, enabling distribution companies (DISCOMs) to manage their power resources effectively.</p>
<p>The MoP will distribute this software model to all the states/DISCOMs free of cost.</p>
<p>The tool was launched in collaboration with the Central Electricity Authority (CEA), The <a href="https://www.lantaugroup.com/" target="_blank" rel="noopener">Lantau Group</a>, and the <a href="https://www.lantaugroup.com/" target="_blank" rel="noopener">Asian Development Bank</a> under the technical assistance program.</p>
<p>The resource adequacy tool is designed to assist the states in carrying out a comprehensive Resource Adequacy plan in line with the resource adequacy guidelines <a href="https://www.mercomindia.com/government-guidelines-resource-adequacy-framework" target="_blank" rel="noopener">issued</a> by the Ministry of Power in June 2023.</p>
<p>STELLAR is an integrated generation, transmission, and storage expansion planning model combined with a demand response. It will ensure optimum resource adequacy for DISCOMs.</p>
<p>The software will also ensure  zero load shedding and stressed capacity and provide the least cost solutions for DISCOMs.</p>
<p>It is designed to optimize the cost of power system generation expansion and system operation while considering the benefits of demand response. The model will also focus on optimizing energy and ancillary services and the size and location of energy storage.</p>
<p>The model considers aspects such as chronological operation of the power system, unit commitment constraints, internal demand response, and ancillary services for its calculations.</p>
<p>The CEA has been carrying out resource adequacy plans for all DISCOMs.  The plans for DISCOMs have been updated up to 2034-35. It has also completed the national-level exercises for up to 2034-35.</p>
<p>In November 2024, the CEA <a href="https://mercomindia.com/cea-approves-uniform-protection-protocol-for-power-grid-stability" target="_blank" rel="noopener">approved</a> the Uniform Protection Protocol to ensure grid stability, reliability, and security and safely integrate 450 GW of renewable energy by 2030 and 2,100 GW by 2047. The National Power Committee, in consultation with the Regional Power Committee, prepared the Uniform Protection Protocol.</p>
<p>In February 2024, the MoP <a href="https://www.mercomindia.com/ministry-urges-adequate-power-generation" target="_blank" rel="noopener">wrote</a> to all states and union territories to adhere to the Resource Adequacy Guidelines to ensure sufficient growth in power generation capacity in line with the rapidly increasing electricity demand in the country.</p>


Power Ministry Launches Resource Adequacy Model STELLAR for DISCOMs


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					</table><p>The <a href="https://gercin.org/" target="_blank" rel="noopener">Gujarat Electricity Regulatory Commission</a> has announced tariffs for the retail sale of electricity for the financial year (FY) 2026. According to the new order, the tariffs for low tension (LT), high tension (HT), and extra-high tension consumers in Gujarat remained unchanged from the previous year.</p>
<p>The revised tariff includes a few new provisions.</p>
<p>It has added a 2% rebate on energy charges for consumers who opt for a pre-paid smart-metering and billing arrangement.</p>
<p>It also specifies a concession of ₹0.60 (~$0.0069)/kWh between 11:00 and 15:00 for consumers with smart pre-paid meters.</p>
<p>The revised tariffs include a time-of-use charge for various HT tariff categories.</p>
<p>The additional tariff rate for the green power tariff has been reduced by 10% to ₹0.9 (~$0.01)/kWh from ₹1 (~$0.011)/kWh. Gujarat Energy Transmission Corporation’s transmission charges are down 5.14% to ₹3,918.01 (~$45.29)/MW/day from ₹4,130.32 (~$47.75)/MW/day.</p>
<p>Transmission charges for short-term users are set at ₹0.37 (~$0.0042)/kWh.</p>
<p>State Load Dispatch Centre charges have been increased by 48.8% to ₹565.45 million (~$6.53 million) from ₹380 million (~$4.39 million).</p>
