Gati Vidhi – September 2026

MoC has released Comprehensive Corporate Social Responsibility Framework for Indian Coal Companies

On 15.09.2026, the Ministry of Coal (“MoC”) released the Comprehensive Corporate Social Responsibility (“CSR”) Framework for Indian Coal Companies (“framework”), prepared by the School of Business Environment, Indian Institute of Corporate Affairs (“IICA”), under the aegis of the Ministry of Corporate Affairs, and commissioned by MoC with the support of Coal India Limited (“CIL”).

The framework provides guidance for planning, implementation, monitoring, assessment, reporting of CSR activities in the coal and lignite sector. It is advisory and voluntary in nature and does not amend, override or substitute the Companies Act, 2013, the Companies (Corporate Social Responsibility Policy) Rules, 2014, or other applicable statutory or regulatory requirements.

The key recommendations include:

• needs assessment and village-level vulnerability mapping before sanction of CSR projects;
• recording local procurement and engagement of MSMEs and Self-Help Groups, along with collection of disaggregated beneficiary data;
• establishment and maintenance of community grievance registers and reporting of grievance categories and resolution rates;
• alignment of projects with specific Sustainable Development Goal targets and preparation of a Government Scheme Convergence and Additionality Note before project sanction;
• Planning and budgeting for impact assessment at the project-approval stage where applicable under the CSR Rules;
• strengthening CSR staffing and management information systems and integrating mine lifecycle and community-transition planning into the Annual Action Plan.

The framework clarifies that CSR is supplementary to, and does not substitute, statutory obligations attached to mining operations. Accordingly, expenditure relating to mine closure, rehabilitation and resettlement, environmental clearance conditions, District Mineral Foundation and other statutory obligations do not constitute CSR expenditure.

The framework can be accessed here.

MoC notifies appointment of the Nominated Authority as Adjudication Authority under Coal Mines (Special Provisions) Act, 2015

MoC has, vide order dated 09.09.2026, notified the appointment of the Nominated Authority to be the Adjudication Authority under Section 24A of the Coal Mines (Special Provisions) Act, 2015 (“Coal Mines Act”) for holding inquiries and imposing penalties in such form and manner as may be prescribed and discharging functions of the Adjudication Authority under Section 24A of the Coal Mines Act.

The order dated 09.09.2026 can be accessed here.

MoPNG has released component-wise Operational Guidelines under GOBARdhan Scheme for Development of CBG Sector

The Ministry of Petroleum and Natural Gas (“MoPNG”) vide office memorandum dated 15.09.2026, has issued the component-wise Operational Guidelines under the GOBARdhan (Galvanizing Organic Bio-Agro Resources Dhan) Scheme (“Guidelines”) for the development of the Compressed Biogas (“CBG”) sector. The Scheme has been approved with a total outlay of Rs. 23,731 crore for FY 2026-27 to FY 2035-36.

The Guidelines provide an operational framework across six key components to establish firm demand, viable pricing, capital support, infrastructure connectivity, credit enhancement and ecosystem development. They apply to registered CBG producers, City Gas Distribution (“CGD”) entities, financial institutions and designated implementation agencies. The key highlights include:

• Assured Offtake Mechanism (Component I): Up to 100% of available CBG, subject to technical and operational feasibility, through Compressed Biogas Obligation targets of 3% in FY 2026-27, 4% in FY 2027-28 and 5% thereafter, supported by standard tripartite agreements incorporating Take-or-Pay and Supply-or-Pay mechanisms.
• CBG Pricing Framework (Component II): Initial Administered CBG Price of Rs. 2,110/MMBTU (approx. Rs. 98/kg), with Government affordability support capped at Rs. 10/kg (~Rs. 215.31/MMBTU), to the Synchro Operator, GAIL, over a period of 10 years. The price is delinked from CNG retail prices to ensure revenue stability .
• Capital Assistance (Component III): Assistance of up to Rs. 30 crore per project, including Rs. 1.25 crore/TPD for eligible greenfield projects and support for brownfield expansion and eligible machinery.
• Pipeline Infrastructure Development (Component IV): 50% financial assistance for eligible pipeline connectivity up to 75 km per plant, capped at Rs. 50 lakh/km for steel and Rs. 7.5 lakh/km for MDPE pipelines.
• Credit Guarantee Scheme (Component V): Managed by NCGTC under an earmarked fund of ₹625 crore, it provides credit guarantee cover of up to 85% on term loans, capped at Rs. 20 crore for general MSMEs and Rs. 25 crore for women-led MSMEs, with a maximum tenure of 15 years.
• CBG Ecosystem Challenge Fund (Component VI): Allocates Rs. 500 crore for FY 2026-27 to FY 2030-31 to promote district-level competition, with awards of up to Rs. 5 crore for top-performing District Administrations, and provides grant assistance of up to 50% for scalable technology, yield enhancement and by-product utilisation.

