India Solar EPC Compliance Calendar 2026-27

Why EPCs need a compliance calendar for 2026-27

Solar EPC compliance is no longer limited to selecting a module and submitting a single-line diagram. A project can be technically complete and still face a delay because the wrong module list was used, the inverter cannot meet a data requirement, a DCR record is missing, a DISCOM form has changed, or commissioning evidence is incomplete.

The challenge is that these requirements sit across different schemes, ministries, regulators, utilities and project types. A rooftop project under PM Surya Ghar does not follow the same evidence trail as a PM-KUSUM feeder project. A private commercial project using green open access has a different approval path from a residential net-metering system. A battery project commissioned in 2027 may also need to meet safety requirements that were not in force when its initial design was prepared.

This calendar is designed as a planning reference for EPC teams. It brings together the main dates, documents and decisions that should be tracked from September 2026 through March 2027. It does not replace the latest MNRE order, CEA regulation, state commission rule, DISCOM circular or project tender.

The 2026-27 calendar at a glance

This is an operational synthesis, not an official government calendar. Dates and rules should be checked again before a purchase order, customer commitment or commissioning decision.

1. ALMM List-I and List-II: the procurement dates EPCs should track

The Approved List of Models and Manufacturers, or ALMM, is one of the most important procurement checks for projects that fall within its scope. The MNRE ALMM page states that listed module models and manufacturers apply to government and government-assisted projects, government schemes and programmes, open-access projects and net-metering projects installed in India.

The lists are updated regularly. The current page records a List-I module revision dated 16 September 2026 and a List-II solar PV cell revision dated 21 August 2026. An EPC should not rely on a saved spreadsheet or an old supplier presentation when placing an order.

A basic ALMM control should include:

• the project category and the rule that makes ALMM applicable;
• the module manufacturer and exact model;
• the cell manufacturer and cell model where List-II applies;
• the date on which the live list was checked;
• supplier declarations and purchase documents;
• serial-number or batch-level records where available; and
• a final verification before commissioning.

What the 31 December 2026 window does and does not mean

MNRE's 18 July 2026 List-II notice says there is no blanket extension for List-II. It provides a limited window through 31 December 2026 for commissioning certain net-metering and open-access renewable-energy projects, subject to the conditions and investment-protection requirements in the notice.

This distinction matters. The date is not permission to use non-compliant cells across all project types. It is not an automatic exemption for government schemes, PM-KUSUM or every commercial rooftop project. The EPC should first confirm that the project qualifies, then retain the documents that prove the applicable commissioning and investment facts.

2. DCR rules: verify the project category before buying modules

Domestic Content Requirement, or DCR, is not a universal rule for every privately financed solar project. It is linked to the relevant scheme, programme, tender or procurement condition.

For crystalline-silicon cells, the MNRE DCR clarification defines qualifying domestic manufacturing through the required processes beginning with an undiffused silicon wafer, also described as a black wafer. Cells made using imported diffused silicon wafers do not qualify under that clarification. Integrated thin-film modules manufactured in India remain eligible under the cited rules.

Before releasing a DCR-sensitive purchase order, the EPC should answer four questions:

1. Which scheme, tender or customer requirement makes DCR applicable?
2. Is the module and cell combination eligible under the current rule?
3. Can the manufacturer provide the required DCR evidence and serial-number traceability?
4. Will the same equipment remain acceptable at commissioning, not only at the quotation stage?

For PM Surya Ghar and PM-KUSUM work, DCR verification is not just a supplier claim. The EPC should retain manufacturer declarations, invoices, module serial numbers and evidence from the NISE DCR Verification Portal. The operational guidance says that, from 1 December 2024, modules whose DCR credentials cannot be verified through the portal are not accepted under PM Surya Ghar and PM-KUSUM.

3. PM Surya Ghar: the 2026-27 customer and vendor workflow

The PM Surya Ghar scheme is scheduled to run through 31 March 2027. For EPCs, the important point is that the subsidy is not created when a module is installed. It depends on a chain of customer, vendor, technical, inspection and portal records.

The typical project sequence is:

1. The consumer submits the application and receives a Consumer Account Number.
2. The consumer selects a registered vendor.
3. The DISCOM completes feasibility and the EPC confirms the approved system configuration.
4. The EPC installs the system using eligible equipment.
5. Pre-installation and post-installation geo-tagged photographs and project details are uploaded.
6. The DISCOM inspects the installation and completes the applicable meter and approval steps.
7. The vendor and consumer submit the required bank and claim information.
8. The CFA process moves through the portal and applicable agency workflow.

The PM Surya Ghar consumer portal describes the live customer journey. Exact KYC, ownership, bank, meter and DISCOM requirements can still vary by state.

PM Surya Ghar vendor obligations EPCs should not overlook

The amended operational guidelines require registered vendors to provide a free five-year comprehensive maintenance contract. They also specify a minimum performance ratio of 75% at commissioning and during the five-year warranty period.

