Every chart on Wattfeed is powered by structured, source-verified data. This page documents each dataset — its columns, date range, and record count.
Daily energy demand (MU) for 35 states and UTs across all five regional grids. Primary input to the state demand heat maps, seasonal overlay charts, and day-of-year comparisons.
DatePunjabHaryanaRajasthanDelhiUttar PradeshAll-India and five-region daily maximum demand met (MW). Feeds the multi-region trend charts and diversity factor computation — the ratio that measures how synchronised regional peaks are.
DateNRWRSRERNEREvening peak demand at 19:00 hrs for all five regions and India. Tracks the critical post-solar ramp period and gauges pressure on peaking and storage assets.
DateNRWRSRERNERDaily peak demand met for individual states and UTs alongside the five regions and India. Powers the state-level peak comparison and state profile pages.
DateState/RegionPeak Demand Met (MW)Daily peak demand, time of occurrence, and unmet shortage split across solar hours (06:00–18:00) and non-solar hours (18:00–06:00). Reveals structural load shifts driven by solar penetration.
DateSolar Peak Demand (MW)Solar Time of PeakSolar Shortage (MW)Non-Solar Peak Demand (MW)Non-Solar Time of PeakState, regional, and all-India monthly peak demand met, energy met, shortages, and load factor. The foundational long-run demand dataset powering trend and regional comparison charts.
YearMonthStateRegionPeak Demand Met (MW)Peak Shortage (MW)96-slot (15-minute interval) all-India demand profile recorded on the maximum-demand day of each month. Enables intraday load shape analysis, morning ramp quantification, and peak-hour identification.
YearMonthDatePeak_MW00:0000:15Morning, evening, and night peak blocks declared each month by the five RLDCs — start time, end time, block duration, and total declared peak hours per day. These windows define when peak-rate obligations and reserve requirements bite.
DateYearMonthMonth_NameMonth_LabelLDCTwo parallel daily diversity factors — one computed against the five regional maximum demands, the other against the individual state maxima. Measures how far apart in time India's peaks actually fall, and therefore how much peaking capacity the country is spared from building.
DateBased on Regional Max DemandsBased on State Max DemandsThe solar and non-solar hours each state declares for a given week, as 15-minute block numbers, block counts, durations and clock times — with the solar window and the two non-solar windows either side of it held separately. The declaration decides which hours a generator is settled against solar terms and which against non-solar, so where a state draws the line is a commercial boundary, not a descriptive one.
Valid FromValid ToStateSolar Start BlockSolar End BlockSolar BlocksMonthly electricity generation by fuel type at both sectoral (central / state / private) and regional (NR/WR/SR/ER/NER) levels. Core input to the generation mix and Capacity/Generation charts.
YearMonthRegion / SectorSourceInstalled Capacity (MW)Programme Generation (GWh)Monthly installed generation capacity by region and fuel type, including renewables. Quantifies the structural transition from thermal to renewables in India's generation fleet over the past decade.
YearMonthRegionCoalLigniteGasDaily hydro, solar, and wind generation by all five regions and India. Three parallel series — enables variability analysis, curtailment tracking, and renewable ramp profiles.
DateNRWRSRERNERDaily forced outage capacity across central and state utility generating units. Quantifies how much capacity is unavailable each day and separates central from state-sector reliability.
DateCentral Sector Total (MW)Central Sector NR/WR/SR/ER/NER (MW)State Sector Total (MW)State Sector NR/WR/SR/ER/NER (MW)Monthly installed capacity cross-tabulated by region, state, ownership sector (Central/Private/State), and fuel type, plus the All-India renewable fuel-wise breakdown. Powers the multi-select Capacity Explorer.
YearMonthRegionStateSectorCoalDaily solar, wind, and other renewable generation broken down by individual state and by grid region. The most granular renewable generation dataset on the site.
DateState/RegionSolar (MU)Wind (MU)Others RES (MU)Total (MU)All-India source-wise generation dispatch, demand, net demand, and grid frequency at 15-minute resolution. The highest-resolution operational dataset on the site.
DateTimeFrequency (Hz)Demand Met (MW)Nuclear (MW)Wind (MW)Daily generation for six fuel groups — coal, lignite, hydro, nuclear, gas/naphtha/diesel, and RES — across all five regions plus All-India, with each fuel’s percentage share of the daily total. The daily counterpart to the monthly source-wise generation series.
