India Solar Compliance Guide 2026: Regulations, Incentives, and Net Metering for EPCs

India crossed 100 GW of installed solar capacity in 2025 and is targeting 280 GW by 2030. Rooftop solar is the fastest-growing part of that buildout, pushed by a central subsidy scheme that has already reached more than 1 million homes.

India is also the largest source of readers for this blog, and the questions we hear most often are not about panels or inverters. They are about paperwork.

Compliance in India runs through 4 layers. The central ministry sets policy, an approved list controls which modules you can use, state regulators set net metering rules, and local DISCOMs approve every grid connection. A missing certificate or a wrong model number can stall a project for weeks.

The stakes are commercial, not just procedural. On a typical residential job, a 3-week approval delay erases most of the net margin once labor rescheduling and working capital are counted.

On C&I projects, a compliance miss can void financing. The installers who treat compliance as a core skill, not an afterthought, are the ones growing in 2026.

This guide consolidates the full compliance stack for EPCs and installers in 2026. We cover the central framework, subsidy workflows, state-by-state net metering, DISCOM approvals, commercial rules, and the mistakes that delay projects. Use it as your India solar compliance hub, and check back as we update it with each policy change.

In this guide:

• What changed in India solar policy in 2026 — ALMM List-II, subsidy progress, and net billing shifts
• The central framework: MNRE, ALMM, CEA standards, and BIS certification explained
• PM Surya Ghar subsidy rates, vendor registration, and the full EPC workflow
• Which modules you can and cannot use — List-I, List-II, and DCR rules
• Net metering rules for Maharashtra, Gujarat, Karnataka, Delhi, and other major states
• The DISCOM approval workflow with a document checklist and realistic timelines
• Commercial and industrial compliance: open access, CEIG approval, and GST treatment
• How to register and scale an EPC business, plus 10 mistakes that delay projects

Latest Updates: India Solar Policy 2026

Policy moved on 3 fronts in 2026: cell-level domestic content rules, subsidy scheme scale-up, and export compensation reviews. The table below summarizes what is in force as of July 2026 and what we think EPCs should do about each item.

ALMM List-II raises the bar on cells

From June 1, 2026, modules used in government-supported schemes must contain cells from ALMM-listed manufacturers. Domestic content rules previously stopped at the module level. This extends them 1 step up the supply chain.

The practical impact lands on procurement. Ask every module supplier for written confirmation that the cells inside their panels are on List-II, and keep that confirmation in the project file. Expect some non-compliant inventory to be discounted into the open market as the deadline passes.

PM Surya Ghar keeps scaling

The scheme crossed 1 million household installations in 2025, according to MNRE updates. Approval capacity is now the binding constraint in high-volume districts, not demand. Meter supply and inspection backlogs are the 2 bottlenecks we hear about most from installers.

Several states have reviewed export compensation for larger systems in the last 12 months. Net metering remains the default for residential rooftops, while larger commercial systems increasingly face net billing or gross metering terms. Check the current order from your state regulator before you quote export economics.

Rooftop is where the growth is

Utility-scale projects still dominate India’s installed solar capacity, but rooftop is growing faster in percentage terms. PM Surya Ghar is the driver, and it has pulled 1000s of small installers into the market. Distributed growth means distributed compliance — every one of those projects touches a DISCOM, a net meter, and a subsidy file.

The 500 GW target keeps reform pressure on

India’s national target is 500 GW of non-fossil capacity by 2030, with solar carrying roughly 280 GW of it. That run rate is impossible without distributed solar scaling, which is why approval machinery keeps getting reformed.

Expect continued digitization of DISCOM processes and tighter domestic content rules. Both trends favor organized EPCs over informal installers.

Taxes and duties are stable

GST and customs duty show no pending revision going into FY 2026-27. The 12% device rate has been in place since January 2022, and the 40% module duty since April 2022. That stability makes this a good window to lock supplier contracts and standardize pricing across your pipeline.

How to track changes

Assign 1 person on your team to monitor SERC tariff orders and MNRE circulars each month. Most compliance failures we see are stale-information failures, not bad engineering. The July 2026 date at the top of this guide reflects the latest status we have verified.