That changes how an EPC should prepare its project file. It should contain more than a quotation and installation photograph. The file should include:

• approved system capacity and equipment details;
• module and inverter serial numbers;
• DCR and ALMM evidence where applicable;
• installation and safety photographs;
• test reports and commissioning readings;
• inspection and meter records;
• consumer acceptance;
• warranty and AMC terms; and
• a clear route for handling service requests over five years.

The current MNRE inverter-data notice adds another procurement check. EPCs should qualify inverter OEMs that can support the required generation data, serial-number mapping, monitoring infrastructure and data storage conditions. This should be checked before the inverter is ordered, not after the portal rejects the application.

4. PM-KUSUM: treat each component and sanction separately

PM-KUSUM should not be placed in the calendar as one generic deadline. Components A, B and C have different project types, stakeholders, procurement conditions and completion evidence.

The MNRE PM-KUSUM overview currently states a scheme period ending on 31 March 2026. Later operational documents and project-specific orders may continue to affect awarded or sanctioned work, but no blanket national extension beyond that date should be assumed without checking the relevant MNRE order, state agency notice or tender.

Component A

Component A covers decentralized grid-connected renewable plants, generally in the 500 kW to 2 MW range. For an awarded project, the EPC should map land or site control, evacuation, PPA, financing, procurement, construction, testing and commercial operation against the applicable letter of award and state implementation schedule.

The cited Component A guidelines use a 15-month commissioning period from the letter of award for the relevant project structure. They also require records such as joint meter reports and lease-rent documents for applicable benefit claims. The PPA and DISCOM conditions must be checked for each state.

Components B and C

Component B covers standalone solar agricultural pumps. Component C covers solarisation of existing agricultural pumps and feeders. The cited scheme documents use a 24-month completion period from MNRE sanction for Components B and C, while state tenders and implementing agencies add their own milestones.

A Component B or C file may need to show beneficiary and pump verification, vendor award, equipment delivery, installation, inspection, commissioning, project completion, utilization certificates and warranty or AMC records. Component B vendors also need to plan for five-year AMC, insurance, periodic inspection and local-language support under the scheme documents.

The MNRE QCO compliance memorandum for PM-KUSUM specifically reiterates compliance with the 2017 Quality Control Order for relevant SPV inverters up to 100 kW. The exact product capacity, BIS registration and current tender specification should be checked before equipment is released.

5. Net metering, open access and state-level variation

A common mistake is to write one national net-metering promise into every proposal. India has national frameworks, but the working process is controlled by the relevant State Electricity Regulatory Commission, DISCOM, nodal agency and project category.

The state checklist may change:

• eligible system capacity;
• net metering, gross metering, net billing or net feed-in route;
• application forms and fees;
• technical feasibility documents;
• meter type and testing process;
• inspection authority;
• synchronization requirements;
• approval validity; and
• the time allowed for construction after approval.

Green Energy Open Access

The Green Energy Open Access Rules reduced the eligibility threshold to 100 kW for many non-captive consumers, including aggregated connections within the same electricity division. Captive consumers have no load limitation under the second amendment. The Ministry of Power and Green Open Access framework also describes a 15-day approval process and a central Green Energy Open Access Registry route.

The 100 kW threshold does not mean that every eligible customer receives the same economics. Transmission, wheeling, cross-subsidy, standby, banking, scheduling and deviation-related charges can materially change the project case. The EPC should model the state-specific charges and collect the correct consumer, source, scheduling and metering documents before promising savings.

Three state examples

These examples are not interchangeable. A state matrix should be maintained as a live internal document with the source circular, date checked, application portal, responsible owner, document list and latest known processing time.

6. BESS safety: prepare now for the 1 April 2027 start date

The CEA Measures relating to Safety and Electric Supply Amendment Regulations, 2026 add a new BESS safety chapter. The amendment is scheduled to commence on 1 April 2027.

The requirements include controls around:

• BMS monitoring and event recording;
• voltage, current, temperature and thermal-runaway alarms;
• automatic shutdown;
• hazard detection and fire suppression;
• power-conversion-system fault tolerance;
• location, separation and access controls;
• security fencing and emergency stops; and
• independent third-party fire-safety audits under an Authority SOP.

The CEA has also issued fire-safety training guidance for BESS installations. Developers and operators should facilitate site visits, provide emergency-response plans and technical documents, and participate in drills and familiarisation exercises.

Some implementation documents, including the detailed standards list and audit SOP, are expected to be issued around the commencement framework. EPCs should therefore design a process that can absorb the final documents instead of treating today's supplier datasheet as a complete 2027 compliance file.

7. Proposed 2027 grid and storage requirements: watch, do not overstate

The CEA has proposed requirements that could affect future renewable and storage projects. The draft identified in the current research proposes that renewable power plants commissioned after 1 July 2027 have at least 15% of inverters with grid-forming control. It also proposes grid-forming control for BESS power-conversion systems and co-located energy storage equal to at least 10% of installed plant capacity with two hours of storage for certain ground-mounted solar and onshore wind projects.