DateCoal NR/WR/SR/ER/NER/India (MU)Coal % ShareLignite … (MU)Hydro … (MU)Nuclear … (MU)Monthly and daily programme-versus-actual generation for every plant monitored by the National Power Portal — 687 raw plant names harmonised to 616 canonical plants across 6 regions, 35 states, and 4 ownership sectors, with capacity and PLF.
PlantRegionStateSectorTypeMonthDaily All-India roll-up of the NPP monitored fleet — how many plants reported, total monitored capacity, and programmed versus actual generation. The headline reliability and coverage indicator for the plant-level database.
DatePlants ReportedTotal Monitored Cap (MW)Total Program (MU)Total Actual (MU)CEA’s monthly battery energy storage position — how many projects sit at each stage from tender through award and construction to operation, and how much power and energy capacity each stage holds. The clearest available read on how much of India’s announced storage pipeline has actually been built.
Report_DateReport_MonthFYCategoryNo_of_ProjectsCapacity_MWThe same monthly CEA battery storage reports read along the other axis — capacity by expected commissioning year and by stage, from everything built up to March 2025 out to the 2029-30 pipeline. Comparing one report against the next is how slippage becomes visible: capacity that moves to a later commissioning year, or is restated downwards entirely.
Report_DateReport_MonthCommissioning_YearStageCapacity_MWCapacity_MWhMonthly plant-level coal receipt (by source), consumption, and closing stock for 223 thermal plants, aggregated to regional and All-India totals. Powers the entire Coal Intelligence page.
MonthYearRegionName of PlantInstalled Capacity (MW)CIL/SCCL (kT)Monthly imported coal receipts for 90 power utilities, split between plants importing for blending with domestic coal and plants designed to run on imported coal. Separates the discretionary import market from the structurally import-dependent fleet.
Report DateYearMonthSectionSub-SectorPower UtilityDaily aggregate coal position for the reporting thermal fleet — domestic and imported stock, receipt, consumption, the normative stock requirement, days of stock in hand, and the count of stations sitting at critical levels.
DatePlants reportedCapacity (MW)Daily requirement (TT)Normative stock (TT)Stock domestic (TT)Daily coal stock, receipt and consumption for 231 individual thermal stations across 18 states — total stock split into its domestic and imported components, alongside the daily flows on either side of it. The most granular coal dataset on the site.
DateStatePlantStock Total (TT)Stock Domestic (TT)Stock Imported (TT)Monthly raw coal production for each of the eight Coal India subsidiaries, plus SCCL and the captive/commercial block, against the target set for that month. The primary read on whether domestic supply is keeping to plan.
DateYearMonthFYECL - TargetECL - ActualThe despatch side of the same monthly return — coal actually moved out of the pithead by each CIL subsidiary, SCCL, and captive producers, against target. Read alongside production, the gap between the two is pithead stock accumulation.
DateYearMonthFYECL - TargetECL - ActualMonthly coking coal output for the five CIL subsidiaries that produce it, plus captive and other producers. Coking coal is the steel feedstock rather than a power fuel, and its domestic shortfall is the single largest driver of India's coal import bill.
DateYearMonthFYECL - ActualBCCL - ActualWhere India's coal actually goes each month: power utilities, captive power plants, steel, cement, sponge iron, and everything else. The demand-side counterpart to the producer despatch series.
DateYearMonthFYPower - ActualCPP - ActualThe same six-way sector split restricted to Coal India despatch. Isolates how much of CIL's book is committed to the power sector under linkage, and how much reaches industrial consumers.
DateYearMonthFYPower - ActualCPP - ActualSector-wise despatch for Singareni Collieries, the Telangana state-owned producer that operates entirely outside the Coal India structure. Overwhelmingly a power-sector supplier.
DateYearMonthFYPower - ActualCPP - ActualSector-wise despatch from captive and commercial mines — the block that has grown fastest since commercial mining was opened, and the one that reveals how much coal now bypasses the CIL linkage system entirely.
DateYearMonthFYPower - ActualCPP - ActualMonthly lignite output for the eight producers that mine it — NLCIL, the Gujarat state operators, and the Rajasthan mines. Lignite is a small but regionally decisive fuel, and the fleet burning it sits almost entirely on the mine mouth.
DateYearMonthFYNLCIL - ActualGMDCL - ActualThe despatch side of the lignite return, producer by producer. Because most lignite capacity is pit-head, production and despatch track each other far more closely than they do for coal.