The Guidelines consolidate certain existing support measures with the GOBARdhan Scheme. With effect from 10.09.2026, Central Financial Assistance for CBG plants under the Ministry of New and Renewable Energy’s Waste to Energy Programme, MoPNG’s Biomass Aggregation Machinery Scheme and Development of Pipeline Infrastructure Scheme are subsumed under the corresponding components of GOBARdhan. Existing retail outlets established under the SATAT initiative are encouraged to be integrated into the GOBARdhan framework. Projects predominantly based on Municipal Solid Waste (“MSW”) or sewage waste, where 50% or more of the feedstock used for CBG production is derived from MSW/sewage waste, are excluded from specified support components, including Capital Assistance and Credit Guarantee support.

The office memorandum dated 15.09.2026 can be accessed here.

MoP issues directions to captive coal-based generating stations under Section 11 of Electricity Act, 2003

The Ministry of Power (“MoP”) has, vide letter dated 25.09.2026, issued directions under Section 11 of the Electricity Act, 2003 (“the Act”) to generating companies owning captive generating stations specified in the Annexure to maximise power generation in view of the prevailing demand-supply scenario and expected rise in electricity demand. The directions are applicable from 01.10.2026 to 31.12.2026.

The captive coal-based generating stations with an installed capacity of 50 MW and above are required to:

• operate and generate power to the maximum extent of their available capacity;
• offer available surplus generation, after meeting captive demand, through power exchanges in accordance with applicable market regulations and procedures;
• maintain adequate coal stock to ensure fuel availability and maximum generation; and
• submit weekly reports to the CEA on generation, captive consumption, sale of power through power exchanges/other permitted avenues, available capacity and coal stock.

The MoP letter dated 25.09.2026 can be accessed here.

MoP extends the validity of the directions issued to Coastal Gujarat Power Ltd. vide letter dated 22.03.2026

MoP has, vide letter dated 25.09.2026, extended the validity of the directions, issued to Coastal Gujarat Power Ltd. (“CGPL”) Imported-Coal Based (“ICB”) plant under Section 11 of the Act vide letter dated 22.03.2026, up to 31.12.2026 in view of the prevailing power demand scenario in the country.

Vide letter dated 22.03.2026, the MoP had issued directions under Section 11 of the Act inter alia requiring CGPL to operate its ICB plant at full capacity from 01.04.2026 to 30.06.2026 (subsequently extended to 30.09.2026), in view of the anticipated increase in electricity demand. Power generated is required to be primarily supplied to PPA holders at a MoP-determined benchmark rate, or at a mutually negotiated rate. Power not scheduled/procured by PPA holders may be offered to other PPA holders and thereafter sold on power exchanges. Net profits from exchange sales had to be shared equally between the generator and the concerned PPA holder. The said letter has been covered in detail in our previous newsletter dated 30.03.2026.

The MoP letter dated 25.09.2026 can be accessed here. The MoP letter dated 22.03.2026 can be accessed here.

PNGRB has invited stakeholder comments on the Draft Guidelines for Baseline IT Infrastructure for CGD Entities

The Petroleum and Natural Gas Regulatory Board (“PNGRB”) has, vide public notice dated 12.09.2026, invited stakeholder comments on the Draft Guidelines for Baseline IT Infrastructure for CGD Entities, 2026 (“Draft Guidelines”), formulated under the PNGRB Act, 2006. The Draft Guidelines seek to establish a standardised, secure and resilient baseline IT infrastructure across CGD entities operating in more than 300 authorised Geographical Areas (“GAs”) in India.