<p><strong>Domestic Consumers</strong></p>
<p><strong>Rural General Purpose (RGP)</strong></p>
<p>GERC fixed the tariff for this category, which includes a single-phase supply up to 6 kW and a three-phase supply above 6 kW.</p>
<p>Fixed charges remain at ₹15 (~$0.17)/month for connected loads of up to 2 KW, ₹25 (~$0.29)/month for loads between 2 kW and 4 kW, ₹45 (~$0.5)/month for loads between 4 kW and 6 kW, and ₹70 (~$0.81)/month for loads above 6 kW.</p>
<p>Consumers can pay energy charges as follows:</p>
<ul>
<li>First 50 units- ₹3.05 (~$0.035)/kWh for post-paid energy and ₹2.99 (~$0.034)/kWh for pre-paid energy</li>
<li>Next 50 units- ₹3.5 (~$0.04)/kWh for post-paid energy and ₹3.44 (~$0.039)/kWh for pre-paid energy</li>
<li>Next 150 units- ₹4.15 (~$0.048)/kWh for post-paid energy and ₹4.07 (~$0.047)/kWh for pre-paid energy</li>
<li>Above 250 units- ₹5.2 (~$0.06)/KWh for post-paid energy and ₹5.10 (~$0.059)/kWh for pre-paid energy</li>
</ul>
<p>Below-poverty-line households will pay fixed charges of ₹5 (~$0.058)/month.</p>
<p>Energy charges will apply as follows:</p>
<ul>
<li>First 50 units- ₹1.5 (~$0.017)/kWh for post-paid energy and ₹1.47 (~$0.017)/kWh for pre-paid energy.</li>
<li>For the remaining units- rates per RGP for post-paid and pre-paid energy consumption.</li>
</ul>
<p>The concessional tariff is only for consuming 50 units monthly.</p>
<p><strong>RGP (Rural)</strong></p>
<p>The tariff RGP(Rural) consumers will cover a single-phase supply of up to 6 kW and a three-phase supply above 6 kW. The consumers must be in areas within gram panchayat limits.</p>
<p>Fixed charges will be ₹15 (~$0.17)/month for connected loads of up to 2 kW, ₹25 (~$0.29)/month for loads between 2 kW and 4 kW, ₹45 (~$0.52)/month for loads between ₹4 kW and 6 kW, and ₹70 (~$0.81)/month for loads above 6 kW.</p>
<p>Energy charges will be as follows:</p>
<ul>
<li>First 50 units- ₹2.65 (~$0.03)/KWh for post-paid energy and ₹2.6 (~$0.03017)/kWh for pre-paid energy</li>
<li>Next 50 units- ₹3.1 (~$0.035)/kWh for post-paid energy and ₹3.04 (~$0.035)/kWh for pre-paid energy</li>
<li>Next 150 units- ₹3.75 (~$0.04)/kWh for post-paid energy and ₹3.68 (~$0.042)/kWh for pre-paid energy</li>
<li>Above 250 units- ₹4.9 (~$0.05)/kWh for post-paid energy and ₹4.8 (~$0.055)/kWh for pre-paid energy</li>
</ul>
<p>Fixed charges for below-poverty-line households will be ₹5 (~$0.058)/month.</p>
<p>Energy charges will be as follows:</p>
<ul>
<li>First 50 units- ₹1.5 (~$0.017)/kWh for post-paid energy and ₹1.47 (~$0.017)/kWh for pre-paid energy</li>
<li>For the remaining units, Rates are as per the RGP for post-paid energy and rates as per the RGP for a smart pre-paid meter for pre-paid energy.</li>
</ul>
<p><strong>Non-RGP</strong></p>
<p>The tariff will apply to premises not covered by other tariff categories and up to a maximum aggregate load of 40 kW.</p>
<p>Consumers under this category can also opt to be charged per the LTMD category.</p>
<p>The fixed charges will be ₹50 (~$0.58)/kW for the first 10 kW of connected load and ₹85 (~$0.98)/kW for the next 30 kW of connected load.</p>
<p>Energy charges will be as follows:</p>
<ul>
<li>Contracted monthly loads of up to 10 kW- ₹ 4.35 (~$0.05)/kWh for post-paid charging and ₹4.26 (~$0.049)/kWh for pre-paid charging</li>
<li>Contracted monthly loads of over 10 kW- ₹4.65 (~$0.053)/kWh for post-paid charge and ₹4.56 (~$0.052)/kWh for pre-paid charge</li>
</ul>
<p>Consumers with a contact demand above 10 kW will also be charged ₹0.45 (~$0.005)/kWh for peak hours from 07:00 to 11:00 and 18:00 to 22:00.</p>
<p><strong>Low Tension Maximum Demand </strong></p>
<p>The tariff is applicable for consumers with an aggregate load above 40 kW.</p>
<p>Non-RGP consumers can also be charged under this tariff category.</p>
<p>Demand charges will apply as follows:</p>
<ul>
<li>For the first 40 kW- ₹90 (~$1.04)/kW/month</li>
<li>Next 20 kW &#8211; ₹130 (~$1.5)/kW/month</li>
<li>Above 60 kW &#8211; ₹195 (~$2.26)/kW/month</li>
<li>For billing demands above the contract demand, consumers must pay ₹265 (~$3.07)/kW</li>