DateYearMonthFYNLCIL - ActualGMDCL - ActualMonthly all-India generation and percentage share for coal, lignite, hydro, nuclear, gas and renewables, as published in the Ministry of Coal return. A second, independent read on the generation mix alongside the CEA series.
DateYearMonthFYCoal - MUCoal - % shareHow Coal India's coal physically leaves each subsidiary — by rail, road, merry-go-round conveyor to a pit-head plant, or other modes. The clearest available measure of rail evacuation constraints, which are the recurring bottleneck between adequate production and adequate plant stocks.
DateYearMonthFYECL - RailECL - RoadMonthly statutory payments made by coal producers — royalty, District Mineral Foundation and NMET contributions, the three GST components, compensation cess, and the cess on coal. Coal is among the most heavily levied commodities in India, and this is what the state actually collects on each tonne.
DateYearMonthFYRoyalty - MonthDMF - MonthMonthly plant-level gas capacity, generation (target vs actual), and Plant Load Factor for 69 gas stations across 17 states, plus pre-aggregated regional and All-India series.
YearMonthRegion/StateStationCapacity (MW)Target Generation (MU)Monthly gas allotted against gas actually supplied for 65 stations across 13 states — broken out by domestic APM, non-APM, KG-D6, and RLNG long-term, e-bid and spot — plus alternate fuel use and generation lost to short supply.
PeriodYearMonthGrid ConnectivitySectorRegionMonthly natural gas supply and demand for the whole economy, not just the power sector: gross and saleable production by ONGC, OIL and private/JV operators, LNG imports, consumption across six consuming sectors split between domestic gas and R-LNG, and a state-wise consumption panel.
MonthFiscal YearGross Production – ONGC (MMSCM)Gross Production – OIL (MMSCM)Gross Production – Pvt./JV (MMSCM)Gross Production – Total (MMSCM)Daily frequency distribution statistics — time within the IEGC band, under/over-frequency excursions, average frequency, and min/max. The real-time barometer of demand-supply balance.
DateTime Below 49.9Hz (min)Time Within Band 49.9–50.05Hz (min)Time Above 50.05Hz (min)Average Frequency (Hz)Highest Frequency (Hz)Monthly and daily cross-border power flows with Bhutan, Nepal, Bangladesh, and Myanmar. Tracks India's role as a regional power hub, both in aggregate and by individual transmission line.
YearMonthBhutan Export/Import/Net (MU)Nepal Export/Import/Net (MU)Bangladesh Export/Import/Net (MU)Myanmar Export/Import/Net (MU)Daily scheduled and actual power flow between India's five regional grids, with the resulting over/under-drawal. Identifies surplus and deficit regions and physical congestion.
DateNR Scheduled/Actual (MU)WR Scheduled/Actual (MU)SR Scheduled/Actual (MU)ER Scheduled/Actual (MU)NER Scheduled/Actual (MU)Daily net power transfer across the 7 bilateral corridors connecting India's regional grids (e.g. East↔North, West↔South). Shows which corridor direction is the net export path each day.
DateEast↔NorthEast↔WestEast↔SouthEast↔North-EastNorth↔North-EastDaily line-level import/export between every pair of neighbouring grid regions, both directions, down to individual transmission line detail. The most granular transmission dataset on the site.
DateTransmission LineFlow (MU)Total (MU)Weekly All-India transmission loss percentage on the Central Transmission Utility network. A compact but long-running indicator of grid-wide transmission efficiency.
S.NoYearWeek StartWeek EndPeriodAll India Transmission Loss (%)Daily corridor-level breaches of Available Transfer Capability and of the N-1 security criterion across six inter-regional interfaces — how many 15-minute blocks were violated, for how many hours, and what share of the day that represents.
Date of ReportingReport DateS.No.CorridorBlocks ViolatedHours ViolatedThe full GRID-INDIA daily frequency report: time spent in each frequency band, the count and average duration of excursions either side of the IEGC band, instantaneous and 15-minute-average extremes with the exact clock time each occurred, and the daily frequency variation index, standard deviation, mileage and FDI.
DateDay<49.2<49.7<49.90<49.97Daily security-constrained unit commitment volumes alongside secondary and tertiary reserve ancillary service deployment — energy scheduled up and down, and the maximum, minimum and average MW held in each direction. The operational cost of balancing a grid with rising renewable share.
