Commercial Solar in Telangana: Your Complete Guide to 40% Depreciation Benefits and HT Net Metering ROI

Commercial solar in Telangana follows different calculations than residential rooftop solar. Industrial and commercial consumers can size systems up to 80% of their sanctioned load, while residential and government connections can reach 100%. Factory owners often overlook this difference and the 40% accelerated depreciation benefit under Section 32, which can result in lost tax savings. This piece covers HT net metering rules, CEIG approval, CAPEX versus RESCO ownership, and a realistic way to calculate your Hyderabad facility's commercial rooftop solar payback period.

Start With Your Factory’s Load and Solar Potential

Pull out twelve months of your HT bills and identify what is driving your costs before calling installers or comparing quotes. Factories rarely struggle with solar calculations because the technology is complex. They struggle because they size systems around a rough consumption average instead of the actual cost structure shown on the bill.

Read your HT bill: energy rates, demand charges and daytime use

Your HT bill provides more detail than a typical LT bill. It separately lists contract demand, maximum demand, energy charges, demand charges, and power factor penalties. Billed maximum demand for an HT connection is the highest of three values: the highest recorded demand excluding Slot A, 75% of the highest demand during the previous 11 months, or 60% of contract demand.

Time-of-day structures add another consideration. One DISCOM's TOD tariff, to name just one example, applies no additional charge between 6 AM-9 AM and noon-6 PM, Rs 0.80/unit from 9 AM-noon, Rs 1.10/unit from 6 PM-10 PM, and a negative Rs 1.50/unit rebate between 10 PM-6 AM. Solar offsets costs only during daylight tariff slots, so you need to know when your plant generates power relative to these windows, not just how much it generates.

Some tariff structures also reward a high load factor. Consumers in HT-I, HT-II, or HT-IX categories can receive a 0.75% rebate on energy charges for every percentage point their load factor rises from 75% to 85%. The rebate rises to 1% per point above 85% and is capped at 15% of energy charges. Rooftop solar reduces energy charges but does not eliminate demand charges, fixed charges, or power factor penalties. Collect your sanctioned load, contract demand, phase details, and separate energy, demand, fixed, and adjustment charges before sizing a system. Include seasonal demand peaks as well.

Match solar output to shifts, weekends and seasonal demand

A rooftop array generates almost no power before 9 AM or after 4 PM, and it produces less electricity in December than in May. A distribution center case study recorded average daily solar generation of 58.1 kWh against average daily consumption of 362.9 kWh. Generation stayed 83.5% below consumption over the year, fell to 89% below consumption in December, and reached only 74.4% below consumption in May. Consumption exceeded solar generation by about four times during spring and summer, then by roughly seven times during autumn and winter at that facility. Power shortfalls still occurred at night on sunny days, even when total daily generation exceeded total daily consumption.

Map your plant's expected output against actual shift timing instead of relying only on an annual kWh figure. A two-shift factory operating from 6 AM to 10 PM captures nowhere near the solar value of a single day-shift operation. Weekend shutdowns also matter. A plant that remains idle on Sundays exports surplus power that it cannot use for self-consumption, so check how your DISCOM settles surplus before you finalize capacity.

Check roof strength, shade and usable space

A proper site assessment examines usable rooftop area, roof condition, and structural capacity. It should also assess shadow patterns, orientation, electrical infrastructure, water tanks, other obstacles, and maintenance access rather than only square footage. A good assessment should provide five figures: recommended capacity; estimated annual generation; specific generation in kWh/kWp/year; estimated electricity value; and estimated generation losses from shading.

Shading losses add up quickly. An illustrative 5 kW system that generates 7,500 units a year loses 375 units with a 5% shading loss, worth around Rs 3,000/year at Rs 8/unit. A 20% loss costs 1,500 units, or around Rs 12,000/year. More panels do not automatically deliver more savings. Capacity should match consumption and export arrangements, not only available roof area.

Structural checks matter more with older industrial sheds. Legacy buildings often lack complete structural documentation, and roof conditions can vary between sections of the same facility. Load-bearing capacity determines how much solar equipment the roof can support. Heat also affects performance. Panel efficiency drops 0.3% to 0.4% per 1°C rise above 25°C in cell temperature, while surface temperatures can reach 60-70°C on a 40°C afternoon. Elevated mounting allows airflow below the panels, which improves generation and extends system life.

Check Telangana’s HT Solar Net Metering Rules

Telangana's net metering rulebook has changed, so make sure you're using the right version. The TGERC (Rooftop Solar PV Grid Interactive Systems) Regulation No. 1 of 2025 replaced the earlier 2016 Regulation No. 6 and took effect on November 15, 2025. Ask your consultant to recheck the framework before sizing your factory's system if they still refer to the old rules.

