07-04-2026
A factory owner in Tamil Nadu, a hotel chain in Delhi, and a warehouse operator in Gujarat each navigate entirely different tariff slabs, billing formats, surcharges, and subsidy regimes — even though they all plug into the same national grid. This fragmentation isn't a bug. It's baked into India's constitutional design, political incentives, and a decades-old tug-of-war between central ambition and state autonomy.
India's power sector is governed by the Electricity Act of 2003, a landmark law that replaced three colonial and post-independence-era statutes. The Act broke apart the old State Electricity Boards — monolithic government agencies that generated, transmitted, and sold power — into separate entities for each function. Generation was "delicensed," meaning anyone could build a power plant without a government license. Trading was recognised as a standalone business. And independent regulatory commissions were mandated at both the central and state level to set tariffs and enforce standards.
Here's how the structure works in practice:
The critical point: there is no hierarchical relationship between CERC and the state commissions. The central body cannot override what a state regulator decides about local tariffs.
Electricity sits in Entry 38 of the Concurrent List (Schedule VII of the Indian Constitution). In India's federal system, some subjects belong exclusively to the central government (defence, foreign affairs), some to states (police, land), and some are "concurrent" — both levels can legislate. Electricity is concurrent. Taxation on electricity sale and consumption, meanwhile, sits in the State List, giving states exclusive control over that revenue.
What does this mean day to day? The central government writes the big rules — the Electricity Act, the National Tariff Policy, renewable energy targets. But states retain enormous freedom in how they implement those rules. They decide retail prices. They decide who gets subsidised power. They decide whether their DISCOMs are well-run or treated as arms of the state government. And when a central policy clashes with a state's political priorities, the state usually wins in practice, even if it loses on paper.
The most visible consequence of this structure is wildly different electricity pricing across India. Industrial tariffs range from roughly ₹7–8 per unit in states like Gujarat and Maharashtra to over ₹9 per unit in Tamil Nadu. Domestic rates in Delhi start at ₹3 per unit with the first 200 units free; in Maharashtra, slabs climb as high as ₹12.83 per unit.
But the headline rate is just the beginning. Every electricity bill in India is a layer cake of charges, and the layers differ everywhere:
The biggest pricing distortion comes from cross-subsidies. Commercial and industrial consumers effectively pay above-cost tariffs so that farmers and low-income households can pay below-cost rates. Agricultural consumers pay roughly 55% less than the actual cost of supplying them power; industrial users pay about 12% more. States like Punjab, Telangana, Tamil Nadu, and Andhra Pradesh provide free electricity to farmers — politically popular, financially devastating. Punjab alone has spent over ₹1.34 lakh crore on free farm power since the programme's inception.
The National Tariff Policy caps cross-subsidies at ±20% of the average cost of supply. No state in India currently complies with this limit.
For a company operating factories, offices, or warehouses across multiple states, this fragmentation creates an operational headache that's hard to overstate. A business present in eight major states could easily deal with 15 to 20 different DISCOMs, each with its own web portal, login credentials, billing cycle, and bill format.
Consider the differences:
There is no unified national portal for viewing or paying electricity bills. No standardised data format. No common API. A company trying to conduct an energy audit across its national portfolio must manually collect, normalise, and reconcile data from dozens of sources — each using different terminology for identical charges.
Open access — the provision allowing large consumers to buy power directly from generators or renewable projects instead of from the local DISCOM — introduces further complexity. Each state sets its own cross-subsidy surcharge, wheeling charge, and banking rules (how surplus solar generation is credited). The economics of the same solar project can look completely different depending on which state the factory is in.
The Revamped Distribution Sector Scheme (RDSS), launched in 2021 with a budget of over ₹3 lakh crore, aims to modernise distribution infrastructure, install smart meters, and push AT&C losses (a combined measure of power theft, billing inefficiency, and collection failure) down to 12–15%. AT&C losses fell to about 15% in FY25 from over 22% a decade earlier, and DISCOMs collectively posted their first profit in over a decade — ₹2,701 crore — though they still sit on accumulated losses exceeding ₹6.4 lakh crore.