DateYearMonthDay of WeekSCUC-Up Scheduled (MWh)SCUC-Down Scheduled (MWh)The monthly System Reliability Index in full: corridor-level ATC and N-1 violations aggregated to the month, the substation voltage profile for 112 substations at 400 kV and 765 kV, and a national summary strip counting violated blocks, affected corridors and substations breaching the voltage band.
PeriodYearMonthMonth StartCorridorBlocks ViolatedMonthly transmission charges notified to every Designated ISTS Customer, split by charge component — AC unbundled and bundled, HVDC and RE node charges, reactive, total and bilateral — alongside the GNAsh/LTA quantum the charge was struck against.
Billing_MonthYearMonth_NoMonthS_NoDIC_CleanThe access quantum held by each Designated ISTS Customer each month across the three regimes that have governed ISTS access — long- and medium-term open access, general network access, and the GNA shadow quantum used during the transition.
Billing_MonthYearMonth_NoMonthS_NoDIC_CleanMonthly short-term transmission rates notified per state under both the short-term open access and temporary GNA regimes, in the two units the notifications use.
Billing_MonthYearMonth_NoMonthS_NoStateThe percentage waiver applied to each Designated ISTS Customer’s transmission charges each month — the mechanism through which renewable and cross-border transactions have been discounted off the ISTS pool.
Billing_MonthYearMonth_NoMonthRegionStateYearly transmission charges claimed by each ISTS licensee against the amount allowed, with the equivalent monthly transmission charge. The supply side of the ISTS pool — what the licensees are paid, against what the customers above are billed.
Billing_MonthYearMonth_NoMonthS_NoISTS_LicenseeEvery gas station offering tertiary reserve ancillary service, week by week — the fixed and variable cost offered for each fuel product and operating cycle, with installed capacity and ramp rates in both directions.
Week NoWeek StartWeek EndYearProvider (canonical)StationEvery thermal station quoting into tertiary reserve ancillary service each month — fixed and variable cost, installed capacity, technical minimum, and ramp rates up and down, separated into shortfall and emergency categories.
Period_IDPeriod_LabelPeriod_StartPeriod_EndYearMonth_NoMonthly collective and bilateral Short Term Open Access statistics — total energy traded and participant counts, cleared through NLDC.
YearMonthC-STOA Energy (MU)C-STOA ParticipantsB-STOA Energy (MU)B-STOA ParticipantsMonthly bilateral Short Term Open Access energy and transaction volumes by RLDC region. Reveals which grids dominate as buyers and sellers in the short-term bilateral market.
YearMonthRegionEnergy Traded (MU)No. of TransactionsDaily traded volume and clearing price across the Day-Ahead Market, Real-Time Market, Green Day-Ahead Market, and Green Hourly-Peak Day-Ahead Market on the power exchanges.
DateMarketHour BlockMCV (MW)MCP (₹/kWh)Purchase Bid (MW)Daily traded volumes for Term-Ahead Market, Green Term-Ahead Market, and Green Hourly-Peak Term-Ahead Market contracts — the exchange-based alternative to bilateral STOA.
DateMarketContract TypeVolume (MU)Weighted Avg Price (₹/kWh)Monthly G-DAM buy and sell volumes broken out by individual participating entity. The most granular market-participant dataset on the site.
YearMonthEntityBuy Volume (MU)Sell Volume (MU)Monthly decomposition of the entire short-term power market — bilateral (via traders and direct), each exchange broken down by DAM, RTM, G-DAM and HP-DAM, and deviation settlement — set against total generation. The single best view of how short-term trade is split between routes.
YearMonthNumMonthPeriodBilateral_Total_MUBilateral_TradersPX_MUMonthly minimum, maximum, and weighted-average clearing price for every combination of market segment and power exchange — DAM, RTM, G-DAM and HP-DAM across IEX, PXIL and HPX. Shows how far exchange prices diverge and where the spread is widest.
YearMonthNumMonthPeriodSegmentExchangeMonthly price range for bilateral trades intermediated by trading licensees, split into round-the-clock, peak, and off-peak contracts, alongside the trading margin licensees earned. The bilateral counterpart to exchange price discovery.
YearMonthNumMonthPeriodMin_Price_Rs_kWhMax_Price_Rs_kWhDay-wise DSM volume with minimum, maximum, and average deviation charge, plus the monthly price-spread summary derived from it. DSM is the balancing mechanism of last resort, so its price range is the sharpest read on real-time system stress.