Central Government Framework: MNRE, ALMM, and CEA Standards

Four institutions define the central compliance layer for solar in India. Each controls a different part of your project, and each keeps its own registry or standard. Understanding who owns what saves you weeks of misdirected paperwork.

MNRE: the nodal ministry

The Ministry of New and Renewable Energy (MNRE) is the central nodal agency for solar. It designs national schemes such as PM Surya Ghar, PM-KUSUM, and the CPSU program, and it sets domestic content policy. MNRE also maintains the ALMM list, which decides which modules qualify for subsidized work.

For EPCs, MNRE is not an approvals body for individual projects. Its rules flow down through scheme guidelines and state implementation. Read MNRE circulars when schemes change, because the details — subsidy rates, eligible capacity, vendor requirements — originate there.

MNRE also runs PM-KUSUM for solar pumps and feeder solarization, and the CPSU scheme for government producers. Both require ALMM-listed equipment. If you work in the agricultural segment, the same module discipline applies as in rooftop work.

CEA: technical and safety standards

The Central Electricity Authority (CEA) sets the technical standards for connecting generation to the grid. The CEA (Technical Standards for Connectivity of the Distributed Generation Resources) Regulations, 2013 cover voltage windows, frequency tolerance, power quality, and anti-islanding protection. The CEA safety regulations, last amended in 2023, govern installation and electric supply safety.

Your inverter and protection scheme must meet CEA requirements before a DISCOM will energize the connection. Ask inverter suppliers for the compliance certificates up front, and check the certificate numbers against the model on your BOM. A cheap inverter without anti-islanding certification cannot legally be connected.

The Central Electricity Authority publishes the full text of the regulations.

BIS: product certification

Modules sold in India must be registered with the Bureau of Indian Standards under the Compulsory Registration Scheme. The key standards are IS 14286 for crystalline silicon modules and IS/IEC 61730 for module safety qualification. Registration sits with the manufacturer, not the importer or trader.

BIS and ALMM are separate systems that are easy to confuse. BIS registration allows a module to be sold in India. ALMM listing allows it to be used in subsidized projects.

A compliant BOM for subsidy work needs both, and the certificates must match the exact model you install. Modules imported for open-market projects still need BIS registration even when ALMM does not apply.

State regulators and DISCOMs

State electricity regulatory commissions (SERCs) set net metering rules, export compensation rates, and standards of performance for approvals. DISCOMs — the state distribution companies — own the grid connection and process every application. The Chief Electrical Inspector to Government (CEIG) certifies electrical safety for larger systems in most states.

A 5th institution shapes the rules indirectly. The Forum of Regulators publishes model net metering regulations that SERCs adapt to their states.

When your state revises its rules, the model regulations tell you where the national direction is heading. Reading them gives you a 12–18 month preview of likely state changes.

Who approves what

The compliance stack is additive. A subsidized residential project needs an ALMM-listed and BIS-registered module, a CEA-compliant inverter, SERC-conformant net metering paperwork, and DISCOM approval. Miss any 1 of them, and the project stalls.

We fix the BOM inside our solar design software before any application goes out. Locking equipment early prevents the most common rejection we see — a design that names a module the DISCOM cannot verify against the current list.

PM Surya Ghar (Muft Bijli Yojana) 2026: Subsidy Guide for EPCs

What the scheme offers

PM Surya Ghar: Muft Bijli Yojana launched in February 2024 with an outlay of ₹75,021 crore. The target is 10 million households, and the headline promise is up to 300 units of free electricity per month for participating homes. The central financial assistance is paid as a direct benefit transfer (DBT) into the customer’s bank account after commissioning.

The scheme also includes 2 supporting components worth knowing. Households can access scheme-linked loans up to ₹2 lakh at concessional rates through public sector banks. And each district is slated to get a model solar village that demonstrates rooftop adoption at community scale, with utility-led aggregation to push volume.

The portal also publishes district-wise installation data, which makes DISCOM backlogs visible for the first time. Use it to set customer expectations by geography before you sign.