India's smart metering programme — targeting 250 million prepaid meters, the world's largest rollout — is the most tangible reform effort. Smart meters generate standardised, real-time consumption data that could eventually enable uniform billing, accurate ToD pricing, and automated energy accounting. But as of late 2025, only about 4.76 crore meters had been installed — under 20% of the target — and just 1.9% were operating in prepaid mode.
The Green Energy Open Access Rules of 2022 lowered the threshold for buying renewable power from 1 megawatt to just 100 kilowatts, opening the door for smaller businesses. The commercial and industrial open-access market has grown at a 46% annual rate, reaching 18.7 GW by FY2024.
The Draft Electricity (Amendment) Bill, 2025 proposes eliminating cross-subsidies for manufacturers within five years and introducing competition in distribution by allowing multiple companies to sell power in the same area. However, power-sector unions staged protests in early 2026, calling it backdoor privatisation, and the bill remains under revision.
Every reform effort runs into the same set of obstacles:
In the absence of regulatory standardisation, technology is filling gaps. Enterprise energy management platforms allow multi-site businesses to aggregate consumption data across DISCOMs, normalise different billing formats, and perform tariff analytics from a single dashboard. The Indian Energy Exchange connects over 8,100 stakeholders across all states, offering a centralised marketplace for power procurement. Smart meters, as they scale, will create a common data infrastructure that makes the case for harmonised billing formats and data APIs much harder for states to resist.
India's electricity fragmentation reflects genuine diversity in geography, development levels, political priorities, and energy needs across 28 states. Full standardisation may never arrive — and perhaps shouldn't. But the current degree of variation imposes real costs: on businesses trying to operate nationally, on DISCOMs struggling to stay solvent, on industrial consumers bearing an outsized cross-subsidy burden, and on a grid trying to integrate hundreds of gigawatts of renewable energy.
The path forward is likely incremental. Smart meters will standardise data even if tariffs remain different. Open access and power exchanges will give consumers more choices. The Amendment Bill, if it passes, could introduce competition that forces DISCOMs to improve. But the deepest challenge is political will — the willingness to price electricity closer to what it costs, to protect consumers through targeted cash transfers instead of blanket tariff subsidies, and to let regulatory commissions do their jobs without interference.
Until that changes, India's power sector will remain what it has always been: a grid that is technically unified but commercially fragmented — one nation, seventy-two electricity systems.
India runs one of the world's largest power grids, yet no two states charge for electricity the same way. A factory owner in Tamil Nadu, a hotel chain in Delhi, and a warehouse operator in Gujarat each navigate entirely different tariff slabs, billing formats, surcharges, and subsidy regimes — even though they all plug into the same national grid. This fragmentation isn't a bug. It's baked into India's constitutional design, political incentives, and a decades-old tug-of-war between central ambition and state autonomy. Understanding why requires a tour through the regulatory plumbing that keeps the lights on — and the political economy that keeps reform at bay.
India's power sector is governed by the Electricity Act of 2003, a landmark law that replaced three colonial and post-independence-era statutes. The Act did something bold: it broke apart the old State Electricity Boards — monolithic government agencies that generated, transmitted, and sold power — into separate entities for each function. Generation was "delicensed," meaning anyone could build a power plant without a government license. Trading was recognized as a standalone business. And independent regulatory commissions were mandated at both the central and state level to set tariffs and enforce standards.
Here's how the structure works in practice. At the national level, the Central Electricity Authority (CEA) sets technical standards, publishes the National Electricity Plan, and advises the government on policy. Think of it as the chief engineer. The Central Electricity Regulatory Commission (CERC) handles inter-state matters — it regulates tariffs for central government power plants, governs the power exchanges where electricity is traded, and manages the rules for electricity flowing across state borders.
Then each state has its own State Electricity Regulatory Commission (SERC). These bodies set the retail tariffs — the prices you and I actually pay. They license the DISCOMs (Distribution Companies) that deliver power to homes, shops, and factories. India has roughly 72 DISCOMs, including 44 state-owned ones, about 10 private companies, and several power departments in smaller states and union territories.