The later proposal increases the storage duration for a future commissioning period. These requirements are still in draft form. The CEA draft notice invited stakeholder comments, with a date identified as 4 October 2026.

For now, an EPC should:

• flag the proposal during early design reviews for projects commissioning after 1 July 2027;
• ask suppliers about grid-forming capability and future firmware support;
• avoid pricing the draft requirement into every current project;
• label the item as a design risk or policy watch item; and
• replace the draft note with the final Gazette notification if the rule is notified.

A proposal is useful for planning. It is not a compliance certificate.

What EPCs should do now

This six-step process is simple, but it prevents a common EPC failure: discovering a compliance issue only after the equipment has been ordered or the installation is complete.

Where 3D design and automated BOMs fit in

Policy compliance still depends on the applicable authority and the EPC's responsibility. Software cannot replace a state regulation or a DISCOM approval.

It can, however, reduce the document mismatch that causes avoidable rework. A design-linked workflow can keep the roof or site layout, equipment schedule, electrical drawings, structural details and material quantities aligned when the design changes. That is useful when an EPC needs to issue a revised submission pack, prove what was installed, or respond to an inspection comment.

Reslink supports mobile site and roof mapping, automatic panel placement, live 3D revisions, PV and array layout drawings, and automated electrical and structural BOMs. For a compliance-heavy project, the practical benefit is not a generic promise of automation. It is fewer disconnected versions between the design, procurement file, plan set and final as-built record.

To see how the design and documentation workflow can fit into your EPC process, book a demo.

Frequently Asked Questions

Q1. What is the most important solar EPC deadline in India for 2026?

There is no single deadline for every project. The most relevant dates in this calendar are 17 October 2026 for the current MNRE inverter-data compliance window, 31 December 2026 for the limited ALMM List-II commissioning window for qualifying net-metering and open-access projects, and 31 March 2027 for the PM Surya Ghar implementation period. Applicability must be confirmed project by project.

Q2. Does the 31 December 2026 ALMM date apply to all solar projects?

No. MNRE's notice describes a limited window for qualifying net-metering and open-access renewable-energy projects. It is not a blanket List-II extension and should not automatically be applied to PM-KUSUM, government-assisted projects or every commercial rooftop installation.

Q3. Is DCR compulsory for every solar project in India?

No. DCR depends on the relevant scheme, tender, programme or procurement condition. It is important for projects such as PM Surya Ghar and PM-KUSUM where the applicable rules require domestic content. A private project outside those conditions should be checked against its own contract and regulatory requirements rather than assumed to be DCR or non-DCR.

Q4. Does PM Surya Ghar end on 31 March 2027?

The scheme guidelines identify 31 March 2027 as the implementation end date. EPCs should still follow the live national portal, MNRE amendments and DISCOM instructions because application, installation, inspection, metering and CFA evidence may have separate operational controls.

Q5. Can an EPC use one net-metering checklist across India?

No. The national framework does not remove state and DISCOM variation. Forms, capacity thresholds, feasibility, fees, meter testing, inspection, approval validity and synchronization can differ. EPCs should maintain a state matrix and verify the latest SERC, DISCOM and nodal-agency documents before submission.

Q6. Are the proposed 2027 grid-forming and storage rules already mandatory?

No. The CEA provisions identified in this article are draft proposals. They may change before notification. EPCs should track them for projects with later commissioning dates, but should not present them to customers as current enforceable requirements.

Q7. When do the new CEA BESS safety requirements start?

The 2026 amendment is scheduled to commence on 1 April 2027. It introduces requirements covering monitoring, alarms, automatic shutdown, fire protection, emergency access and third-party fire-safety audits. EPCs should also monitor the supporting standards list and audit SOP as they are issued.

Final takeaway

The useful way to read India's 2026-27 solar policy environment is as a series of project gates, not a long list of circulars.

Before procurement, check ALMM, DCR, QCO and inverter-data eligibility. Before submission, check the state and DISCOM process. Before commissioning, confirm that the installed system matches the approved design and that the evidence file is complete. For projects crossing into 2027, add the CEA BESS safety amendment and keep proposed grid-forming requirements in a separate policy watchlist.

For EPCs, the advantage comes from making these checks part of the design and delivery workflow rather than treating compliance as paperwork at the end.

Sources

• MNRE Approved List of Models and Manufacturers
• MNRE notice on ALMM List-II and the 31 December 2026 commissioning window
• MNRE clarification on Domestic Content Requirement for solar PV cells
• NISE DCR Verification Portal
• PM Surya Ghar operational guidelines
• PM Surya Ghar consumer portal
• MNRE PM-KUSUM scheme overview
• MNRE memorandum on QCO compliance under PM-KUSUM
• Ministry of Power summary of the Green Energy Open Access framework
• MSEDCL net-metering procedure
• CEA Measures relating to Safety and Electric Supply Amendment Regulations, 2026
• CEA fire-safety training guidance for BESS installations
• CEA draft notice on proposed grid-forming and co-located storage requirements