Subsidy rates in 2026

*Assumes installed costs of ₹55,000–₹70,000 per kW before subsidy.

The structure is ₹30,000 per kW for the first 2 kW and ₹18,000 for the 3rd kW. There is no central subsidy beyond 3 kW, though households may install larger systems at full price. Some states have offered top-up subsidies in the past, so check your state portal before quoting.

Eligibility rules

• The applicant must be an Indian household with a valid electricity connection and rights to the roof.
• The system must be grid-connected and use ALMM-listed, domestically manufactured modules.
• The household must not have claimed central rooftop subsidy before.
• Installation must go through a vendor registered on the national portal with the local DISCOM.

The EPC workflow, step by step

1. Register as a vendor with your DISCOM on the PM Surya Ghar portal. You need GST registration, PAN, and bank details, and some states also ask for an electrical contractor license.
2. The customer applies on the portal with their electricity bill and roof details, and selects you as the vendor.
3. The DISCOM issues a feasibility approval for the connection.
4. Install the system with ALMM-listed modules and a CEA-compliant inverter.
5. Submit the work completion report and request inspection. The DISCOM inspects the site and installs the bidirectional meter.
6. The commissioning certificate is issued, and the subsidy reaches the customer’s account, typically within 30 days.

After commissioning: DBT tracking and grievances

The subsidy goes to the customer, but the customer will call you when it is late. Track the commissioning certificate number and DBT status on the portal for every project. If payment crosses 30 days, the customer can raise a grievance on the portal or with the DISCOM.

Keep your vendor-side records ready, because disbursal can pause if inspection photos or documents are questioned. We log every commissioning date in a shared sheet and follow up at day 15 and day 25. That habit has kept our average disbursal close to the 30-day mark.

Quoting subsidy projects

A 3 kW system typically costs ₹1.65–₹2.1 lakh before subsidy, so the customer pays roughly ₹0.9–₹1.3 lakh after the ₹78,000 credit. At residential tariffs of ₹6–8 per unit, payback runs 3–5 years. Model the exact cash flows with our /generation-financial-tool, and present the subsidy math inside the quote using our solar proposal software.

For financing-led customers, the scheme-linked loan changes the pitch. The monthly EMI on a ₹1.3 lakh loan at concessional rates often lands close to the bill savings, which makes the cash-flow story positive from year 1. Quote both the cash and loan scenarios side by side.

The payback methodology is the same one we apply in other markets — see /blog/solar-panel-roi-italy for the year-by-year model. Swap the tariff and irradiance inputs, and the structure holds for Indian cities.

The contrarian case: do not build your whole pipeline on subsidy work

Subsidy volume is attractive, but it carries 3 structural costs. DBT timing is outside your control, so receivables stretch when inspections back up. Price competition among registered vendors is intense, and gross margins on portal-driven residential jobs often land in the 8–12% range.

Portal rules and rates can also change with a single circular.

We learned this at Heaven Green Energy running EPC projects in Gujarat and Maharashtra. We now cap scheme-driven residential work at roughly 60% of the pipeline and keep the rest in open-market residential and C&I, where margins per megawatt run 2–3 times higher. Subsidy work builds volume and brand, and open-market work pays the bills.

ALMM Compliance: What Modules You Can and Cannot Use

What ALMM is

The Approved List of Models and Manufacturers (ALMM) is MNRE’s registry of compliant solar equipment. List-I covers modules and has been mandatory for government-supported projects since 2021. List-II covers cells and applies from June 1, 2026.

A listed module has verified manufacturing details, test certificates, and a declared factory. MNRE reviews listings and removes models that fail verification. The list changes, so the version in force on your commissioning date is the one that matters.

Where ALMM applies

DCR versus non-DCR

Domestic Content Requirement (DCR) means the cells and the module were both manufactured in India. Subsidy schemes require DCR-compliant equipment. Non-DCR modules — imported cells assembled in India, or fully imported panels — are legal to sell but restricted to open-market projects.

