TGERC ₹0.82/kWh Additional Surcharge: Open Access vs Solar
TGERC ₹0.82/kWh Additional Surcharge Order: Why Telangana Factories Are Pivoting from Open Access to On-Site Captive Solar
Telangana’s ₹0.82/kWh additional surcharge makes electricity procurement more expensive for applicable open access consumers from November 1, 2026, to March 31, 2027—not throughout FY 2026–27. However, captive and qualifying green energy exemptions mean factories should establish liability before assuming their solar imports become costlier. This article explains the order, compares procurement economics, and examines on-site solar options without treating a proposed engineering arrangement as automatic regulatory permission.
What does the TGERC open access order for FY 2026–27 change?
The TGERC additional surcharge open access Telangana order sets ₹0.82/kWh for applicable transactions during November 2026–March 2027. TGERC lists the H2 determination under TGERC Suo Moto Order O.P. Nos. 28 & 29 of 2026. Crucially, the rate should not be inserted into every renewable electricity quotation without checking the transaction’s classification and exemptions.
For procurement teams reviewing Telangana open access charges 2026, the distinction between an approved rate and a charge actually payable is fundamental. A factory purchasing conventional third-party electricity, a qualifying green energy consumer paying demand charges, and a verified captive user can face different treatment. Telangana’s surcharge orders have expressly recognised captive and green energy exceptions.
The financial exposure is straightforward once chargeability is established:
100,000 chargeable scheduled kWh: ₹82,000 in additional surcharge.
1 million chargeable scheduled kWh: ₹8.2 lakh.
Exempt transactions: do not add ₹0.82 merely because electricity arrives through open access.
These are arithmetic illustrations, not forecasts of a particular factory’s bill. Use the order’s chargeable energy basis rather than substituting total factory consumption.
The legal rationale is stranded capacity recovery
Section 42(4) of the Electricity Act, 2003, provides the legal basis for an additional surcharge: recovering a distribution licensee’s fixed costs arising from its obligation to supply when consumers purchase electricity elsewhere. For TGSPDCL and TGNPDCL, the concern is that high-tension consumers sourcing power off-site through open access can leave contracted generating capacity financially stranded under established appellate tribunal rulings.
Imagine a factory reducing DISCOM energy purchases while retaining its grid connection. The utility may still owe fixed payments under long-term power purchase agreements. Additional surcharge addresses eligible unrecovered obligations; it is not simply another name for transmission charges, wheeling charges, or cross-subsidy surcharge.
The calculation also considers demand-charge recovery. Reporting on the H2 order identifies ₹77.07 crore in net stranded fixed charges after adjustment and 936.26 million units of chargeable open access sales. Consequently, a sound procurement model separates fixed-cost recovery from network-use charges instead of combining everything into an unexplained surcharge allowance.
Does captive solar avoid the additional surcharge?
Qualifying captive consumption receives different treatment from ordinary third-party purchases. Telangana’s orders exclude open access electricity wheeled from consumers’ own captive plants, while the Supreme Court has distinguished captive users’ statutory rights from ordinary consumers requiring permission to procure elsewhere. The captive solar exemption from additional surcharge therefore depends on a valid captive arrangement—not merely a contract labelled “captive,” as affirmed by Supreme Court precedents governing Section 9 of the Electricity Act.
Group-captive projects require particular attention. TGERC’s verification procedure examines ownership and consumption compliance, with information submitted through the distribution licensee. Before assigning exemption benefits, obtain the project’s compliance methodology, reporting responsibilities, and contractual protection if captive status is lost, in accordance with the TGERC Captive Verification Guidelines.
There is another important qualification: Telangana has exempted green energy open access consumers paying fixed or demand charges. A renewable project is therefore not necessarily exposed to ₹0.82/kWh, even when it is third-party rather than captive. Verify the operative H2 order and billing treatment for the specific connection before sanctioning an investment based on surcharge avoidance.
