India Data Center Review 2026 — India's most comprehensive infrastructure analysis to support the A.I. era. 250+ pages, 14 chapters, 100+ illustrations, free to download.
Read NowIndia Data Center Review 2026 — India's most comprehensive infrastructure analysis to support the A.I. era. 250+ pages, 14 chapters, 100+ illustrations, free to download.
Read NowGujarat, operating within the Western Regional grid (IEX WR zone), is one of India's largest electricity-consuming states and a long-standing leader in utility-scale renewable deployment. As of 02:00 UTC on 1 June 2026, live SLDC-feed demand stood at 18,466 MW, with 46.8% of instantaneous generation sourced from renewables — a figure that places Gujarat among the higher RE-penetration states in WR. The state's carbon intensity averaged 480.2 gCO2/kWh over the recent ~48-hour window, reflecting a mixed thermal-RE dispatch profile typical of a large industrialised grid. AT&C losses, at a mean of 9.25% across its two reporting DISCOMs (FY23 data, range 6.40%–12.10%), are structurally below the national average, pointing to relatively disciplined distribution infrastructure. The open-access charge stack at HT voltage sits at INR 2.68/kWh. Four active incentive categories — covering agricultural pump subsidy, OA banking, and residential solar capex — underpin continued distributed uptake.
Gujarat's live demand at 02:00 UTC on 1 June 2026 was 18,466 MW, anchored on the state's SLDC real-time feed. At that timestamp, renewables contributed 46.8% of the generation mix. The recent ~48-hour window delta in RE share was +46.8 percentage points relative to the window-open reading (30 May 02:30 UTC), indicating a pronounced intra-window swing — likely reflecting diurnal solar output cycling across the window boundary rather than a structural shift; this should be read as a within-window fluctuation, not a directional trend. Peak deficit performance is robust: the p95 of daily peak shortage-to-demand ratio was 0.0% as of 30 May 2026, meaning Gujarat met peak demand without measurable shortfall at the 95th percentile of recent days. This zero-deficit p95 is consistent with the state's historically adequate generation capacity and its access to WR interchange. Transmission ATC and TTC data are not yet integrated into the Atlas pipeline, limiting any corridor-level congestion assessment. Multi-year demand CAGR is also unavailable; the Atlas platform exposes only the ~48-hour real-time window, so long-run demand growth trajectory cannot be quantified from current data.
At 46.8% RE share in the latest hourly slice (02:00 UTC, 1 June 2026), Gujarat is operating at a meaningful renewable penetration level for a large industrial-load state. The recent ~48-hour window delta of +46.8 pp should be interpreted with caution: this is a within-window fluctuation driven largely by solar generation cycling between the night-trough at window open (30 May 02:30 UTC) and likely peak solar output hours within the window, not evidence of a sustained multi-year transition trajectory. No long-term demand CAGR aggregator is available from Atlas, so structural load-growth context for transition planning cannot be derived from current data. Average carbon intensity over the recent ~48-hour window was 480.2 gCO2/kWh — consistent with a grid where coal-based baseload remains material even as solar penetration is high during daylight hours. RPO compliance is estimated at 20.8% (FY23, provisional/modelled from GERC tariff orders and Prayas review); this figure is below the trajectory implied by national RPO schedules, though its provisional nature warrants caution before drawing firm compliance conclusions. Gujarat holds 4 active incentive categories including OA banking provisions that structurally support RE procurement by open-access consumers.
Gujarat's two reporting DISCOMs recorded a mean AT&C loss of 9.25% in FY23 (range: 6.40%–12.10%), placing the state in a relatively strong position on distribution efficiency by Indian standards. The 5.7 percentage-point spread between the two DISCOMs signals heterogeneity within the state that warrants DISCOM-level scrutiny rather than reliance on the state mean alone. The open-access charge stack at HT voltage totals INR 2.68/kWh (as of April 2025), comprising CSS, wheeling, transmission, and loss charges — a relevant cost signal for large industrial and commercial consumers evaluating OA procurement against DISCOM supply. The p95 peak deficit of 0.0% (as of 30 May 2026) indicates no material reliability stress at the distribution-system supply level in recent days. Two data gaps constrain a fuller DISCOM health picture: average residential tariff data is unavailable (Atlas tariff endpoint lacks the required API key provisioning), and IEX DAM market-clearing prices are currently empty, removing the real-time market-cost benchmark against which DISCOM procurement economics would normally be assessed.
Over a 1–3 year horizon, Gujarat's energy posture is characterised by three anchoring data points: a 46.8% instantaneous RE share, a 0.0% p95 peak deficit, and AT&C losses of 9.25% (FY23). The zero peak-deficit p95 reduces near-term supply-security risk, but the absence of transmission ATC/TTC data means corridor-level bottlenecks — particularly relevant as RE capacity continues to be added in Kutch and Saurashtra — cannot be assessed from current metrics. The provisional RPO compliance estimate of 20.8% (FY23) suggests potential exposure to regulatory compliance costs if enforcement tightens under national RPO schedules, though this figure is modelled and should be verified against final GERC orders. The INR 2.68/kWh OA charge stack is a material factor for industrial consumers weighing third-party RE procurement; movement in this stack — particularly the CSS component — will influence captive and group-captive RE project economics. Three data gaps materially constrain forward analysis: residential tariff structure (API key gap), multi-year demand CAGR (no long-term aggregator), and IEX DAM price feed (upstream empty). Resolving these would substantially sharpen both demand-side and market-pricing dimensions of any investment or policy decision.