From June 2026, the practical gap between the 2 categories narrows. List-II forces listed cells into scheme projects, so manufacturers must show cell provenance either way. Treat cell documentation as part of every BOM review from now on.

How to verify a module in 5 steps

1. Download the current ALMM list from the MNRE website.
2. Match the exact model number and wattage bin on your datasheet — a 545 W variant and a 550 W variant are separate entries.
3. Confirm the manufacturer name, not the trader or brand reseller.
4. Check the validity dates on the listing and on the BIS registration.
5. Save a dated copy of the list entry in the project file.

Reading an ALMM entry

Each entry shows the manufacturer, factory location, model series, wattage range, and validity dates. The wattage range matters: a series listed from 530 W to 560 W covers every bin inside it, while a model outside that range is not covered. Screenshot the entry with the date visible, and file it with the project records.

What happens if a model gets delisted mid-project

MNRE can remove models when manufacturers fail review. If a model on your BOM is delisted before commissioning, the DISCOM can question the subsidy claim even if procurement happened while the model was listed. The defense is documentation: purchase invoices, the dated ALMM entry from your procurement date, and delivery records.

Where a project has not yet been procured, swap to a listed alternative immediately. This is why we verify the list at 3 points — quote, procurement, and commissioning — rather than once at the start.

The trade-off: ALMM costs money and narrows supply

Listed modules have historically carried a 10–15% price premium over imported equivalents, and supply tightens around policy deadlines. The basic customs duty (BCD) of 40% on modules and 25% on cells, in place since April 2022, already makes imports expensive. The June 2026 List-II shift will squeeze remaining non-compliant inventory into the open market at discounts.

Here is the contrarian view. For open-market C&I projects with no subsidy, some EPCs still buy non-listed Tier-1 imports to save on module cost. After BCD, logistics, and warranty risk, the saving is usually 3–5% at best — and you lose the ability to pivot the stock into subsidy work.

We standardize on ALMM-listed BOMs across all segments so 1 supply chain serves every project type.

The supply picture is improving. Domestic nameplate module manufacturing capacity crossed 80 GW in 2025, and the premium over imports has narrowed as new factories ramp. Procurement discipline matters more than brand selection at this point.

State-by-State Net Metering and DISCOM Approval Guide

How net metering works in India

Net metering credits exported solar units against imported units on the same electricity bill. Net billing credits exports at a regulated feed-in rate that is usually below the retail tariff. Under gross metering, the DISCOM buys all generation and sells all consumption at their respective rates.

The central baseline comes from the Electricity (Rights of Consumers) Rules, 2020, which provide for net metering up to 500 kW. State commissions build their own regulations on top of that baseline, and the details differ. Size caps, export rates, and meter costs all vary by state and sometimes by DISCOM.

Maharashtra

The Maharashtra Electricity Regulatory Commission issued net metering regulations in 2015 and has amended them since. MSEDCL runs an online application portal, and systems up to 1 MW are generally eligible. Residential PM Surya Ghar applications move through the national portal, with MSEDCL handling feasibility and metering.

Maharashtra also applies grid support charges to some larger consumer categories. Verify the current order on the MERC website before quoting export economics for C&I clients.

Gujarat

GERC’s net metering framework covers residential and commercial consumers, generally up to the sanctioned load. Applications go through the 4 state DISCOMs — UGVCL, DGVCL, MGVCL, and PGVCL — or Torrent Power in Ahmedabad and Surat. Gujarat was an early mover on rooftop policy, and its DISCOM portals are among the most mature in the country.

Karnataka

KERC’s rooftop regulations provide net metering for residential and LT commercial consumers, with caps set by DISCOM and consumer category. BESCOM processes applications online for the Bengaluru region. HT consumers are typically compensated on a net billing or feed-in basis rather than retail net metering.

Delhi

DERC’s net metering regulations allow systems up to the sanctioned load. Delhi also pioneered virtual net metering (VNM) and group net metering (GNM), which let apartment residents and government buildings share generation across multiple connections. Check the DERC website for current rates and eligibility conditions.

