NIPSCO's failure to restore power to Gary, Indiana within 12 days of an August 11 derecho is a direct consequence of a regulatory body that denied a $741 million grid hardening plan and simultaneously owns the vegetation management oversight program a class-action lawsuit now calls inadequate. If you operate a facility anywhere in Indiana — Lake County, Porter County, or central Indiana — two separate utility stories converged this week into a single planning question: is your operation sized for a multi-day grid failure, or only for a shift-length one?

This TEG Daily covers the NIPSCO outage Gary Indiana manufacturers need to understand, the IURC contradiction sitting underneath it, and the September 8 AES Indiana rate deadline that central Indiana operators cannot afford to ignore.

NIPSCO Leaves 30,000 Customers Dark for 12 Days — Including 17,000 in Gary

As of Sunday, August 23, NIPSCO was still working to restore power to roughly 30,000 customers, with nearly 17,000 of them in Gary alone — twelve days after the August 11 derecho struck with 99 mph straight-line wind gusts and killed seven people. NIPSCO set a restoration target of end of day Tuesday, August 25 for Gary. That deadline had already slipped once before that date.

The slow restoration matters operationally: a 12-day outage is not a weather event anymore. It is a reliability failure. Governor Braun activated the National Guard, requested an expedited FEMA disaster declaration covering 54 counties, and told NIPSCO publicly to put every available resource in the field and get creative.

Why the restoration dragged: the NIPSCO outage Gary operators experienced is not just a function of storm severity. It reflects what happens when vegetation management is deferred and grid hardening is blocked — which brings us directly to the regulatory layer.

The IURC Contradiction: Denied the Investment, Owns the Oversight

Weeks before the August 11 storm, the Indiana Utility Regulatory Commission voted 3-0 to deny NIPSCO's $741 million, five-year infrastructure improvement plan. The IURC ruled that NIPSCO failed to provide sufficient evidence that each proposed upgrade was cost-justified.

That denial is now Exhibit A in a class-action complaint filed in Porter Superior Court on behalf of potentially more than 100,000 customers. The complaint alleges systemic vegetation mismanagement.

Here is the contradiction: the IURC blocked the grid hardening investment. The IURC also oversees the vegetation management program the lawsuit says was inadequate. The same regulatory body denied the infrastructure plan and owns the oversight failure simultaneously.

That is not an edge case or a technicality — it is the structural flaw that leaves every manufacturer served by NIPSCO in Lake and Porter County exposed. NIPSCO already carries the highest residential rate among Indiana investor-owned utilities at $233.62 per 1,000 kWh, and its reliability record ranks worst in the state. If you want the underlying SAIDI and SAIFI figures, those are in the IURC's annual reliability report.

The NiSource Share Sale: Governance Story, Not an Operational Budget Story

Three days into the outage — on August 14 — NiSource EVP Melody Birmingham, the executive personally running NIPSCO's public crisis response, filed an SEC Form 144 disclosing intent to sell approximately 38,000 NiSource shares at roughly $42.40 per share, totaling about $1.6 million.

Whether the sale was pre-scheduled is a separate legal question. The governance fact is this: an EVP disclosing a $1.6 million share sale three days into a crisis she is personally fronting will be Exhibit B in the class action and in any IURC reliability proceeding that follows. It stands completely apart from anything about NiSource's operational budget — but it will shape how aggressively regulators and plaintiffs pursue accountability.

If NIPSCO misses the August 25 restoration deadline again, expect Governor Braun to escalate toward a formal IURC reliability proceeding. That proceeding will directly shape how NIPSCO recovers costs going forward — which means it will shape your future rate exposure in Lake and Porter County.

The AES Indiana Story: Settlement Clears the Path to a September 8 Rate Decision

The second major development this week involves central Indiana. On August 22, Governor Braun's office announced a $625,000 settlement ending former IURC Commissioner Andy Zay's wrongful-termination lawsuit. The payout breaks into three lump sums: $185,000 in W-2 wages, $300,000 to resolve other claims, and $140,000 in attorneys' fees.