</ul>
<p>Energy charges applicable for a full month will be ₹4.6 (~$0.053)/kWh for a post-paid energy charge and ₹4.51 (~$0.052)/kWh for a pre-paid energy charge.</p>
<p>Additionally, time-of-use charges of ₹0.45 (~$0.005)/kWh will apply to energy consumption during peak hours between 07:00  to 11:00 and 18:00 to 22:00</p>
<p>Reactive energy charges for the month will be ₹0.1 (~$0.001)/kVARh.</p>
<p><strong>LT Electric Vehicle Charging Stations</strong></p>
<p>Fixed charges will be ₹25 (~$0.29)/installation/month.</p>
<p>Energy charges will be ₹4.1 (~$0.047)/kWh for post-paid energy charges and ₹4.02 (~$0.046)/kWh for pre-paid energy charges.</p>
<p>There will also be time-of-use charges amounting to ₹0.45 (~$0.005)/kWh.</p>
<p><strong>Commercial and Industrial Consumers</strong></p>
<p><a href="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/GERC.png"><img loading="lazy" decoding="async" class="aligncenter wp-image-78502 size-full" src="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/GERC.png" alt="" width="680" height="218" srcset="https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/GERC.png 680w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/GERC-300x96.png 300w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/GERC-650x208.png 650w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/GERC-624x200.png 624w, https://mercomindia.s3.ap-south-1.amazonaws.com/wp-content/uploads/2025/04/GERC-600x192.png 600w" sizes="(max-width: 680px) 100vw, 680px" /></a></p>
<p><strong>High-Tension Power (HTP)-1</strong></p>
<p>The tariff will apply to HT consumers with a minimum contracted demand of 100 kVA for regular power supply and purposes not specified in any other HT categories.</p>
<p>Demand charges will be as follows:</p>
<ul>
<li>For the first 500 kVA- ₹150 (~$1.74)/kVA/month</li>
<li>For the next 500 kVA &#8211; ₹260 (~$3.01)/kVA/month</li>
<li>For the billing demand above 1,000 kVA- ₹475 (~$5.51)/kVA/month</li>
</ul>
<p>In case the billing demand exceeds contract demand, consumers will be charged ₹555 (~$6.4)/kVA/month.</p>
<p>Energy charges will be as follows:</p>
<ul>
<li>For up to 500 kVA demand- ₹4 (~$4)/kWh</li>
<li>For demand between 500 kVA and 2,500 kVA- ₹4.2 (~$0.048)/kWh</li>
<li>For demand above 2,500 kVA- ₹4.30 (~$0.049)/kWh</li>
</ul>
<p>The time-of-use charges will be as follows:</p>
<ul>
<li>For demand up to 500 kVA- ₹0.45 (~$0.005)/kWh</li>
<li>For demand above 500 kVA- ₹0.85 (~$0.009)/kWh</li>
</ul>
<p>The following provisions will apply to all high-tension tariffs:</p>
<p>The billing demand will be the highest maximum demand during a month, 85% of the contract demand, and a billing demand of 100 kVA.</p>
<p>Power factor adjustment charges of 1% will be levied on electricity bills for every 1% average power factor drop from 90% to 85%.</p>
<p>If the average power factor falls below 85%, for every 1% drop, 2% of the total electricity bill will be charged as power factor adjustment charges.</p>
<p>If the power factor is above 95%, the consumer can receive a rebate of 0.5% on their electricity bill for every 1% increase above 95%.</p>
<p>The contract demand will be the maximum power supply.</p>
<p>There will be a 1% rebate on the supply of power at high and extra high voltage for 11 kV/ 22 kV high voltage supply, a 1.5% rebate on 11 kV/ 22 kV extra high voltage supply, and a 2% rebate on 132 kV and above extra high voltage supply.</p>
<p><strong>HTP-II</strong></p>
<p>The tariff will apply for energy supplied to HT consumers contracting at least 100 kVA for power in waterworks and sewerage pumping stations run by local authorities, the Gujarat Water Supply and Sewerage Board, and Gujarat Industrial Development Corporation Water Works.</p>
<p>Demand charges will be as follows:</p>
<ul>
<li>For demand of up to 500 kVA- ₹115 (~$1.33)/kVA/month</li>
<li>For the next 500 kVA- ₹225 (~$2.61)/kVA/month</li>
<li>For demand above 1,000 kVA &#8211; ₹290 (~$3.36)/kVA/month</li>
</ul>