Tamil Nadu and Rajasthan

Tamil Nadu’s TNERC framework offers net metering to residential LT consumers, while HT consumers are generally compensated on a net feed-in basis. TANGEDCO inspections are thorough, and structural certificates get checked on larger roofs. Rajasthan’s RERC regulations cover the 3 state DISCOMs, with category-based caps and strong uptake in the subsidy segment.

Uttar Pradesh and Telangana

Both states offer residential net metering with category-based caps, and both have grown in the subsidy segment since 2024. UP runs applications through a portal plus subdivision offices, so expect more manual follow-up than in Gujarat or Maharashtra. Telangana splits service between 2 DISCOMs — TSSPDCL for Hyderabad and TSNPDCL for the rest of the state.

Comparison table

Caps and rates change with each tariff order. Verify the current SERC order before quoting export economics, and re-check at commissioning if the project spans a tariff revision. A 6-month-old quote can be wrong even when the underlying hardware cost has not moved.

Net billing is spreading — plan for it

The national direction is clear: residential keeps retail net metering, and larger systems drift toward net billing at regulated feed-in rates. For EPCs, this changes C&I sales math. A system designed for maximum self-consumption holds its value under either regime, while an export-heavy design loses value if the state moves to net billing.

Size C&I systems to daytime load first, and treat export revenue as upside. That design principle survives any compensation regime your state adopts next.

What this means for EPCs

Build a 1-page playbook per state: the forms, the caps, the meter specifications, and the typical approval timeline. For PM Surya Ghar projects up to 3 kW, the national portal overrides much of the state variation, which simplifies multi-state residential operations. Above the subsidy segment, state rules are the project.

The states that frustrate installers most are rarely the ones with strict rules. They are the ones with unclear rules. Where a SERC order is ambiguous, get the DISCOM’s interpretation in writing before you commit a delivery date to the customer.

DISCOM Approval Workflow: Documents, Inspection, and Timeline

The DISCOM approval is the single gate every grid-connected project must pass. The sequence is similar across states, but the portals, forms, and timelines differ. Here is the workflow we follow, with the documents and timing that hold up in practice.

The 7-step approval workflow

1. Pre-check the site. Confirm the sanctioned load, transformer capacity in the area, and clear roof ownership before you quote.
2. File the application on the DISCOM portal — or the PM Surya Ghar portal for subsidized residential — with the full document pack.
3. Receive feasibility approval. The DISCOM reviews technical feasibility, typically in 7–15 days.
4. Install the system per the approved design.
5. Submit the work completion report and request inspection.
6. The DISCOM inspects the site and installs the bidirectional meter. This step is the most common bottleneck.
7. The commissioning certificate is issued, billing starts, and the subsidy is released on PM Surya Ghar projects.

National portal versus DISCOM portal

For PM Surya Ghar residential work, the application lives on the national portal, and the DISCOM acts inside that workflow. For everything else — open-market residential, C&I, and larger systems — you file directly on the DISCOM’s own portal or at its office. The 2 tracks use different document formats and different escalation paths.

Train your office staff on both, and label every project file with the track it follows. Mixing the formats is a common reason applications bounce back in the first week.

Document checklist

What inspectors check on site

Inspectors verify module and inverter earthing, cable routing on the DC and AC sides, protection devices per the approved single-line diagram, and the meter location. Have the installation team present with the approved diagram printed. A failed inspection restarts at the back of the queue, which costs 2–4 weeks in busy districts.

A realistic timeline

End-to-end approval runs 30–90 days in most states. Feasibility takes 7–15 days, installation 3–10 days, and inspection plus meter installation 10–30 days. Commissioning paperwork adds another 7–15 days on top.

Meter supply is the constraint in high-volume districts. When PM Surya Ghar volumes spike, DISCOM meter inventories run short, and the queue stretches. Tell customers the range, and never promise a fixed subsidy date.

What worked for us on the ground

At Heaven Green Energy, we learned to submit the single-line diagram, the inverter compliance certificate, and the ALMM certificates with the initial application — not after the DISCOM asks for them. On our Gujarat residential projects, complete first submissions cleared feasibility in about 2 weeks. Incomplete packs took 6–8 weeks, because each query restarted the queue.

