Three developments this week carry direct cost and risk consequences for Indiana manufacturers on any investor-owned utility rate schedule. The IURC closed the AES Indiana rate case with a $71 million annual revenue increase — then new commission leadership arrived recused from Indiana's two highest-stakes open dockets. DOE renewed emergency coal orders covering 952 megawatts of largely offline generation through September 19. And Ports of Indiana-Burns Harbor finished a roughly $100 million buildout that reshapes bulk logistics for northern Indiana, with a federal grant deadline hitting June 27.

AES Indiana Rate Case Closes at a Compressed ROE — Then the Commission Chair Changes

The IURC voted 3-1 on June 17 to approve a $71 million annual revenue increase for AES Indiana, with Commissioner Deig dissenting. The commission cut AES's allowed return on equity from the settled 10.7% down to 9.5% — below AES's current 9.9% — while locking the utility into a rate freeze that bars a new base case until 2029 and new rates until 2030. AES must finance the Petersburg coal-to-gas repowering (due December 2026) and the 85-megawatt Crossvine Solar and Storage project (due mid-2027) entirely inside that freeze.

Within days of the order, Governor Braun replaced Chairman Zay with Commissioner Anthony Swinger, who is recused from 20 pending dockets tied to his prior work at the OUCC — including the AES case itself. Braun is simultaneously calling for OUCC rehearing of the AES order, while the OUCC is already pursuing Duke Energy Indiana for an estimated $86.5 million in excess annual collections. The new chair cannot touch the AES rehearing path or the NIPSCO-Genco docket ecosystem, leaving Indiana's two highest-exposure regulatory proceedings to the remaining commissioners at the exact moment the governor is signaling he wants those orders revisited. If you hold a large-load contract or special rate with any Indiana investor-owned utility, get a read now on whether a rehearing filing could reopen terms you considered final.

DOE Renews Schahfer Coal Orders for a Third Time — Court Ruling Could Shift the Retirement Timeline

Energy Secretary Chris Wright on June 18 extended Section 202(c) emergency orders requiring NIPSCO to keep Schahfer Units 17 and 18 in Wheatfield and CenterPoint to keep the Culley plant in Warrick County online through September 19 — a combined 952 megawatts. NIPSCO has reported $11.5 million in compliance losses to date. The detail buried in the headline: both Schahfer units are currently offline for turbine and boiler repairs — DOE is preserving dispatch capability from units that, by NIPSCO's own admission, are largely unavailable.

FERC has authorized MISO to recover compliance costs through tariffs spread across all 11 MISO states, so your facility is absorbing a share of those losses regardless of which utility serves you. The D.C. Circuit Court of Appeals (docket 26-1057) filed its opening brief May 8. A ruling before September 19 could invalidate these orders and shift the retirement timeline from federally mandated to utility controlled, with MISO reliability-must-run proceedings likely to follow. Build that scenario into your business continuity planning now, not after a ruling drops.

Burns Harbor Port Expansion Near Complete — Railcar Storage Up 1,200%, Grant Deadline June 27

Ports of Indiana-Burns Harbor in Portage is nearing completion of a roughly $100 million infrastructure buildout: railcar storage capacity expanded 1,200%, adding 250 additional railcar slots and enabling unit train service; ocean-vessel handling capacity is up 35% with three new ship berths; and Louis Dreyfus — one of the global big-four agri-commodities firms, with 2024 net sales of $50.6 billion — is set to reopen the port's international grain export terminal, which closed in 2023. The FY26 MARAD Port Infrastructure Development Program has $488.6 million in discretionary grants available with applications closing June 27. If your inbound raw materials or outbound finished goods move through the Calumet corridor, pull your current routing contracts and run the unit-train economics against what Burns Harbor now offers before that deadline passes.

Questions for Your Morning Huddle

Q: What does the IURC's AES Indiana rate order mean for manufacturers on AES rate schedules?
A: The IURC approved a $71 million annual revenue increase for AES Indiana but cut the allowed ROE to 9.5%, and Governor Braun is calling for OUCC rehearing of the order. If you hold a large-load contract or special rate with AES Indiana, determine now whether a rehearing could reopen terms you considered settled.

Q: What happens to Indiana manufacturer electricity costs if the D.C. Circuit invalidates the DOE's Schahfer coal orders?
A: Invalidation would shift Schahfer's retirement timeline from federally mandated to utility controlled, likely triggering MISO reliability-must-run proceedings. Your facility is already absorbing a share of the $11.5 million in reported NIPSCO compliance losses through MISO tariff recovery — a retirement scenario adds grid reliability risk on top of that existing cost exposure.

Q: Should Indiana shippers revisit routing contracts given the Burns Harbor buildout?
A: If you move bulk commodities by rail through northern Indiana or the Calumet corridor, yes. The 1,200% increase in railcar storage capacity and new unit train capability materially changes per-car logistics costs, and the port's FY26 federal grant push closes June 27 — the next funding cycle is already in motion.

Indiana manufacturers are simultaneously absorbing regulatory instability at the IURC, carrying unquantified grid-risk exposure from a court case that could pull 952 megawatts from compelled dispatch before September 19, and sitting within reach of a port logistics upgrade whose first-mover window closes this month. For a structured framework to evaluate how Indiana utility and regulatory changes affect your all-in cost of power, start with the TEG Energy Decision Blueprint.

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