Confirm current TGSPDCL or TGNPDCL rules for your connection

Your distribution licensee is TGSPDCL in the southern region or TGNPDCL in the north. Both follow the same statewide regulation, but each DISCOM has its own forms and application portal. For HT consumers, the Divisional Engineer (Operations) responsible for your premises is the nodal contact for the process. Find out which office manages your connection and get its current checklist. This can save weeks of back-and-forth when you are ready to apply.

Check solar capacity limits against sanctioned load and contract demand

Industrial, commercial, and other consumers can install a rooftop system up to 80% of sanctioned load or contracted demand under Net Metering or Gross Metering. Group Net Metering and Virtual Net Metering allow up to 80% of the combined contracted demand of the parent connection and participating connections. This matters when your plant has several metered sections under one company.

The minimum system size is 1 kWp for Net Metering and Gross Metering. Group and Virtual arrangements require at least 10 kWp. New Net Metering applicants are capped at 500 kWp, but prosumers who exceeded that limit before the rule change can keep their existing benefit. Consumers with pending arrears cannot use any of these four arrangements.

Understand transformer and feeder capacity checks

Your sanctioned load is not the only limit to consider. The transformer or feeder serving your premises also has an absorption limit. Cumulative solar capacity on an LT transformer cannot exceed 50% of its rated capacity. HT solar capacity also has a 50% cap on an 11 kV or 33 kV feeder, based on the feeder's maximum permitted load or the connected substation/PTR capacity.

TGNPDCL's earlier guidance set fixed limits of 1.125 MW for 11 kV feeders and 4.5 MW for 33 kV feeders. Capacity can exceed 50% only after a detailed load study and approval from the Chief General Manager (Commercial). DISCOMs must publish transformer-wise and feeder-wise available capacity on their websites and update it every quarter, so you can check available headroom before applying.

The 2025 rules allow up to 15 working days for a feasibility assessment, compared with the earlier 21-day period. The feasibility letter remains valid for four months and can be extended to 10 months. Your application will be queued by seniority if capacity is unavailable and reviewed again when space opens up.

Compare self-use sizing, surplus exports and zero-export systems

Telangana now recognizes four arrangements. Your choice affects how your factory uses and earns from solar:

• Net Metering: Your solar generation offsets your consumption first. Any surplus goes to the grid and adjusts against future bills.

• Gross Metering: The DISCOM buys all solar generation at a discovered tariff and bills your full electricity consumption separately at the regular retail rate.

• Group Net Metering / Virtual Net Metering: One parent connection can share solar benefits with multiple participating connections. This works well for sites with several metered loads under one owner.

• Island mode: This zero-export arrangement supplies power only for self-consumption and does not feed electricity into the grid.

These arrangements are mutually exclusive. A prosumer using net metering cannot use gross or virtual net metering, and the same applies in reverse. Factories that also use Open Access cannot have combined OA and solar capacity above their contracted maximum demand.

Apply for Approval and Commission Your Solar System

Once you've settled on the system size and chosen an arrangement, paperwork is the next hurdle. Many commercial projects stall because no one keeps track of the required documents.

Prepare the application, documents and current fee payment

Download the Annexure I application from the DISCOM website and submit it at your local Consumer Service Center or Integrated Consumer Service Center. Consumers under TGNPDCL can also submit it at the relevant division office. HT consumers pay an application fee of Rs 15,000 per connection, while LT consumers pay Rs 2,500. This fee applies to 11 kV and 33 kV connections, or to systems with installed capacity above 56 kW. Submit the following with the form:

• A copy of your latest electricity bill

• A bank draft for the applicable fee, payable to the DISCOM

• Two self-addressed Rs 5 stamped envelopes

• A copy of your bank passbook if you want the settlement credited to your account

You can also submit the application through the DISCOM portal and pay digitally. Either option provides a unique registration number that you will use throughout the process.

Complete the DISCOM feasibility review and connection agreement

The Divisional Engineer (Operations) responsible for HT applications must confirm whether your documents are complete within seven working days. The engineer will also identify any missing documents. If the application has deficiencies, you will receive a cost estimate to correct them. Pay this amount within 15 days, or DISCOM will cancel the application and forfeit the fee. After DISCOM confirms feasibility, execute the net metering connection agreement within 15 days of receiving technical feasibility approval.