We also file the inspection request on the day installation finishes, and we keep dated copies of every ALMM list version used on a project. That audit trail has settled more than 1 subsidy query at commissioning.

When approvals stall

SERC standards of performance set approval timelines, and some states include deemed-approval or penalty provisions. If a DISCOM misses the timeline, escalate in writing, then to the consumer grievance redressal forum, and finally to the electricity ombudsman. Keep every acknowledgment number from the day you file.

Commercial and Industrial Solar Compliance in India

How C&I differs from residential

There is no central subsidy for C&I rooftop solar. The economics run on tariff arbitrage — commercial grid tariffs of ₹7–10 per unit against a rooftop generation cost of roughly ₹3.5–4.5 per unit. Businesses can also claim accelerated depreciation at 40% on solar assets, which improves post-tax returns in the first years.

The C&I compliance stack

C&I projects face the same central standards as residential, plus 4 extra layers:

1. CEIG approval and electrical inspector certification for larger systems, with thresholds that vary by state.
2. Structural safety certification for rooftops, and fire NOCs for large installations.
3. DISCOM connectivity approval, with HT consumers in several states on net billing or gross metering instead of retail net metering.
4. Open access permissions for captive, group captive, or third-party sale models.

Budget time for the fire NOC early on large plants. Fire department reviews sit outside the DISCOM’s timeline and follow their own queue.

Captive, group captive, and third-party PPA

Structure choice is a compliance decision. In a captive model, the consumer owns the plant, holds at least 26% of the equity, and consumes at least 51% of the generation — meeting both tests exempts the project from cross-subsidy surcharge.

Group captive spreads ownership across multiple consumers under the same 2 tests. Third-party PPA keeps ownership with the developer and attracts the full surcharge stack.

Each state interprets these rules through its own open access regulations. The same structure can be profitable in 1 state and marginal in the next, so model the surcharge stack before you pick the structure.

Open access after the 2022 rules

The Green Energy Open Access Rules, 2022 cut the eligibility threshold to 100 kW, which opened the mechanism to mid-size consumers. A captive or group captive project needs a no-objection from the state load dispatch center and the transmission or distribution utility. Cross-subsidy surcharges, additional surcharges, and banking charges apply, and they vary widely by state.

Model these charges before you structure a third-party PPA. A surcharge revision can move project returns by several percentage points. State commissions publish the applicable charges in their open access orders, and those orders change more often than most sales teams assume.

GST treatment

GST on solar devices has been 12% since January 2022, up from 5% earlier. Works-contract EPC uses a deemed 70:30 split — 70% of the contract value taxed as goods at 12%, and 30% as services at 18%. The effective rate on a full EPC contract works out to about 13.8%.

Show the split in every commercial quote, and align it with how your tax team invoices. The CBIC publishes the rate notifications. Residential subsidy customers see the 12% device rate inside the quoted system price.

Design documentation for C&I

C&I buyers scrutinize generation estimates because financing depends on them. Shadow studies carry real weight on factory roofs with vents, parapets, and hoardings. We run those studies in our solar shadow analysis software and attach the report directly to the proposal.

For the installer-side workflow, see our page for /for-solar-installers. It shows how design, simulation, and proposals connect for teams running multiple C&I bids at once. The teams that win C&I work are usually the ones that submit bankable documentation first, not the ones that quote lowest.

Generation guarantees raise the stakes

C&I contracts routinely include generation guarantees with penalty clauses. A compliance failure that delays commissioning can start the penalty clock before the plant exports a single unit. We never sign a guarantee without a DISCOM timeline buffer of at least 30 days built into the schedule.

How to Start and Scale a Solar EPC Business in India

Registration: the 7-step setup

1. Incorporate the entity — proprietorship, partnership, LLP, or private limited — and get PAN and TAN.
2. Register for GST. It is mandatory above the turnover threshold and practically required for B2B work.
3. Get Udyam (MSME) registration for priority-sector lending and tender benefits.
4. Obtain an electrical contractor license from your state licensing board. The license class depends on voltage level and project size.
5. Register as a vendor on the PM Surya Ghar portal through your DISCOM if you plan to serve residential customers.
6. Buy insurance: workmen compensation for crews and third-party liability for sites.
7. Set up a business bank account, accounting, and a working capital line. Subsidy projects run 30–60 day receivable cycles.