The critical point: there is no hierarchical relationship between CERC and the state commissions. The central body cannot override what a state regulator decides about local tariffs. This brings us to the constitutional root of the problem.
Electricity sits in Entry 38 of the Concurrent List (Schedule VII of the Indian Constitution). In India's federal system, some subjects belong exclusively to the central government (defense, foreign affairs), some to states (police, land), and some are "concurrent" — both levels can legislate. Electricity is concurrent. Taxation on electricity sale and consumption, meanwhile, sits in the State List, giving states exclusive control over that revenue.
What does concurrent mean day to day? The central government writes the big rules — the Electricity Act, the National Tariff Policy, the push for renewable energy targets. But states retain enormous freedom in how they implement those rules. They decide retail prices. They decide who gets subsidized power. They decide whether their DISCOMs are well-run or treated as arms of the state government. And when a central policy clashes with a state's political priorities, the state usually wins in practice, even if it loses on paper.
The most visible consequence of this structure is wildly different electricity pricing across India. Industrial tariffs range from roughly ₹7.38 per unit in Maharashtra (a recent target) to over ₹9 per unit in Tamil Nadu — a 22% spread. Domestic rates in Delhi start at ₹3 per unit with the first 200 units free; in Maharashtra, slabs climb as high as ₹12.83 per unit.
But the headline rate is just the beginning. Every electricity bill in India is a layer cake of charges, and the layers differ everywhere:
Energy charges are what you pay per unit consumed. These vary by consumer category (domestic, commercial, industrial, agricultural) and by consumption slab.
Demand or fixed charges are levied based on your sanctioned load or maximum demand, regardless of how much you actually consume. Gujarat charges among the highest fixed rates per kilovolt-ampere (kVA) in the country; other states emphasize energy charges instead.
Time-of-Day (ToD) pricing means you pay more during peak hours and less when demand is low. While 23 states have some form of ToD tariff, each defines "peak" and "off-peak" differently. In Uttar Pradesh, summer peak hours stretch from 9 AM to 1 AM — sixteen hours. In Delhi, peak is just 6 PM to 10 PM.
Surcharges pile on: fuel adjustment charges (updated quarterly to reflect coal prices), electricity duty (Jharkhand charges 15%), wheeling charges for using the network, and a cross-subsidy surcharge for consumers buying power on the open market.
The biggest distortion comes from cross-subsidies. Commercial and industrial consumers effectively pay above-cost tariffs so that farmers and low-income households can pay below-cost rates. In 2019, cross-subsidies amounted to at least ₹75,000 crore (about $10 billion). Agricultural consumers pay roughly 55% less than the actual cost of supplying them power; industrial users pay about 12% more. States like Punjab, Telangana, Tamil Nadu, and Andhra Pradesh provide free electricity to farmers — politically popular, financially devastating. Punjab alone spends around ₹10,000 crore annually on this.
For a company operating factories, offices, or warehouses across multiple states, this fragmentation creates an operational headache that's hard to overstate. A business present in eight major states could easily deal with 15 to 20 different DISCOMs, each with its own web portal, login credentials, billing cycle, and bill format.
Tamil Nadu's state utility still uses a "White Meter Card" — a manually recorded, bimonthly, paper-based system that doesn't even break down individual charges. Maharashtra issues detailed monthly electronic bills with separate line items for wheeling and fuel adjustment. Delhi's private DISCOMs provide ToD breakdowns. There is no unified national portal for viewing or paying electricity bills. No standardized data format. No common API. A company trying to conduct an energy audit across its national portfolio must manually collect, normalize, and reconcile data from dozens of sources — each using different terminology for identical charges.
Open access — the provision allowing large consumers to buy power directly from generators or renewable projects instead of from the local DISCOM — introduces another layer of complexity. Each state sets its own cross-subsidy surcharge, wheeling charge, and banking rules (how surplus solar generation is credited). Maharashtra recently tightened its rules to limit solar banking to the same time-of-day slot. Karnataka is progressively reducing cross-subsidies. The economics of the same solar project can look completely different depending on which state the factory is in.
