Andhra Pradesh — Energy Transition Snapshot
Generated 1 May 2026Carbon intensity (recent ~48h)
Generation mix (latest)
Peak deficit history (%)
Overview
Andhra Pradesh sits within the Southern Regional (SR) grid and draws on a generation mix that spans thermal, hydro, wind, and solar assets. At the snapshot hour (2026-05-01 01:00 UTC), instantaneous demand stood at 10,349 MW — a scale that places AP among the larger SR consumers. The headline metric that frames the current posture is a carbon intensity of 576.4 gCO2/kWh averaged over the recent ~48h window, indicating the fuel mix is presently dominated by thermal dispatch. RE penetration at the latest hourly slice was 4.0%, a sharp drop from a higher starting point across the ~48h observation window — signalling significant intra-day and inter-day variability in renewable output. On the reliability front, the p95 peak deficit registers at 0.0%, suggesting AP has met peak demand without recorded shortage across the observed daily series. Open-access costs at HT voltage total INR 2.79/kWh (as of April 2025). Several structural metrics — AT&C losses, RPO compliance, residential tariff, and long-run demand CAGR — are not yet integrated into the data pipeline.
Demand & Supply
At 2026-05-01 02:00 UTC, AP's live SLDC feed records instantaneous demand at 10,349 MW. Against that load, the current fuel mix is heavily thermal: RE share at the latest hourly slice is 4.0%. The ~48h recent window delta for RE share is −51.4 pp, meaning renewable penetration has compressed sharply over the observation window — most likely reflecting the transition from a high-solar daytime window to overnight/early-morning hours when solar output collapses and wind contribution is reduced. This swing is characteristic of SR-zone grids with significant solar capacity but limited storage or must-run thermal flexibility to smooth the ramp. Peak deficit, measured as the p95 of daily peak shortage over the POSOCO PSP series (as of 2026-04-23), is 0.0%: AP's system operator has absorbed peak demand without logged shortage at the 95th-percentile threshold. That is a meaningful reliability signal given the 10,349 MW instantaneous load, though it should be read against the ~48h window rather than a full-year load duration curve. Multi-year demand CAGR is not yet integrated; directional load growth context is therefore unavailable. IEX DAM price data is also absent, precluding any spot-market marginal-cost comparison against the OA charge stack.
RE & Transition
RE share at the latest hourly observation (2026-05-01 01:00 UTC) is 4.0%, with a recent ~48h window delta of −51.4 pp. The magnitude of this delta is not a structural reversal; it reflects the diurnal collapse of solar generation between a high-penetration daytime period and the early-morning snapshot hour. Nevertheless, it underscores AP's dependence on time-of-day RE availability and the absence of dispatchable storage at scale. Average carbon intensity over the recent ~48h window is 576.4 gCO2/kWh — a level consistent with a coal-heavy dispatch stack during non-solar hours. For reference, a fully renewable dispatch would approach sub-50 gCO2/kWh; 576.4 gCO2/kWh indicates thermal units are carrying the majority of load during this window. Long-term RE trajectory cannot be assessed: the Atlas pipeline does not yet expose a multi-year demand or generation CAGR aggregator, so directional transition progress over 5–10 years is outside the scope of this snapshot. RPO compliance data is also not yet integrated (IEA-58), meaning it is not possible to confirm whether AP is meeting its statutory renewable purchase obligations. The combination of a high carbon intensity reading and a gapped RPO metric leaves the transition compliance picture materially incomplete.
DISCOM Health
The open-access charge stack for AP at HT voltage totals INR 2.79/kWh (as of 2025-04-01), comprising CSS, wheeling, transmission, and loss charges. This figure is the primary available cost-of-power signal for large commercial and industrial consumers considering OA procurement. A stack of INR 2.79/kWh is non-trivial relative to typical DAM clearing prices in the SR zone, though DAM price data is currently unavailable for direct comparison (IEX area-prices feed empty). On the reliability side, p95 peak deficit is 0.0% (as of 2026-04-23), which is consistent with a utility meeting its supply obligations at the measured percentile. DISCOM financial health cannot be assessed quantitatively: AT&C loss data (UDAY dataset, IEA-57) is not yet integrated, residential tariff data requires an API key not yet provisioned, and subsidy/incentive catalogue integration (IEA-59) is pending. These three gaps collectively prevent any assessment of revenue realisation, cross-subsidy burden, or DISCOM balance-sheet stress from this snapshot alone.
Outlook
Over a 1–3 year horizon, AP's posture is shaped by three available data points. First, the 0.0% p95 peak deficit indicates current grid reliability is adequate, but the 10,349 MW instantaneous load and the steep intra-day RE swing (−51.4 pp over ~48h) point to a growing grid-balancing challenge as solar capacity additions continue without commensurate storage. Second, the 576.4 gCO2/kWh average carbon intensity confirms thermal dispatch dominance during off-solar hours; decarbonisation progress will require either dispatchable RE (storage, pumped hydro) or demand-side flexibility, neither of which can be sized from current data. Third, the INR 2.79/kWh OA charge stack constrains the economics of captive/third-party open-access renewable procurement for large consumers; policy decisions on CSS and wheeling charges will directly determine whether AP can attract industrial RE buyers. The four structural gaps — AT&C losses, RPO compliance, residential tariff, and demand CAGR — represent the highest-priority data integrations before a full investment or policy assessment is possible. No forward projections are made from unavailable inputs.
Data gaps in this brief
- Transmission ATC: Atlas endpoint not yet integrated (see IEA-56).
- DISCOM AT&C losses (UDAY): Atlas endpoint not yet integrated (see IEA-57).
- RPO compliance: state RE policy dataset not yet integrated (see IEA-58).
- Subsidies / incentives: state catalogue not yet integrated (see IEA-59).
- Residential tariff: Atlas tariff endpoint requires X-API-Key not yet provisioned for tools-api.
- Multi-year demand CAGR: Atlas does not yet expose a long-term aggregator (only ~48h realtime).
- IEX DAM price: upstream IEX area-prices feed currently empty.
- Transmission ATC: Atlas endpoint not yet integrated (IEA-56).
- DISCOM AT&C losses (UDAY): Atlas endpoint not yet integrated (IEA-57).
- RPO compliance: state RE policy dataset not yet integrated (IEA-58).
- Subsidies / incentives: state catalogue not yet integrated (IEA-59).