Build a certified team

You need a licensed electrical supervisor, site engineers, and trained installers. Training from the National Institute of Solar Energy or the Skill Council for Green Jobs — the Suryamitra program — adds credibility in tenders. Certification also reduces rework, which is where young EPCs lose margin.

Standardize the compliance pack

Scaling is a documentation problem before it is a sales problem. Build 1 standard pack per state: single-line diagram, ALMM-matched BOM, structural note, generation estimate, and customer agreements. Every project then leaves the office compliant by default.

We run this in SurgePV. Our solar software covers design, simulation, and proposals in 1 workflow, and Clara AI assists with the design work. The BOM in the proposal matches the BOM in the DISCOM application, which is exactly what inspectors check.

What the economics look like

In our experience, a lean EPC in 1 city installs 20–40 kW a month in year 1 and can reach 100 kW a month by year 2 as DISCOM relationships mature. Gross margins run 12–18% on residential and 8–14% on C&I volume work. The 2 expenses new founders underbudget are working capital and compliance staffing.

Plan for both before you scale sales. A growing pipeline with a frozen approvals desk is a cash-flow crisis, not a growth story.

Sales channels that work in India

Residential volume comes from referrals, society-level campaigns, and the PM Surya Ghar portal’s vendor listings. C&I work comes from energy consultants, chartered accountants advising on depreciation, and direct outreach to factory owners. Budget customer acquisition separately for each channel, because the 2 share almost nothing.

Scaling beyond 1 state

Multi-state operations mean multi-SERC compliance. Keep a playbook per state, vet subcontractor licenses before awarding work, and maintain a compliance calendar for renewals. GST returns, contractor licenses, and portal registrations all lapse on different schedules.

For contrast, look at a mature single-framework market: /blog/community-solar-projects-germany shows a federal, standardized regime where 1 rulebook covers the country. India is layered and state-specific, which is exactly why disciplined compliance is a competitive advantage here rather than a checkbox.

Common Compliance Mistakes That Delay Projects

We see the same 10 errors across states, project sizes, and company ages. None of them are engineering problems.

1. Quoting a module that is not on the current ALMM list. Listings change, and a model valid at signing can lapse before commissioning. Verify at 3 points: quote, procurement, and commissioning.
2. Mixing DCR and non-DCR stock in one BOM. Subsidy projects need fully DCR-compliant modules, and 1 wrong pallet fails inspection.
3. Filing incomplete DISCOM applications. A missing NOC or a single-line diagram without protection details restarts the queue.
4. Name mismatches across the electricity bill, identity proof, and property papers. The subsidy DBT fails when names do not match exactly.
5. Ignoring inverter certification. Anti-islanding compliance is mandatory, and a cheap inverter without certificates cannot be energized.
6. Promising customers a fixed subsidy date. DBT timing depends on inspection and meter supply, so quote ranges, not dates.
7. Missing CEIG or structural certificates on larger systems. Found at inspection, they add weeks.
8. Applying before checking transformer capacity. A feasibility rejection costs you the customer’s trust.
9. Letting licenses and registrations lapse. GST returns, contractor licenses, and portal registrations renew on different schedules.
10. Keeping no audit trail. Save dated ALMM entries, certificates, and acknowledgments for every project.

A concrete example: on a 40 kW school project in Gujarat, a single name mismatch between the trust’s registration papers and the electricity bill held the file for 5 weeks. The fix took 1 affidavit and 2 days — the queue restart cost the other 33.

The pattern matters: 8 of these 10 failures are documentation errors, not engineering errors. Compliance is a process discipline, and process is the 1 thing fully inside your control.