The Guidelines are advisory and recommendatory and cover network connectivity, cloud and computing infrastructure, data management, consumer-facing digital services, operational technology (“OT”) and SCADA systems, business applications, regulatory reporting, cybersecurity and IT governance. They do not prescribe specific technology products or vendors. Mandatory requirements under applicable laws and directions issued by the competent authorities continue to apply.

The key recommendations and baseline requirements include:

• Network Segmentation and IT/OT Separation: Logical separation of consumer-facing, business IT systems and OT networks using firewalls, demilitarised zones or data diodes, in line with Zero Trust Architecture principles.
• Physical and Data Infrastructure: Indicative standards of 18°C and 27°C temperature, 40% to 60% humidity levels and minimum 30 minutes UPS backup for critical infrastructure, together with CCTV retention of 30 days, extending to 90 days for critical IT/OT facilities. The Guidelines also encourage the 3-2-1-1 backup strategy, daily backups of critical data and annual restoration testing.
• Consumer-Facing Services: Web portals/mobile applications should have regard to GIGW 3.0 and aim for WCAG 2.1 Level AA compliance, with indicative benchmarks of at least 99.5% portal availability, page-load times within 3 seconds, grievance acknowledgement within 24 hours and round-the-clock emergency helplines.
• OT and SCADA: Maintenance of component-level OT asset registers and adoption of IEC 62443 Defence-in-Depth principles, with compensating controls such as network isolation and application whitelisting for legacy/end-of-life systems.
• Cybersecurity: Multi-factor authentication for all privileged accounts and remote access, rotation of privileged credentials at least every 90 days, annual vulnerability assessment and penetration testing of critical systems and retention of ICT security logs for at least 180 days within India.
• Governance, AI Adoption and Business Continuity: Designation of a senior IT official and a Chief Information Security Officer, governance of AI use, and adoption of Business Continuity Plans and Disaster Recovery arrangements.

The Guidelines preserve the primacy of operational safety under the Technical Standards and Specifications including Safety Standards framework in case of conflict between IT and OT requirements. They also provide indicative technology guidance for smaller CGD entities while leaving entities free to select technologies appropriate to their requirements.

The comments and views on the Draft Guidelines can be submitted within 15 days of the issuance of the Public Notice.

The public notice dated 12.09.2026 and Draft Guidelines for Baseline IT Infrastructure for CGD Entities can be accessed here.

PNGRB has released Minutes of Open House discussion on the Draft PNGRB (Third Party Conformity Assessment) Amendment Regulations, 2026

PNGRB has, vide public notice dated 14.09.2026, released the Minutes of Open House discussion held on 01.09.2026 on the Draft PNGRB (Third Party Conformity Assessment) Amendment Regulations, 2026, as part of the stakeholder consultation initiated through its Public Notice dated 29.05.2026. The proposed amendments seek to strengthen the Third Party Conformity Assessment framework.

The stakeholders raised concerns regarding the proposed 70-year age limit for auditors, suggesting that experience, competence and physical fitness should also be considered. Suggestions were also made to make QCBS and eligibility requirements proportionate to the size and complexity of assignments, provide clearer mechanisms for verification of auditor credentials and allow flexibility in documentary requirements.

Concerns were further raised regarding mandatory pre-commissioning audits, IMS certification and recertification timelines, audit checklists, mock drills, auditor training and competency requirements, as well as the classification of non-conformities based on their severity. 

Stakeholders also sought review of Third Party Inspection Agencies (“TPIAs”) remuneration and the proposed restriction on TPIAs undertaking similar assignments. SEVA suggested that, where necessary to maintain independence and avoid conflicts of interest, such restrictions could instead apply to the individual auditor rather than the TPIA organisation.

The public notice dated 14.09.2026 can be accessed here. The Draft PNGRB (Third Party Conformity Assessment) Amendment Regulations, 2026 can be accessed here.

CERC issues draft second amendment to the Indian Electricity Grid Code Regulations, 2026

The Central Electricity Regulatory Commission (“CERC”), vide its draft notification dated 21.09.2026, has proposed the CERC (Indian Electricity Grid Code) (Second Amendment) Regulations, 2026. The proposed amendments seek to introduce changes relating to trial runs, commercial operation, scheduling of infirm power, Energy Storage Systems (“ESS”), Pumped Storage Plants (“PSP”), congestion charges and scheduling and operation of generating stations. 