The central government has not been passive. The Revamped Distribution Sector Scheme (RDSS), launched in 2021 with a budget of over ₹3 lakh crore, aims to modernize distribution infrastructure, install smart meters, and push AT&C losses (a combined measure of power theft, billing inefficiency, and collection failure) down to 12-15%. Progress has been real but uneven: AT&C losses fell to 15% in FY25 from over 22% a decade earlier, and DISCOMs collectively posted their first profit in over a decade — ₹2,701 crore — though they still sit on accumulated losses exceeding ₹6.4 lakh crore.
India's smart metering program — targeting 250 million prepaid meters, the world's largest rollout — is the most tangible reform effort. Smart meters generate standardized, real-time consumption data that could eventually enable uniform billing, accurate ToD pricing, and automated energy accounting. But as of late 2025, only about 4.76 crore meters had been installed — under 20% of the target. Just 1.9% were operating in prepaid mode.
The Green Energy Open Access Rules of 2022 lowered the threshold for buying renewable power from 1 megawatt to just 100 kilowatts, opening the door for smaller businesses. The commercial and industrial open access market has grown at a 46% annual rate, reaching 18.7 gigawatts by FY2024. And the Draft Electricity Amendment Bill of 2025 proposes eliminating cross-subsidies for manufacturers within five years and introducing competition in distribution by allowing multiple companies to sell power in the same area. But power-sector unions staged protests in March 2026, calling it "backdoor privatization," and the bill remains under revision.
Every reform effort runs into the same set of obstacles. Electricity pricing is one of the most powerful political tools in Indian democracy. Free power to farmers has been an election promise since the 1970s, and no government has successfully reversed it. One-third of Indian states offer free farm power; the rest offer steep subsidies. The political cost of raising agricultural tariffs — or even accurately metering farm consumption — is considered electoral suicide.
State governments guard their control over DISCOMs fiercely. Many treat utilities as instruments of patronage and employment. State regulatory commissions, while nominally independent, often lack true autonomy — their budgets depend on state governments, vacancies go unfilled for years, and tariff orders are influenced by political considerations rather than cost-recovery math. The UDAY scheme of 2015 wrote off ₹4 lakh crore in DISCOM debt, but without structural reform, losses simply re-accumulated.
Cross-subsidies create a vicious cycle. High industrial tariffs push large consumers toward captive power generation or open access, eroding DISCOM revenues and forcing remaining consumers to bear a heavier subsidy burden. The National Tariff Policy caps cross-subsidies at ±20% of the average cost of supply. No state in India currently complies with this limit.
In the absence of regulatory standardization, technology is filling gaps. Enterprise energy management platforms allow multi-site businesses to aggregate consumption data across DISCOMs, normalize different billing formats, and perform tariff analytics from a single dashboard. Global platforms like SAP and Oracle have utility-specific modules; Indian companies like Fluentgrid, Neptune India, and specialized energy consultancies provide localized solutions. The Indian Energy Exchange connects over 8,100 stakeholders across all states, offering a centralized marketplace for power procurement.
Smart meters, as they scale, will create a common data infrastructure. When millions of meters report standardized consumption data in real time, the case for harmonized billing formats, ToD structures, and data APIs becomes much harder for states to resist. The Green Open Access Registry already provides a single national portal for renewable energy procurement approvals.
India's electricity fragmentation is not an accident — it reflects genuine diversity in geography, development levels, political priorities, and energy needs across 28 states. Full standardization may never arrive, and perhaps shouldn't. But the current degree of variation imposes real costs: on businesses trying to operate nationally, on DISCOMs struggling to stay solvent, on industrial consumers bearing an outsized cross-subsidy burden, and on a grid trying to integrate hundreds of gigawatts of renewable energy.
The path forward is likely incremental. Smart meters will standardize data even if tariffs remain different. Open access and power exchanges will give consumers more choices. The Amendment Bill, if it passes, could introduce competition that forces DISCOMs to improve. But the deepest challenge is political will — the willingness to price electricity closer to what it costs, to protect consumers through targeted cash transfers instead of blanket tariff subsidies, and to let regulatory commissions do their jobs without interference. Until that changes, India's power sector will remain what it has always been: a grid that is technically unified but commercially Balkanized — one nation, seventy-two electricity systems.