Comparing landed costs across four procurement models
The landed cost of open access solar in Telangana is not the generator’s headline PPA tariff. For a complete mathematical comparison of transmission losses, wheeling charges, and banking fees, evaluate our guide on open access vs rooftop solar in Telangana and landed costs. It includes the delivered-energy effect of network losses, applicable network and scheduling charges, banking or settlement costs, and any payable surcharges. TGERC publishes separate retail, wheeling, transmission, and SLDC determinations, so these components should remain visible in the comparison.
For a TGSPDCL HT industrial solar tariff assessment, the FY 2026–27 HT-I(A) Industry General schedule lists base energy charges of ₹7.65 at 11 kV, ₹7.15 at 33 kV, and ₹6.65 at 132 kV and above, plus ₹500/kVA/month demand charges, as outlined in the TGSPDCL HT Retail Supply Tariff Schedule. Normalise the actual billing unit and power factor before comparing these with solar ₹/kWh offers. To understand why daytime solar displacement can distort grid-side power factor without dynamic compensation, review our analysis on the kVAh billing reality and solar power factor correction.
The table uses verified regulated values and calculation formulas rather than inventing universal solar prices. P means the project’s generation price, L the applicable network-loss fraction, and R the rooftop cost per usable, self-consumed kWh.
Procurement model | Comparable cost calculation | Surcharges, losses, and remaining liabilities |
|---|---|---|
TGSPDCL HT-1 Grid | Applicable ₹7.65/₹7.15/₹6.65 base energy rate, normalized to kWh, plus allocated demand charges and adjustments | Include time-of-day treatment, applicable fuel adjustments, duty, and other billed items |
Third-Party Open Access Solar | P ÷ (1 − L), plus network, scheduling, banking/settlement costs, applicable cross-subsidy surcharge and additional surcharge | Add ₹0.82 per chargeable scheduled kWh only when liable; convert consistently to delivered-kWh cost |
Group-Captive | P ÷ (1 − L), plus applicable network, scheduling, banking/settlement and compliance costs | Model surcharge exemptions only with verified eligibility; network losses remain relevant |
On-Site Captive Rooftop Solar | R, including financing, maintenance, replacements, internal losses and curtailed generation | No off-site wheeling leg for self-consumed output; retained grid charges require separate assessment |
To compare the on-site CAPEX model against third-party PPA options, consult our unbundled commercial solar cost per kW and BOQ breakdown covering HT switchgear, protection, and tier-1 module pricing.The grid values and adjustments come from TGERC’s tariff schedule; exemption assumptions require separate regulatory verification. These formulas are budgeting tools, not DISCOM tariff quotations.
Two details can change the result. First, the schedule provides a ₹0.50/unit reduction from 10 a.m. to 6 p.m. for applicable categories, so solar should be valued against the grid electricity it actually displaces. Second, rooftop production does not automatically eliminate contracted demand charges. Comparing a solar energy price with an all-in grid average can exaggerate savings.
For the green energy open access Telangana landed tariff, request separate “exemption confirmed” and “exemption unavailable” cases. This makes regulatory exposure visible without presuming either outcome.
On-site solar sizing must respect the net-metering ceiling
TGERC Regulation 1 of 2025, published on November 15, 2025, limits new net-metering installations to 500 kWp, including eligible commercial consumers. Existing prosumers already enjoying net metering above 500 kWp are grandfathered. Industrial and commercial installations under the regulation also face an 80% sanctioned-load or contracted-demand capacity condition under TGERC Regulation 1 of 2025 (Rooftop Solar Grid Connectivity).
The ceiling concerns the permitted metering arrangement; it should not be presented as unrestricted permission to install additional parallel generation outside that arrangement. For a commercial rooftop solar vs open access Telangana comparison, confirm the sanctioned capacity, connection topology, and export entitlement before calculating revenue from surplus generation. The regulation requires formal applications and DISCOM approval for its metering arrangements.
A conditional hybrid design for loads above 1 MW
For an HT facility with load greater than 1 MW, an engineering proposal worth evaluating is a 500 kWp net-metered system paired with an adjacent behind-the-meter zero-export solar system. However, Regulation 1 of 2025 does not itself establish blanket approval for this combination. Submit the complete single-line diagram and seek written acceptance before procurement.