A key proposal relates to simplifying the trial-run requirements for renewable energy projects and ESS. The draft proposes that projects having a capacity of 250 MW or more may conduct trial runs in instalments of at least 50 MW, without any limit on the number of instalments. For standalone ESS, a minimum aggregate capacity of 50 MW is proposed for the trial run. ESS projects between 50 MW and 250 MW may conduct the trial run for the balance capacity in up to three instalments, with a minimum capacity of 5 MW. The draft also provides that standalone ESS projects below 50 MW may conduct trial runs for the capacity for which connectivity has been granted. Further, the notice period for trial runs is proposed to be reduced from seven days to three days.

The draft also proposes a new framework for scheduling infirm power and introduces provisions for congestion charges. Scheduling of infirm power would be permitted only after successful completion of the trial run, while, in the absence of specific contractual provisions, such power would first be offered to the contracted buyers before being sold to third parties. CERC has further proposed a separate congestion charge for entities causing congestion in inter-regional or intra-regional transmission links, in addition to applicable deviation charges. The draft also proposes measures for regulating access of entities that default on statutory charges such as DSM, congestion and reactive energy charges, or fail to maintain the required payment security mechanism.

CERC has invited comments/suggestions/objections on the draft Regulations from the stakeholders and interested persons which may be addressed to the CERC on secy@cercind.gov.in and shilpa@cercind.gov.in on or before 21.10.2026. A copy of the draft Regulations can be viewed here.

MERC invites comments on the Draft MERC (Distribution Open Access) Regulations, 2026

The Maharashtra Electricity Regulatory Commission (“MERC”) vide public notice dated 22.09.2026, has invited comments, suggestions or objections on the Draft MERC (Distribution Open Access) Regulations, 2026 (“Draft DOA Regulations”). The Draft DOA Regulations seek to replace the existing Distribution Open Access framework and introduce a banking mechanism linked to the contracted RE capacity of an Open Access consumer.

The key highlights of the Draft DOA Regulations are as follows:

• Banking would be available to Open Access Consumers, including Green Energy Open Access and Captive Open Access Consumers, procuring electricity from RE generating stations identified as “non-firm power”, including wind, solar, wind-solar hybrid and micro, mini and small hydro projects up to 25 MW.
• Banking would however not be available to consumers opting for Full Open Access to the distribution network or GNA to the intra-State or inter-State transmission network.
• Introduction of capacity-linked banking and settlement. Consumers are categorized based on contracted RE capacity into 0-3 kW, 3-10 kW, 10-100 kW, 0.1-1 MW, 1-5 MW and 5 MW and above. The banking settlement period varies from annual to monthly depending on the capacity, while consumers above 10 kW are subject to progressively granular intra-day banking slots, ranging from four slots for 10-100 kW consumers to 24 hourly slots for consumers with contracted RE capacity of 5 MW and above.
• Proposed fixed Banking and Standby Charges (₹/kW/month) and variable Banking and Standby Charges (₹/kWh).
• For consumers with 5 MW or more of contracted RE capacity, the maximum banked energy credited against consumption in a particular banking slot would be capped at 10% of the consumer’s total consumption from the Distribution Licensee in that slot.
• Within 3 years of notification of the Draft Regulations, consumers with contracted RE capacity exceeding 5 MW would transition from the 24-slot banking framework to 15-minute scheduling, subsequent to which fixed Banking and Standby Charges and compensation for surplus energy injected would no longer apply. Unutilised surplus banked energy would lapse at the end of the applicable banking settlement period, subject to the proposed treatment of RE Certificates corresponding to such lapsed energy.
• Consumers already availing/having applied for banking before notification would have a one-time option to continue under the existing banking framework for the validity of their Open Access Agreement or migrate to the proposed framework. However, any augmentation of existing RE Open Access capacity would result in mandatory migration to the new framework.

The comments, suggestions or objections can be submitted within 21 days (online) or by 5 PM on 12.10.2026 (hard copy). Counter submissions to the comments, suggestions or objections can be filed by 15.10.2026.

The MERC public notice dated 22.09.2026 can be accessed here. The Draft DOA Regulations can be accessed here.

