Indiana Commercial Electricity: Limited retail choice with rates set by the IURC. Average commercial rate: 10.0-12.5¢/kWh (2026). Indiana spans two ISOs—NIPSCO in MISO and Duke/AES in PJM—creating distinct pricing dynamics. The state's heavy manufacturing base makes industrial tariff optimization critical.
A manufacturing powerhouse spanning two ISO markets. NIPSCO (MISO) in the north and Duke/AES (PJM) in the central/south.
NIPSCO is undergoing a significant generation portfolio transformation, retiring coal plants and replacing them with wind, solar, and natural gas. The transition costs are being recovered through base rate increases approved by the IURC.
View NIPSCO Rate Analysis →Northern Indiana (Gary, South Bend, Fort Wayne) is served by NIPSCO within the MISO market. MISO capacity prices have historically been lower than PJM, but the Zone 6 shortage is narrowing this gap significantly.
Central and Southern Indiana (Indianapolis, Bloomington, Evansville) falls within PJM Interconnection. These territories are subject to PJM capacity auction results, which cleared at record highs for the 2026/2027 delivery year.
See how your manufacturing or commercial facility compares to Indiana averages
Indiana is a top-10 US manufacturing state. Automotive, steel, pharmaceuticals, and logistics drive massive industrial loads with unique rate structures and interruptible tariffs.
Indiana historically relied on coal for 60%+ of generation. The aggressive retirement schedule (NIPSCO, Duke) is creating rate volatility as replacement resources come online.
Northern Indiana is part of the MISO wind corridor. NIPSCO is replacing coal with utility-scale wind and solar, creating long-term rate stability at the cost of near-term increases.
Whether you're in NIPSCO's MISO territory or Duke's PJM zone, our team can identify tariff optimization and demand response opportunities.
Get Your Rate Analysis →Latest news affecting Indiana commercial energy buyers
MISO's draft MTEP-26 totals $8.8 billion with $3.1B earmarked for data center and industrial load growth. Expedited Project Review processes 13 GW of new load. Peak demand CAGR revised to 1-2% through 2044 — up from 0.5% in prior plans. Board vote December 2026.
MISO's 2026/2027 PRA results post April 28. After Zone 4 cleared at $72.84/MW-day last year — a 300% spike — analysts expect further tightening. What this means for commercial electricity costs in IL, MI, IN, WI, MN.
MISO 2026/27 Planning Resource Auction results post April 28. 1.9 GW capacity gap, demand response verification tightening, and RBDC framework. Clearing price scenarios and commercial rate impact for Midwest buyers.
MISO PRA 2026-2027 capacity auction offer window closes March 31. 1.9 GW capacity gap, demand response verification tightening, and clearing price scenarios for Midwest commercial buyers.