<p>Consumers must pay ₹360 (~$4.17)/kVA/month if the billing demand exceeds the contract demand.</p>
<p>Energy Charges will be as follows:</p>
<ul>
<li>For demand of up to 500 kVA- ₹4.35 (~$0.05)/kWh</li>
<li>For demand between 500 kVA and 2,500 kVA- ₹4.55 (~$0.052)/kWh</li>
<li>For demand above 2,500 kVA- ₹4.65 (~$0.053)/kWh</li>
</ul>
<p>Time-of-use charges of ₹0.45 (~$0.005)/kWh will apply for billing demand of up to 500 kVA for consumption during peak hours between 7:00 to 11:00 and 18:00 to 22:00.</p>
<p>Billing demand above 500 kVA for consumption during peak hours between 7:00 to 11:00 and 18:00 and 22:00 will attract time-of-use charges of ₹0.85 (~$0.0098)/kWh.</p>
<p><strong>HTP-III</strong></p>
<p>The tariff will apply for consumers temporarily taking at least 110 kVA of power.</p>
<p>Demand charges will be ₹18 (~$0.208)/kVA/day for up to the contract demand and ₹20 (~$0.23)/kVA/day for demand above the contract demand.</p>
<p>Energy charges will be ₹6.6 (~$0.076)/kWh for monthly consumption.</p>
<p>Consumers must also pay time-of-use charges of ₹0.85 (~$0.009)/kWh for peak hours between 7:00 and 11:00 and 18:00 to 22:00.</p>
<p><strong>HTP-IV</strong></p>
<p>The tariff will apply to consumers opting for an electricity supply of at least 100 kVA during night hours between 22:00 and 6:00.</p>
<p>Demand charges will be one-third of the HTP-I fixed charges.</p>
<p>Consumers must also pay energy charges of ₹2.25 (~$0.026)/kWh for monthly consumption.</p>
<p><strong>HTP V</strong></p>
<p>The tariff will apply to electricity supply to high-tension agriculture consumers contracting at least 100 kVA of power to lift water from sources such as canals, rivers, and dams for agricultural irrigation.</p>
<p>Demand charges will be ₹25 (~$0.29)/kVA/month.</p>
<p>Energy charges will be ₹0.8 (~$0.009)/kWh.</p>
<p><strong>Railway Traction tariff</strong></p>
<p>Demand charges will be ₹180 (~$2.08)/kVA/month for billing demand up to the contract demand.  The demand charges will be ₹425 (~$4.9)/kVA/month for demand above the contract demand.</p>
<p>For bunching of trains, consumers will be charged normal demand charges.</p>
<p>Energy charges will be ₹5 (~$0.058)/kWh for monthly consumption.</p>
<p><strong>HT Electric vehicle charging stations</strong></p>
<p>The tariff is applicable for electric vehicle charging stations.</p>
<p>Demand charges will be ₹25 (~$0.29)/kVA/month for billing demand up to the contract demand and ₹50 (~$0.58)/kVA/month for demand above the contract demand.</p>
<p>Energy charges will be ₹4 (~$0.046)/kWh for the entire month.</p>
<p>Consumers must pay time-of-use charges of ₹0.45 (~$0.005)/kWh for power consumption between 7:00 to 11:00 and 18:00 to 22:00.</p>
<p>In 2024, GERC <a href="https://www.mercomindia.com/gujarat-regulator-regulations-until-2030" target="_blank" rel="noopener">issued</a> the Multi-Year Tariff Regulations, 2024, which will be effective from April 1, 2025, to March 31, 2030.</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>


Gujarat Retains Last Year’s Electricity Tariffs for FY 2026


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					</table><p>The Gujarat Electricity Regulatory Commission (<a href="https://gercin.org/" target="_blank" rel="noopener">GERC</a>) has approved a petition filed by Paschim Gujarat Vij Company (<a href="https://www.pgvcl.com/" target="_blank" rel="noopener">PGVCL</a>) to adopt tariffs for 276 MW of solar power projects under Component C of the Pradhan Mantri Kisan Urja Suraksha evam Utthaan Mahabhiyan (PM-KUSUM) program.</p>
<p>The approved tariffs range from ₹2.13 (~$0.026)/kWh to ₹3 (~$0.036)/kWh.</p>
<p><strong>Background</strong></p>
<p>The petitioner, PGVCL, approached GERC to approve tariffs ranging from ₹2.13 (~$0.026) to ₹3 (~$0.036)/kWh for its 276 MW solar projects under Component C of the PM-KUSUM program to support 45,800 pumps under 11 kV agricultural feeders. PGVCL had received 129 bids for 125 solar projects to be contracted for 25 years under RESCO model.</p>
<p>It submitted that the tariffs were discovered through a transparent and competitive bidding process.</p>