MERC invites comments on the Draft MERC (Grid Interactive Rooftop Renewable Energy Generating Systems) Regulations, 2026

The MERC vide public notice dated 22.09.2026 has invited comments, suggestions or objections on the Draft MERC (Grid Interactive Rooftop Renewable Energy Generating Systems) Regulations, 2026 (“Draft Rooftop Regulations”). The Draft Rooftop Regulations seek to replace the existing rooftop RE framework and govern Net Metering, Net Billing, Group Net Metering, Virtual Net Metering, Gross Metering, and Behind-the-Meter (“BTM”) systems. Upon notification, the MERC (Grid Interactive Rooftop Renewable Energy Generating Systems) Regulations, 2019 would stand repealed.

The key highlights of the Draft Rooftop Regulations are as follows:

• Introduction of mandatory ESS integration for all new grid-interactive rooftop REGS and BTM systems with capacity above 100 kW. Such systems would be required to install ESS equivalent to at least 50% of installed RE capacity with minimum 2-hour storage duration, or 25% with minimum 4-hour storage duration. 
• The minimum ESS capacity is prescribed at 1 kWh/kW of installed RE capacity up to 2030 and 2 kWh/kW thereafter.
• Technical limit on cumulative rooftop RE capacity connected to a particular Distribution Transformer or feeder. The cumulative capacity of REGS under Net Metering, Net Billing, Group Net Metering and Gross Metering arrangements would generally be capped at 70% of the rated capacity of the Distribution Transformer/feeder. Connectivity beyond this may be permitted after undertaking a detailed load study.
• The proposed banking framework is linked to consumer’s cumulative contracted RE capacity.
• Existing REGS covered under the prevailing regulations would continue to be governed by those regulations until expiry of their existing agreements, unless the prosumer opts to terminate the existing agreement and migrate to the new framework.
• Any enhancement, augmentation or modification in the capacity or configuration of an existing REGS after notification would bring it within the new framework.

The comments, suggestions or objections can be submitted within 21 days (online) or by 5 PM on 12.10.2026 (hard copy). Counter submissions to the comments, suggestions or objections can be filed by 15.10.2026.

The public notice dated 22.09.2026 can be accessed here. The Draft Rooftop Regulations can be accessed here.

MERC invites comments on the Draft MERC (Renewable Purchase Obligation, its Compliance and Implementation of Renewable Energy Certificate Framework) (Second Amendment) Regulations, 2026

The MERC vide public notice dated 22.09.2026 has invited comments, suggestions or objections on the Draft MERC (Renewable Purchase Obligation, its Compliance and Implementation of Renewable Energy Certificate Framework) (Second Amendment) Regulations, 2026 (“Draft RPO Amendment Regulations”). The Draft RPO Amendment Regulations seek to amend the MERC (Renewable Purchase Obligation, its Compliance and Implementation of Renewable Energy Certificate Framework) Regulations, 2019 to incorporate the Government of Maharashtra’s target of achieving 65% RE procurement by FY 2035–36, including a minimum storage obligation for Distribution Licensees.

The key highlights of the Draft RPO Amendment Regulations are as follows:

• Every Obligated Entity would be required to plan its power procurement such that, by FY 2035-36, procurement from RE sources constitutes at least 65% of its total procurement from all sources in that year.
• MERC may separately specify annual RPO targets for the intervening period from FY 2030–31 to FY 2035–36.
• Introduction of a progressively increasing storage requirement on an energy basis – from 1.5% in FY 2024-25 to 2.5% in FY 2026-27, 5% in FY 2030-31 and ultimately 10% in FY 2035-36.

The comments, suggestions or objections can be submitted within 21 days (online) or by 5 PM on 12.10.2026 (hard copy). Counter submissions to the comments, suggestions or objections can be filed by 15.10.2026.

The public notice dated 22.09.2026 can be accessed here. The Draft RPO Amendment Regulations can be accessed here.

MERC invites comments on the Draft MERC (State Grid Code) (Second Amendment) Regulations, 2026

The MERC vide public notice dated 22.09.2026, has invited comments, suggestions or objections on the Draft MERC (State Grid Code) (Second Amendment) Regulations, 2026 (“Draft Grid Code Amendment Regulations”). The Draft Grid Code Amendment Regulations seeks to incorporate ESS and REGS within the scope of the State Grid Code and prescribe specific requirements for their integration with the InSTS.