MonthNumMonthDayPeriodVolume_MUMin_Charge_Rs_kWhMonthly count of active inter-state trading licensees, the share held by the top five, and the Herfindahl-Hirschman Index. Measures whether bilateral trade is consolidating into fewer hands or opening up.
YearMonthNumMonthPeriodN_LicenseesTop5_PctMonthly ranked market share for each of 74 inter-state trading licensees. The underlying detail behind the concentration index — shows exactly which traders gained and lost ground, month by month.
YearMonthNumMonthPeriodRanklisencee_nameMonthly congestion statistics per segment and exchange — unconstrained versus actually cleared volume, how much failed to clear because of transmission congestion, and what share of the day congestion was binding, broken into four six-hour bands.
YearMonthNumMonthPeriodSegmentExchangeGreen day-ahead clearing at 15-minute resolution under the reporting split IEX moved to in July 2026 — bids, market clearing volume and final scheduled volume broken out by Hydro, Wind, Other RE and DRE (distributed renewable energy), with the clearing price. The energy-type breakdown is finer than the Solar / Non-Solar / Hydro split that preceded it.
DateHourTime BlockPurchase Bid (MW)Total Sell Bid (MW)Hydro Sell Bid (MW)Monthly Renewable Energy Certificate opening balance, issuance, redemption (via exchanges and traders), and closing balance. Tracks the compliance market underpinning India's RPO framework.
DateOpening BalanceRECs IssuedRECs Redeemed (Exchanges)RECs Redeemed (Traders)RECs Retained by GeneratorsMonthly REC issuance and redemption broken down by power exchange and by generator category (solar / non-solar), sourced directly from GRID-INDIA rather than the aggregate registry.
YearMonthExchangeCategoryRECs IssuedRECs RedeemedDaily variable renewable energy penetration for All-India — wind, solar, and combined contribution and penetration during solar and non-solar hours, daily maxima with the exact time they occurred, and running all-time records for every metric.
Report_DateSolar_Hours_WindowSolarHrs_Max_Demand_Met_MWSolarHrs_Wind_Contribution_MWSolarHrs_Solar_Penetration_pctSolarHrs_VRE_Penetration_pctDaily wind and solar capacity, availability, generation extremes, schedule-versus-actual, and capacity utilisation factor for the RE-rich regions and the eight states that dominate India’s renewable fleet — reported separately for the all-India, ISTS-connected, and intra-state layers.
Report_DateEntityEnergy_SourceInstalled_Capacity_MWMax_Available_Capacity_MWDay_Max_MWThe same daily wind and solar metrics for the non-RE-rich regions and states — Assam, Bihar, Chhattisgarh, Mizoram, Odisha, Punjab, Tripura and Uttar Pradesh. Tracks how renewable build-out is spreading beyond the traditional wind and solar belts.
Report_DateEntityEnergy_SourceInstalled_Capacity_MWMax_Available_Capacity_MWDay_Max_MWAll-India annual CO₂ emissions and emission intensity from the power sector, financial year 2014–15 through 2024–25. The top-line trend feeding the Emissions Intelligence KPI strip.
Financial YearTotal Emissions (Million Tonnes CO2)Specific Emission (tCO2/MWh)Total Generation (MU)Annual CO₂ emissions and specific emission rate for 599 individual power plants across 41 states, now covering hydro and nuclear stations alongside thermal. Powers the searchable plant explorer on the Emissions page.
Financial YearStatePlant NameFuel TypeInstalled Capacity (MW)Generation (MU)Daily live storage for 31 major hydroelectric reservoirs across India, as a percentage of full reservoir level and against the 10-year average. Tracks hydro generation risk and monsoon dependency.
DateReservoirLive Storage (BCM)% of Full Reservoir Level10-Yr Average %A filterable database of 1,838 individual conventional generating units across 6 fuel types and 34 states — plant name, unit-wise capacity, commissioning details, and ownership.
Plant NameStateSectorFuel TypeUnit NumberUnit Capacity (MW)Revenue from operations, tariff subsidy billed and received, UDAY and other revenue grants, other income and regulatory income for every state distribution utility, resolved to three total-revenue definitions. The table that decides whether a DISCOM looks solvent or not.
FYSource_reportSectionGroupStateUtilityThe same revenue lines expressed as Rs per kWh of gross input energy, ending in three average realisable revenue (ARR) definitions. This is the numerator of the ACS–ARR gap.