<p>The petitioner contended that the tariff adoption was necessary to implement the solar projects.  It also presented the bidding process details noting that the discovered tariffs were reasonable and aligned with prevailing market rates.</p>
<p>One of the selected bidders, Gensol Engineering, requested to sign the power purchase agreement (PPA) under ‘Gensol SPV.’ The petitioner denied this request, causing Gensol Engineering to contend this move.</p>
<p><strong>Commission’s Analysis</strong></p>
<p>GERC observed that the petitioner’s bidding process was competitive and transparent.</p>
<p>The Commission concluded that the discovered tariffs were reasonable and aligned with the prevailing market rates and the objectives of the PM-KUSUM program.</p>
<p>It approved the requested tariff of ₹2.13 (~$0.026)/kWh to ₹3 (~$0.036)/kWh, allowing PGVCL to sign the PPAs with the successful bidders except for Gensol Engineering.</p>
<p>The petitioner was also directed to disclose the successful bidders’ names and tariff details publicly. These details will be posted on the petitioner’s website for 30 days.</p>
<p>The Commission listed Gensol Engineering’s request for further hearing.</p>
<p>Earlier this year, GERC <a href="https://www.mercomindia.com/gerc-approves-tariff-for-three-solar-projects-under-pm-kusum-c" target="_blank" rel="noopener">adopted</a> a uniform tariff for Madhya Gujarat Vij Company’s three solar power projects developed under Component C of the PM-KUSUM program.</p>
<p>In November 2024, GERC <a href="https://www.mercomindia.com/gerc-approves-tariffs-for-259-mw-solar-projects-under-kusum" target="_blank" rel="noopener">approved</a> tariffs for 101 solar power projects of PGVCL with a total capacity of 259 MW under Component C of the PM KUSUM program.</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>


Gujarat Adopts Tariffs for 276 MW Solar Projects Under KUSUM Program


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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 (ISTS) to evacuate 2,500 MW of renewable energy from the Morena Special Economic Zone in Madhya Pradesh.</p>
<p>Bids must be submitted by June 9, 2025. Bids will be opened on the same day.</p>
<p>Bidders must furnish a document fee of ₹500,000 (~$5,852) and a bid bond of ₹208 million (~$2.43 million).</p>
<p>Selected bidders must submit ₹520 million (~$6.08 million) as a contract performance guarantee within ten days from the date of issue of the letter of intent.</p>
<p>The scope of work entails establishing a 3&#215;1500 MVA, 765/400 kV, and 2&#215;500 MVA, 400/220 kV pooling substation, and 2&#215;330 MVAr 765 kV and 2&#215;125 MVAr 420 kV bus reactors.</p>
<p>It also involves constructing a 90 km 765 kV D/C transmission line from the Morena pooling substation (south of Sabalgarh) to Karera (near Datia). At Karera, two 765 kV line bays must be installed for terminating the Morena pooling substation – Karera 765 kV D/C line.</p>
<p>Selected bidders must augment the 400/220 kV transformation capacity at the 765/400/220 kV Karera substation (Section I) by adding a 1&#215;500 MVA interconnecting transformer.</p>
<p>They must commission the system within 27 months of signing the transmission service agreement.</p>
<p>Bidders must have developed infrastructure projects with a total capital expenditure of at least ₹10.4 billion (~$121.76 million) in the last five years. The capital expenditure of each project must have been at least ₹2.08 billion (~$24.35 million).</p>
<p>The projects must have been completed at least seven days before the bid submission deadline. Bidders must have held at least 26% ownership in the company executing the projects from financial closure to commissioning.</p>
<p>Bidders can also participate if they have received at least ₹10.4 billion (~$121.76 million) from clients for completed infrastructure projects over the past five years. The payment for each project must have been at least ₹2.08 billion (~$24.35 million).</p>