Plan CEIG approval for solar in Telangana where required

Your system size determines whether you need a Chief Electrical Inspector to Government (CEIG) certificate. Installations above 75 kW require insurance, CEIG testing, and certification. Consumers can self-certify systems up to 75 kW for safety and protection compliance. Most mid-sized factories with commercial rooftop solar in Telangana exceed 75 kW, so allow enough time to complete this requirement.

Install approved equipment with earthing and anti-islanding protection

Approved equipment needs separate grounding and anti-islanding protection that meets IEC 61727 and IEC 62116 standards. The system must trip when voltage rises above 110% or falls below 80%, with clearance within two seconds. It must also trip when frequency exceeds 50.3 Hz or falls below 49.2 Hz, with clearance within 0.2 seconds. The system must stop energizing within two seconds if an unintended island forms. It can reconnect only after voltage and frequency remain stable for sixty seconds. DC injection cannot exceed 0.5% of rated output. Paralleling devices must withstand 220% of nominal voltage, and interconnection voltage fluctuation cannot exceed ±5%.

Complete meter testing, inspection and grid synchronization

Submit a work completion report to trigger the inspection. The Divisional Engineer must complete it within 10 working days. Approval is automatically deemed granted if the engineer does not respond within that period. DISCOM then installs a bi-directional meter that matches your sanctioned load. HT systems of 56 kW and above need a meter with 0.2 class accuracy, CT functionality, and BIS certification. Connections under the Time-of-Day tariff need a meter that records ToD consumption and generation separately. After synchronization, officials sign the Annexure V(a) synchronization report and send it to the Circle Office for billing.

Understand How HT Net Metering Affects Your Bill

Your HT bill takes on a new format after synchronization. Understanding the layout helps you see whether net metering reduces your costs or simply adds line items that are hard to follow.

Read import, export and carried-forward units on your bill

Each billing period, your bill must show four separate figures: units exported, units imported, net units billed for payment, and net units carried forward to the next cycle. If your factory exports more electricity than it imports during a month, the excess carries forward as credited units. You will still receive a monthly minimum bill instead of a zero bill. If imports exceed exports, the DISCOM invoices you for net consumption after adjusting any credits you have accumulated. Shortfalls do not receive a deemed generation payment, and your billing period and due date remain the same as before you installed solar.

Check current credit periods and surplus settlement rates

Unadjusted net credited units cannot carry forward indefinitely. TGSPDCL and TGNPDCL settle these credits twice a year, in June and December, at the average power-purchase cost that the Commission approves for that year or at a separately notified rate. The settlement amount is adjusted against your next bill or deposited into the bank account you provided during the application process. Each new settlement period resets the cumulative carried-forward balance to zero, so unused surplus cannot continue indefinitely.

TSERC's pooled cost rate for FY2024-25 was roughly ₹3.45 to ₹3.75 per unit. Many IT and pharmaceutical consumers pay ₹8 to ₹12 per unit under their HT tariff. This gap shows why self-consumption, rather than exports, drives most ROI calculations for commercial solar in Telangana. Canceling your net metering agreement requires one month's notice. Any unused credits are paid at Rs 0.50 per kWh or at a rate that the Commission notifies later.

Account for time-of-day rules and kVAh billing where applicable

Connections under a Time-of-Day tariff must use a net meter that records ToD consumption and generation in separate blocks. Solar injected during a given time slot offsets consumption in that same slot first, whether it is peak or off-peak. Excess injection beyond your consumption in another slot is treated as off-peak generation. If your tariff uses kVAh billing instead of kWh billing, the system measures both net drawl and net injection in kVAh.

Identify demand, fixed and minimum charges that remain payable

Net metering reduces energy charges, but it does not eliminate every bill component. Your rooftop system is exempt from Transmission Charge, Transmission Loss, Wheeling Charge, Wheeling Loss, Cross Subsidy Surcharge and Additional Surcharge. A typical mid-size HT industrial bill allocates about 38% to energy charges, around 30% to demand charges, roughly 16% to fuel cost adjustment, and close to 12% to electricity duty. Power factor and meter rent account for the remaining amount. A power factor below 0.90 triggers a 1-3% surcharge, while a power factor above 0.95 earns a 1-2% rebate. Fuel cost adjustment also tends to range from ₹0.28 to ₹0.55 per unit. These charges remain after your panels go live, so include them in your ROI model instead of assuming solar clears the entire bill.

How the 40% Solar Depreciation Benefit Works

Net metering credits tell only half the savings story. The other half appears in your tax return, where Section 32 of the Income Tax Act allows profitable businesses to write off a significant part of their solar investment in the first year.