The zero-export branch would use a power controller to reduce inverter output as consumption falls, backed by an ANSI 32R reverse-power relay that trips the generation breaker during reverse flow. For technical schematics on coordinating fast curtailment during grid transitions, see our engineering guide on smart solar-DG synchronisation controllers with ANSI 32R reverse-power protection. A relay is protective backup, not a substitute for continuous export control. Reverse-power protection and inverter-based export limiting are established engineering approaches, but their settings must follow the local connection approval.
A credible design review should address:
Metering boundaries: distinguish authorised net-metered exports from the non-export branch; a shared connection needs coordinated controls.
Sudden load rejection: test what happens when a large motor or production line stops while solar output remains high.
Fail-safe operation: establish safe behaviour after communication, controller, or measurement failure.
Commissioning evidence: document relay direction, breaker operation, response tests, and accepted export settings.
These checks help maximise self-consumption while reducing unauthorised injection risk and potential contractual or regulatory penalties. Neither a 32R relay nor a “zero-export” equipment label guarantees penalty-free operation.
A practical procurement decision for Telangana factories
The open access vs captive rooftop solar Telangana decision should start with the factory’s operating profile, not the surcharge headline. Ask bidders to compare the same production schedule, demand assumptions, and delivered-energy denominator. Otherwise, an apparently cheaper proposal may simply exclude costs included by another bidder.
Use a common evaluation brief:
Establish liability. Obtain the applicable order, transaction classification, and written exemption analysis.
Match generation to demand. Compare interval consumption with expected solar output, including holidays and shutdowns.
Price usable energy. Include curtailment, network losses, replacement provisions, and financing—not just installed capacity.
Retain unavoidable costs. Keep residual grid energy and demand charges visible in every scenario, and ensure the grid connection study and single-line diagram approvals are executed by vetting an accountable Class-A turnkey solar EPC licensed to carry out HT substation modifications in Telangana..
Stress-test the contract. Identify who bears changes in law, loss of captive status, shortfalls, and settlement costs.
A daytime factory with suitable roof space can investigate self-consumption first; a roof-constrained facility should retain off-site options in its shortlist. These are decision scenarios, not evidence that all Telangana factories are already switching. The Telangana solar energy transition is better understood as a choice between procurement structures than a simple rejection of open access.
One further detail matters for solar energy in Telangana: Regulation 2 of 2026 amended the 2024 open access framework concerning wheeling-agreement timing and REC entitlement for unutilized banked energy. These provisions affect administration and value allocation, but do not independently establish additional-surcharge liability. Telangana solar power contracts should reflect the updated rules notified under the amended open-access framework.
The takeaway is practical: establish exemptions first, compare delivered costs second, and approve the electrical design before committing capital. On-site solar deserves serious evaluation, but a defensible business case must stand on usable generation and compliant operation—not an assumed ₹0.82 saving on every unit. Explore our turnkey commercial and industrial solar engineering solutions to conduct a detailed tariff audit, assess behind-the-meter sizing, and evaluate the financial viability of on-site captive solar for your factory.
Frequently asked questions
1. What dates does Telangana’s ₹0.82/kWh additional surcharge cover?
The reported H2 FY 2026–27 rate applies to eligible transactions from November 1, 2026, through March 31, 2027. It should not be applied retrospectively across the entire financial year.
2. Is third-party green open access solar automatically subject to additional surcharge?
No. Telangana’s orders recognize an exemption for green energy open access consumers paying fixed or demand charges. Confirm the operative order and connection-specific eligibility before adding the surcharge.
3. What proves eligibility for captive solar exemptions?
Captive status requires compliance with applicable ownership and consumption requirements. TGERC has a verification procedure; a developer’s marketing description or captive-labelled PPA alone is insufficient evidence.
4. Can a new commercial rooftop system exceed 500 kWp under net metering?
Regulation 1 of 2025 sets a 500 kWp ceiling for new net-metering arrangements. Existing eligible installations above that capacity are grandfathered; additional generation requires assessment under an approved arrangement.
5. Which tariff should rooftop solar savings replace in the financial model?
Use the avoidable grid energy cost during actual solar-generation hours, with applicable time-of-day treatment. Do not assume rooftop output also removes retained demand charges or every other grid bill component.