Build the habit into 1 weekly ritual. Every Friday, review open files against the document checklist, confirm each active BOM against the current ALMM list, and chase every approval that has crossed its expected timeline. Thirty minutes of review prevents most of the 10 errors above.

Conclusion

India’s solar rules are layered, but they are not arbitrary. Every requirement in this guide traces back to 1 of 3 goals — grid safety, equipment quality, or subsidy integrity. Once you map your projects to those goals, the paperwork stops being a surprise.

3 action items to take from this guide:

• Audit every active BOM against ALMM List-I this week, and get written cell-provenance confirmation from suppliers before the June 2026 List-II deadline.
• Build a 1-page playbook per state — net metering rules, document packs, and DISCOM timelines — and assign 1 person to track SERC orders monthly.
• Balance your pipeline between subsidy residential and open-market C&I so a single circular cannot stall your revenue.

Use the state table when you quote, the document checklist when you file, and the mistakes list when you train new staff. Each section of this guide maps to 1 stage of a project.

The rest of 2026 will test all 3 disciplines. List-II cell verification will start appearing in DISCOM inspections, not just in MNRE circulars. PM Surya Ghar volumes will keep pushing meter supply and inspection capacity.

Expect 2–3 more states to revise export compensation for larger systems before the year ends. EPCs that built the checklists early will absorb these changes as routine work. The rest will learn them through rejections, and rejections are the most expensive teacher in this market.

India’s buildout toward 280 GW of solar by 2030 will keep every one of these frameworks busy. The EPCs that grow through it will treat compliance as a product — documented, repeatable, and current. None of this requires a legal team; it requires checklists, dated records, and the discipline to verify before you quote.

Bookmark this India solar compliance hub. We verify and update it as MNRE circulars and SERC orders land. If a rule here ever conflicts with a newer SERC order, the order wins — and tell us, so we can fix the page.

Frequently Asked Questions

What is the PM Surya Ghar subsidy in 2026?

PM Surya Ghar: Muft Bijli Yojana provides up to ₹78,000 central subsidy for residential rooftop solar up to 3 kW. The scheme requires MNRE-approved modules from the ALMM list and grid-connected systems with net metering.

The rate structure is ₹30,000 per kW for the first 2 kW and ₹18,000 for the 3rd kW, paid as a direct benefit transfer after commissioning. Systems larger than 3 kW are allowed, but the subsidy stays capped at ₹78,000.

What is ALMM in solar?

ALMM (Approved List of Models and Manufacturers) is MNRE’s list of compliant solar modules. Only ALMM-listed modules qualify for government subsidies and grid-connected schemes in India.

List-I covers modules and has been mandatory for supported projects since 2021. List-II covers cells and applies from June 1, 2026, which extends domestic content rules 1 step up the supply chain.

How do I get net metering approval in India?

Apply to your local DISCOM with a net metering application, system design, module ALMM certification, and consumer documents. The DISCOM conducts a site inspection, approves the application, and installs a bidirectional meter.

For PM Surya Ghar projects, the application runs through the national portal instead. End-to-end approval typically takes 30–90 days, with meter supply the most common bottleneck.

What documents are needed for DISCOM solar approval?

You typically need identity proof, property ownership documents, latest electricity bill, system design, module ALMM certificate, inverter datasheet, and the installer’s certification. Larger systems also need CEIG approval, and some states ask for a structural stability certificate. Submit the complete pack with the initial application — incomplete submissions restart the review queue.

Is net metering available in all Indian states?

Most states offer net metering or net billing, but rules vary. Maharashtra, Gujarat, Karnataka, and Delhi have established net metering frameworks. Some states have caps on system size or export limits.

Delhi also allows virtual and group net metering for shared buildings. Always check the current SERC order before quoting export economics, because size caps and compensation rates change with tariff revisions.

What is the process to start a solar EPC business in India?

Register your business, obtain GST registration, apply for electrical contractor licenses in your state, build a certified team, source ALMM-compliant modules, and register with the PM Surya Ghar portal if serving residential customers. Add Udyam registration for MSME benefits, and insure crews and sites from day 1. Plan working capital for 30–60 day receivable cycles on subsidy projects.