The key highlights of the Draft Grid Code Amendment Regulations are as follows:

• BESS and REGS connected to, or seeking connection with, the InSTS would be required to comply with the State Grid Code, applicable Central Electricity Authority (“CEA”) technical standards, connectivity, communication and protection requirements, and other standards, procedures and guidelines approved by MERC.
• Owners or operators of InSTS-connected BESS would be designated as “State Entities” and would be required to comply with applicable requirements relating to connectivity, communication, metering, scheduling and despatch, operation, maintenance and system security.
• Introduction of specific real-time telemetry and operational data requirements for BESS and obligation to provide State Load Despatch Centre (“SLDC”) with information, including charging/discharging status, available energy, charging and discharging capacity, and State of Charge (SoC) through approved communication systems. 
• BESS would be required to comply with SLDC directions for charging, discharging, frequency support, voltage regulation, congestion management, reserve support, system restoration, and grid security.
• InSTS-connected BESS would be required to participate in scheduling and despatch in accordance with the Grid Code and SLDC procedures.

The comments, suggestions or objections can be submitted within 21 days (online) or by 5 PM on 12.10.2026 (hard copy). Counter submissions to the comments, suggestions or objections can be filed by 15.10.2026.

The public notice dated 22.09.2026 can be accessed here. The Draft Grid Code Amendment Regulations can be accessed here.

MERC invites comments on the Draft MERC (Forecasting, Scheduling and Deviation Settlement for Solar and Wind Generation) (Second Amendment) Regulations, 2026

The MERC vide public notice dated 22.09.2026, has invited comments, suggestions or objections on the Draft MERC (Forecasting, Scheduling and Deviation Settlement for Solar and Wind Generation) (Second Amendment) Regulations, 2026 (“Draft DSM Amendment Regulations”). The Draft DSM Amendment Regulations seek to amend the MERC (Forecasting, Scheduling and Deviation Settlement for Solar and Wind Generation) Regulations, 2018 to address increasing renewable penetration, including solar, wind and wind-solar hybrid projects, and support the objectives of the Maharashtra Renewable Energy and Energy Storage Policy (2025-26 to 2035-36).

The key highlights of the Draft DSM Amendment Regulations are as follows:

• Sale or self-consumption of electricity within Maharashtra by an existing Wind and Solar (“WS”) seller would be commercially settled on the basis of Scheduled Generation from an “Implementation Date” to be notified by MERC, which shall not be later than 01.04.2028. 
• To facilitate the transition towards schedule-based deviation assessment, the parameter “X” used for computing Absolute Error would be progressively reduced, as specified. Prior to the Implementation Date, these values would apply only for trial accounting and would not affect final commercial settlement.
• Deviations of new WS projects would be governed directly by the provisions applicable to a General Seller under MERC’s DSM Regulations where the project is awarded through tariff-based competitive bidding with the last date for bid submission on or after 01.01.2027, or, in other cases, where the commercial operation date is on or after 01.01.2029.
• Existing WS Sellers would continue under the forecasting and scheduling framework, including the proposed transition mechanism.
• Until the Implementation Date, the existing commercial settlement mechanism would continue, while the SLDC would issue parallel trial accounts for at least 3 complete monthly settlement cycles.

The comments, suggestions or objections can be submitted within 21 days (online) or by 5 PM on 12.10.2026 (hard copy). Counter submissions to the comments, suggestions or objections can be filed by 15.10.2026.

The MERC public notice dated 22.09.2026 can be accessed here. The Draft DSM Amendment Regulations can be accessed here.

MERC invites comments on the Draft MERC (Intra-State Transmission Connectivity and General Network Access) Regulations, 2026

The MERC vide public notice dated 22.09.2026 has invited comments, suggestions or objections on the Draft MERC (Intra-State Transmission Connectivity and General Network Access) Regulations, 2026 (“Draft GNA Regulations”). The Draft GNA Regulations seek to establish a consolidated framework for grant of Connectivity, General Network Access (“GNA”) and Temporary General Network Access (“T-GNA”) to the Intra-State Transmission System (“InSTS”) in Maharashtra. Upon notification, the MERC (Transmission Open Access) Regulations, 2016 would be repealed.