<p>Bidders must have a minimum net worth of ₹4.16 billion (~$48.7 million) in the last three financial years. Their net worth should not have been negative in any of the past three financial years.</p>
<p>In March this year, PFC Consulting <a href="https://www.mercomindia.com/pfc-invites-bids-for-renewable-energy-transmission-project-in-madhya-pradesh/" target="_blank" rel="noopener">invited</a> bids to augment the evacuation capacity of renewable energy by 4.5 GW and construct line bays at the Mandsaur substation in Madhya Pradesh.</p>
<p>In October 2024, PFC Consulting <a href="https://www.mercomindia.com/pfc-consulting-evacuate-andhra-pradesh/" target="_blank" rel="noopener">invited</a> bids to select a transmission service provider to set up an ISTS at Ananthapur-II Renewable Energy Zone (Phase I) in Andhra Pradesh to evacuate an additional 4.5 GW of renewable energy.</p>


PFC Consulting Invites Bids to Evacuate 2.5 GW Renewable Energy in Madhya Pradesh


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					</table><p>The <a href="https://powermin.gov.in/" target="_blank" rel="noopener">Ministry of Power</a> has introduced amendments to the standard bidding documents for procuring interstate transmission services through a tariff-based competitive bidding process.</p>
<p>These amendments apply to the establishment, operation, and maintenance of transmission projects on a build, own, operate, and transfer basis. The revisions aim to address challenges in land acquisition while improving the transmission projects’ feasibility and flexibility.</p>
<p>One of the key changes in the amendment is the revision of locational constraints for greenfield substations, which include switching stations, high-voltage direct current (HVDC) terminals, and inverter stations. The actual location of a generation pooling substation must remain within a 3 km radius of the point specified in the survey report prepared by the bid process coordinator. The permissible location radius has been increased to 5 km for load-serving substations. However, the locational constraint for an intermediate substation remains unchanged at 10 km.</p>
<p>Previously, both generation pooling and load-serving substations were restricted to a 3 km radius, while intermediate substations were limited to 10 km. The amendment distinguishes between generation pooling and load-serving substations by expanding the latter’s permissible radius.</p>
<p>These revisions address practical challenges developers face in acquiring land and implementing transmission projects. By allowing an increased location radius for load-serving substations, the amendment aims to provide greater flexibility while maintaining efficiency and feasibility in transmission infrastructure development.</p>
<p>Mercom has <a href="https://www.mercomindia.com/as-ists-waiver-nears-amid-lack-of-substations/" target="_blank" rel="noopener">reported</a> on how transmission infrastructure challenges, especially the shortage of substations, are a huge concern for projects under development.</p>
<p>The estimated expenditure for <a href="https://www.mercomindia.com/transmission-infrastructure-2027-cea/" target="_blank" rel="noopener">implementing</a> the additional transmission system (including transmission lines, substations, and reactive compensation) during 2022-27 is projected at ₹4.25 trillion (~$50.55 billion), according to the Volume II – Transmission of National Electricity Plan issued by the Central Electricity Authority.</p>
<p>Expanding India’s transmission system from 2022-27 will include the addition of 114,687 ckm of transmission lines and 776,330 MVA of transformation capacity at the 220 kV level and above. A 1,000 MW HVDC bi-pole capacity is also planned. These developments will bring the total transmission line length to 571,403 ckm, the transformation capacity to 18,47,280 MVA, and the HVDC bi-pole capacity to 34,500 MW by the end of 2027.</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>


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