Check asset eligibility under Section 32 of the Income Tax Act

The Income Tax Department's depreciation schedules cover several renewable-energy devices, such as solar systems and related equipment. Rates and conditions vary by asset type and financial year. Confirm with your tax advisor whether the components in your installation qualify under the eligible category before you assume the entire array qualifies.

Apply 40% depreciation to eligible written-down value, not as a cash rebate

This benefit does not come as a cheque from the tax department. Your business can claim up to 40% accelerated depreciation in the first year under a CAPEX purchase, followed by normal depreciation in later years. The deduction reduces taxable income rather than providing cash directly. A solar loan does not affect ownership, so your business still claims depreciation and receives the full electricity savings.

Check the 180-day rule for first-year depreciation

Timing determines how much you can claim in the first year. Commission the system and put it to use before the midpoint of your financial year to claim the full first-year rate. A shorter period of use usually limits the claim to half the eligible rate, and you can carry the remaining amount into the next year.

Calculate tax savings using your applicable tax rate and taxable income

Depreciation provides value only when your business has an actual tax liability. Since it reduces taxable profit, a business without sufficient taxable income cannot benefit from the deduction. A consistently profitable company can turn much of its solar capital cost into a first-year tax benefit. This reduces taxable income and can shorten the project's effective payback period.

Compare depreciation eligibility under CAPEX and RESCO ownership

Ownership determines who can claim this benefit. Your business owns the system from commissioning under CAPEX and can claim depreciation directly. The developer owns the asset under RESCO or OPEX and claims the depreciation instead. Charitable trusts, societies, schools, trust-run hospitals, loss-making businesses, newly incorporated entities, and organizations under exemption regimes often cannot use this benefit because they have no taxable income to offset it. Consistently profitable companies with tax liability and available capital benefit the most. Profitable MSMEs that own their premises and use a solar loan, as well as large commercial and industrial consumers with high daytime loads, often benefit most from CAPEX because of this depreciation advantage.

Keep invoices, asset records and proof of the put-to-use date

Your accountant will need supporting documents when filing the claim, including purchase invoices, asset-capitalisation entries, and dated commissioning proof. A missing put-to-use date makes it harder to defend the claim during an assessment. Keep these records with your CEIG certificate and synchronization report from day one.

Calculate Commercial Rooftop Solar ROI in Telangana

Run the numbers before signing an EPC contract, since a reliable payback figure needs each cost and savings line factored in separately.

Build the full project cost, including HT equipment and approval costs

Commercial rooftop projects in India typically cost ₹4.5 to ₹6 crore per MWp, depending on site conditions. Include HT metering gear and costs such as CEIG fees and feasibility studies, not just panels and inverters.

Estimate annual savings from self-use and export credits separately

Value self-consumed units at your retail tariff of ₹8.50 to ₹12.00 per unit. Value exported surplus separately at the settlement rate covered earlier, since combining the two can overstate your returns.

Include maintenance, insurance, output loss and inverter replacement

Set aside 0.6% to 1.5% of project cost each year for O&M. Factor in panel degradation of about 0.4% a year and a mid-life inverter replacement.

Model a Hyderabad commercial solar payback example with stated assumptions

A 100 kW plant that produces about 14,000 units a month at ₹9.50 per unit saves roughly ₹1.33 lakh monthly, or ₹16 lakh annually. It can pay back its cost in 2.8 to 3.2 years.

Compare pre-tax and after-tax cash flow without double-counting benefits

A ₹50 lakh investment with 40% depreciation creates ₹20 lakh in write-offs and saves ₹5 to ₹6 lakh in tax, depending on the tax bracket. Add this benefit to energy savings rather than counting it twice.

Test lower export credits, shutdowns and future load growth

Stress-test lower generation and export credits, along with shutdown days and tariff escalation, before committing. A proper feasibility and financial assessment that covers structural load, HT bills and the exact tax shield is more reliable than guesswork.

Conclusion

Commercial solar in Telangana rewards factories that prepare first. System sizing against 80% of sanctioned load and a proper review of HT bills should happen before any EPC discussion, along with confirmation that the transformer has sufficient headroom.

Proper CEIG approval and meter testing, followed by synchronization, keep commissioning on schedule instead of delaying the project in paperwork. The financial case also matters. The 40% depreciation available under Section 32 complements net-metering credits rather than replacing them, provided the business has enough taxable income to claim the deduction.

We recommend a full feasibility study before signing any contract. The study should assess structural load, tariff slabs, and the available tax shield. This work to be done separates a 2.8-year payback from a stalled system that fails to perform as expected.