The key highlights of the Draft GNA Regulations are as follows:

• Generating stations, renewable energy generating stations (“REGS”), captive generating plants, standalone Energy Storage Systems (“ESS”), Renewable Power Park Developers (“RPPD”), Distribution Licensees and eligible Bulk Consumers/Captive Users may seek Connectivity.
• Minimum threshold is generally proposed at 5 MW for generating stations, captive plants, standalone ESS and RPPD, including through aggregation using Lead Generator/Lead ESS arrangements.
• Proposed integration of ESS and differential access for solar and non-solar hours.
• REGS applying for Connectivity would generally be required to install ESS corresponding to prescribed proportions of the Connectivity capacity, with minimum discharge-duration requirements.
• Defined timelines and financial requirements for processing Connectivity applications.
• Eligible entities for GNA include Distribution Licensees, drawee entities including Bulk Consumers and Captive Users connected to the InSTS, Intra-State Transmission Licensees requiring auxiliary power and standalone ESS requiring power for charging/auxiliary consumption. 
• Flexibility in utilisation of access rights, permitting a GNA grantee, with prior approval, to authorise another eligible GNA grantee to use its GNA, wholly or partly, for up to 3 years at a time, while the original grantee remains liable for transmission charges.
• GNA may be relinquished, wholly or partly, generally subject to 1 year’s notice and applicable relinquishment charges.
• Curtailment hierarchy in case of transmission constraints, with non-RE T-GNA, RE T-GNA, non-RE GNA and RE GNA consumers being curtailed sequentially, followed by T-GNA/GNA of Distribution Licensees, with pro-rata curtailment within each category.
• Open Access Monitoring and Review Committee to be convened by the State Transmission Utility for monitoring implementation of the Connectivity and GNA framework, examining implementation issues and periodically recommending remedial measures to the Commission.

The comments, suggestions or objections can be submitted within 21 days (online) or by 5 PM on 12.10.2026 (hard copy). Counter submissions to the comments, suggestions or objections can be filed by 15.10.2026.

The MERC public notice dated 22.09.2026 can be accessed here. The Draft GNA Regulations can be accessed here.

MERC allows simultaneous Net Metering and Open Access for rooftop solar consumers

MERC vide its order dated 18.09.2026 in Case No. 259 of 2025, Alfa Biomed India Private Limited v. Maharashtra State Electricity Distribution Company Ltd. (MSEDCL), held that a consumer having a Rooftop Renewable Energy Generating System (RREGS) can simultaneously avail Open Access and Net Metering. The Commission directed MSEDCL to restore the Petitioner’s Net Metering arrangement and undertake reconciliation and consequential adjustment/refund of the excess amount recovered, along with applicable interest under Section 62(6) of the Electricity Act, 2003.

The Commission observed that Regulation 3.4 of the MERC (Distribution Open Access) Regulations, 2016, inserted through the 2023 Second Amendment, expressly permits consumers having rooftop renewable energy systems to simultaneously avail Open Access. The earlier provision requiring gross metering adjustment during the Open Access period had also been deleted. Accordingly, MSEDCL could not unilaterally switch an approved Net Metering arrangement to Gross Metering merely because the consumer was availing Open Access.

The Commission also rejected MSEDCL’s contention that alleged procedural issues relating to Green Energy Open Access (GEOA) approval disentitled the Petitioner from Net Metering benefits. It noted that the dispute concerned the billing of an already approved rooftop solar installation under a Net Metering arrangement and that MSEDCL itself had granted STOA approvals for the relevant period. The Commission further relied on its earlier orders and held that similarly placed consumers must be treated uniformly. The relief granted to the Petitioner, including restoration of Net Metering benefits and consequential billing adjustment/refund with applicable interest, was made subject to the final outcome of Case No. 232 of 2024.

BERC invites comments on draft RPO (1st Amendment) Regulations, 2026

The Bihar Electricity Regulatory Commission (“BERC”) has issued the Draft BERC (Renewable Purchase Obligation, its compliance and REC Framework Implementation) (1st Amendment) Regulations, 2026 (“draft RPO Amendment Regulations”), in exercise of power under Section 181(2)(zd) read with Sections 61, 66 and 86(1)(e) of the Electricity Act, 2003, pursuant to Suo-Motu Proceedings No. SMP-40/2026, proposing to amend the BERC (Renewable Purchase Obligation, its compliance and REC Framework Implementation) Regulations, 2025 (“Principal Regulations).