Neither side admitted wrongdoing. Both sides agreed to dismiss the Marion Superior Court lawsuit.

What the settlement resolves: AES Indiana had used the procedural cloud created by the Zay lawsuit to pause the rehearing on its approved $71 million rate increase. That pause is now cleared. The reconstituted IURC — four of five commissioners are now Braun appointees — faces a live September 8 deadline on the Office of Utility Consumer Counselor and Citizens Action Coalition petitions to revisit that rate decision.

With four of five commissioners appointed by Braun and Braun's own OUCC petitioning for reversal, the base case is a partial or full rate rollback. But this is not a settled outcome.

What the settlement does not resolve: the June 15 phone call from Secretary of Energy Suzanne Jaworowski to sitting Commissioner Zay — two days before the AES rate vote — was never adjudicated as lawful or unlawful. That unadjudicated ex parte question is exactly what AES Indiana's lawyers will raise in any appellate challenge to a reversed rate order. AES Corporation is currently the target of a $33.4 billion buyout by a BlackRock-led consortium, with analysts flagging AES Indiana's data center pipeline as a valuation driver. They will contest a rate reversal aggressively.

Walmart and Eli Lilly — named parties to the October 2025 partial settlement the IURC undercut — have direct financial exposure here. So does every central Indiana manufacturer on AES Indiana's system.

Questions for Your Morning Huddle

Q: If my facility is in Lake or Porter County and served by NIPSCO, what do I need to check today?

A: Audit your backup generator autonomy in hours — not in fuel tank capacity alone, but in runtime against your actual critical load. The August 11 outage ran 12 days. If your generator is sized for a shift-length event, it was not sized for this. Get a quote this quarter on either a second NIPSCO feed from a separate substation or on-site natural gas generation sized to critical loads; both options carry 12-to-18-month lead times, so the decision window is now.

Q: What does NIPSCO's infrastructure denial mean for my future rate exposure in Lake or Porter County?

A: The IURC denied NIPSCO's $741 million hardening plan — meaning the upgrades still need to happen, and the cost recovery path for them remains open. If a formal reliability proceeding follows the August 11 outage, the approved cost recovery structure for any future hardening investment will be set there. Your rate exposure in Lake and Porter County is not resolved; it is deferred and likely increasing.

Q: Should I model an AES Indiana rate reversal or rate continuation for my 2027 budget?

A: Model both. The base case tilts toward a partial or full rollback given the IURC's reconstituted composition, but AES has a credible appellate path through the unadjudicated ex parte argument. The September 8 deadline creates appellate uncertainty that will not resolve quickly. Run the 2027 number under both scenarios before that deadline, not after.

Q: What is an interruptible tariff and should I ask NIPSCO about it now?

A: An interruptible tariff is a rate structure where you agree to reduce or cut your load on short notice during grid stress events in exchange for a lower base rate. If your facility has loads you can shed — certain HVAC, lighting, non-critical process lines — it may qualify. It also gives you advance notice of grid stress before curtailment hits, which is operationally useful in a service territory with NIPSCO's reliability record. Ask your NIPSCO account rep whether your facility qualifies and request the tariff schedule in writing.

The Bottom Line

Indiana's two largest utility stories right now share the same structural flaw: a regulatory environment that is underfunding grid reliability in the northwest and under political pressure on rate decisions in the center — at the same time. Indiana is on pace for 89 tornadoes through July 2026 versus a 28-tornado historical average, and the August 11 derecho that hit Gary was a separate event on top of that. Whether 2026 proves anomalous or not, the planning question does not change: your continuity plan needs to be sized for a 12-day grid event, not a shift-length one.

For background on how NIPSCO's infrastructure denial connects to the broader rate case mechanics playing out at the IURC, see the coverage from August 18: Nucor $59M Steel Plant, IURC Crisis, and Samsung SDI: Indiana Manufacturing News for August 18, 2026.

For the ongoing AES Indiana rate story and what central Indiana manufacturers should be tracking, start with the August 21 brief: AES Indiana Rate Freeze Risk & Indiana Labor Pressure | TEG Daily August 21, 2026.