FYSource_reportSectionGroupStateUtilityRevenue per unit restated on energy sold rather than energy input — so distribution losses sit outside the denominator. Reading this against the input-basis table above is the cleanest way to see what AT&C losses cost a utility per unit.
FYSource_reportSectionGroupStateUtilityPower purchase cost, own generation cost, employee cost, interest, depreciation and other costs for every distribution utility, with total expenses and a combined cost-of-power line.
FYSource_reportSectionGroupStateUtilityThe expense lines restated as Rs per kWh of gross input energy, terminating in average cost of supply. Paired with Annexure 1.1(a) this gives the ACS–ARR gap that dominates every discussion of Indian distribution finance.
FYSource_reportSectionGroupStateUtilityCost per unit of energy sold rather than energy input, ending in ACS on an energy-sold basis. The gap between this and the input-basis ACS is a direct read on distribution loss.
FYSource_reportSectionGroupStateUtilityProfit after tax on three subsidy treatments alongside the corresponding ACS–ARR gap per unit. The difference between PAT on subsidy billed and PAT on subsidy received is, in effect, what state governments owe their own utilities.
FYSource_reportSectionGroupStateUtilityAverage cost of supply, average realisable revenue and the resulting gap, all on an energy-sold basis and all excluding regulatory income and UDAY grants. The tightest three-column statement of the distribution gap in the whole PFC report.
FYSource_reportSectionGroupStateUtilityThe gap restated on cash actually collected — total revenue stripped of unrealised sale-of-power revenue and unrealised subsidies. A utility can post a modest accrual gap and a severe cash gap, and this table is where that shows up.
FYSource_reportSectionGroupStateUtilityThe asset side of the distribution balance sheet: net tangible assets, capital work in progress, regulatory assets, receivables for sale of power in both rupees and days, and total assets.
FYSource_reportSectionGroupStateUtilityThe liability side of the distribution balance sheet: equity and capital reserves, non-current and short-term borrowings, payables for power purchase in rupees and days, and current maturities and interest due on long-term borrowings.
FYSource_reportSectionGroupStateUtilityEquity, general reserves, accumulated surplus or deficit, capital grants and consumer contributions resolved into net worth, alongside state government borrowings and total borrowings.
FYSource_reportSectionGroupStateUtilityCash-adjusted debt service coverage ratio (DSCR) with its three inputs — adjusted EBITDA, total interest cost, and opening current maturities on long-term borrowings with interest accrued.
FYSource_reportSectionGroupStateUtilityAggregate technical and commercial losses decomposed into their two drivers — billing efficiency and collection efficiency — with the input, sold and realised energy behind them.
FYSource_reportSectionGroupStateUtilityRevenue from operations and other income for state generation, transmission and trading utilities, with the per-unit restatement against net generation or gross input energy.
FYSource_reportSectionGroupStateUtilityPower purchase and generation cost, employee cost, interest, depreciation and other costs, with total expenses and a combined generation-or-purchase line for utilities that do both.
FYSource_reportSectionGroupStateUtilityThe same cost lines expressed as Rs per kWh, ending in average cost of supply. For a TRANSCO the per-unit figures are struck against energy wheeled rather than generated, so cross-group comparison needs care.
FYSource_reportSectionGroupStateUtilityTotal revenue against total expenses, tax and deferred tax, profit after tax, and the resulting per-unit gap for state generation, transmission and trading utilities.
FYSource_reportSectionGroupStateUtilityNet tangible assets, capital work in progress, non-current assets, trade receivables and current assets for state generation, transmission and trading utilities.
FYSource_reportSectionGroupStateUtilityEquity and capital reserves, non-current and short-term borrowings, payables for power and fuel purchase, other liabilities, and maturities and interest due on long-term borrowings.
FYSource_reportSectionGroupStateUtilityEquity, reserves, accumulated surplus or deficit, capital grants and consumer contributions resolved into net worth, with state government and total borrowings.
FYSource_reportSectionGroupStateUtilityReceivables for sale of power in both rupees and days outstanding. Read against the distribution side’s payables-in-days, this is the two-sided picture of the money owed between state utilities.
FYSource_reportSectionGroupStateUtilityPayables for fuel and power purchase in rupees and days outstanding — how long generators are taking to pay their coal and gas suppliers.
FYSource_reportSectionGroupStateUtility