The draft RPO Amendment Regulations propose to exclude electricity consumed from nuclear sources from the Renewable Purchase Obligation (“RPO”) for all obligated entities and require open access consumers and captive users specified as obligated entities to meet their RPO from any renewable source, with RPO for open access consumers computed on electricity drawn from the grid.

For captive users, self-consumed electricity (net of auxiliary consumption) is proposed to be included within RPO, subject to certain exclusions, namely waste heat recovery from fossil-based sources (barring a Waste Heat Recovery Steam Generator in a captive Combined Cycle Gas-Based Generating Station), waste energy recovery from industrial by-product gases, and 50% each of fossil-fuel based co-generation and aluminium smelter consumption. For distribution licensees, RPO is proposed to be computed on electrical energy supplied within their periphery, excluding open access consumption sourced elsewhere and captive self-consumption. 

The draft RPO Amendment Regulations also introduce a phased Energy Storage Obligation, rising from 2.5% in FY 2026-27 to 4% in FY 2029-30 of total RPO, to be met through solar/wind energy with or through storage, and forming part of overall RPO compliance. Further, a new compliance mechanism is proposed allowing payment of the buyout price fixed by the Central Electricity Regulatory Commission, with 75% of buyout proceeds to be routed from the Central Energy Conservation Fund to State Energy Conservation Funds for development of renewable and storage capacities. The existing Annexure-I on illustrative RPO computations stands replaced, and a new Annexure-II prescribing reporting formats for distribution licensees, captive users and open access consumers has been proposed. 

Comments/objections on the draft RPO Amendment Regulations may be addressed to Secretary, Bihar Electricity Regulatory Commission, Vidyut Bhawan-II J.L. Nehru Marg, Bailey Road, Patna-800021 by 08.10.2026, and the interested stakeholders and the general public may appear before the BERC in the public hearing scheduled for 13.10.2026 at 11:30 A.M. A copy of the draft RPO Amendment Regulations can be viewed here.

JERC (Goa & UTs) proposes amendments to Electricity Supply Code and Standard of Performance Regulations

The Joint Electricity Regulatory Commission for the State of Goa and Union Territories (“JERC”) has issued the Draft Joint Electricity Regulatory Commission for the State of Goa and Union Territories (Electricity Supply Code) (Fourth Amendment) Regulations, 2026 (“Draft Supply Code Fourth Amendment Regulations) proposing amendments to JERC (Electricity Supply Code) Regulations, 2018. 

Under the Draft Supply Code Fourth Amendment Regulations, no inspection would be required for connections at Low Tension, with the owner/consumer instead required to submit self-certification, and electrical installations for such connections would not be subjected to testing, with the licensee accepting self-certification in Form II & III as prescribed under the CEA (Measures Relating to Safety and Electric Supply) Regulations, 2023. The draft Regulations also propose revised timelines for new connections, namely 3 days in metro/urban/municipal areas, 7 days in rural areas, and 15 days in rural areas of islands, from receipt of a complete application, and, where network extension, transformer capacity enhancement, or commissioning of new substations is required, supply within 90 days of such extension or commissioning. 

JERC has also issued the Draft Joint Electricity Regulatory Commission for the State of Goa and UTs (Standard of Performance for Distribution Licensees) (Second Amendment) Regulations, 2026 (Draft SoP Second Amendment Regulations) proposing to amend amend Schedule-III (Compensation) of the JERC (Standard of Performance for Distribution Licensees) Regulations, 2015, so as to align compensation timelines for release of new connections with the same 3/7/15-day framework. 

The JERC has invited Comments/suggestions on both draft Regulations which may be addressed by email or post to the Secretary, Joint Electricity Regulatory Commission (for the State of Goa & Union Territories), 3rd & 4th Floor, Plot No. 55-56, Udyog Vihar, Phase- IV, sector- 18, Gurugram, Haryana 122015 (email: secy.jercuts@gov.in) latest by 19.10.2026. Both the draft JERC Amendment Regulations can be viewed here.