Two developments this week put long-term Indiana manufacturing power costs in sharper focus — a Ball State study linking county-level renewable restrictions to $204 million in GDP losses and more than 8,700 jobs, and a $2 billion DC Blox data center proposal targeting the former Ford Visteon site in Indianapolis and the same grid your facilities depend on.

Watch this TEG Daily on YouTube: TEG Daily — Ball State Renewable Study and DC Blox Indianapolis

Ball State Says Renewable Restrictions Are Costing Indiana GDP and Jobs

The Ball State Center for Business and Economic Research, led by Dr. Michael Hicks, released a study claiming that Indiana counties restricting utility-scale wind and solar have seen weaker economic performance — an estimated $204 million in net GDP loss and more than 8,700 fewer jobs concentrated in manufacturing, transportation, and warehousing.

On the surface that reads: allow renewables, get more jobs. Here's where that framing is incomplete. The study looks like a front-end snapshot of construction and manufacturing jobs without fully tracking what happens after these projects are built. Utility-scale renewable integration comes with high capital costs, cost recovery riders, and follow-on grid modernization projects — and every dollar the utility spends gets pushed back onto commercial, industrial, and residential customers. Whether the study accounts for the full second and third-order cost waves that land on your bill years after the ribbon is cut remains an open question.

What to watch now: how this brief gets used in county zoning fights and at the General Assembly. If Ball State's findings become the only story being told, you may get policy that chases near-term construction headlines without a full accounting of long-term cost recovery riders and grid upgrade spending.

DC Blox Targets Indianapolis: A $2B Large Load on the Grid You're Already On

DC Blox has filed plans to build a three-building, $2 billion data center campus on the former Ford Visteon manufacturing site at 305 Fintail Drive in Indianapolis — approximately 35 permanent positions and hundreds of construction roles. The company has committed to covering costs tied to a new substation and additional generation capacity, which on paper sounds favorable for existing customers.

It isn't automatically favorable. The real equation is data center plus utility posture plus regulator behavior. Substation and generation costs are only part of the infrastructure picture. Transmission and distribution upgrades can still be allocated to existing commercial and industrial customers over time — quietly, through future rate cases and riders. The question is whether AES and state regulators treat this as a self-funded project or as an opportunity to blend subsidy costs into future rates across your rate class.

The first public hearing is scheduled for May 14th at the City-County building. Watch how AES and local regulators describe transmission and distribution costs around this project. The substation is not the full picture.

Questions for Your Morning Huddle

Q: Do county-level renewable restrictions in Indiana affect manufacturing power costs? A: Not directly through today's bill — but they shape the economic strength of the communities you hire from and source from, and they influence the long-term direction of utility capital spending and rate structures. Counties with active restrictions may also see less local generation investment over time, which tightens supply options and leaves your operation more exposed to grid stress events.

Q: Will the DC Blox Indianapolis data center raise AES rates for existing commercial and industrial customers?A: DC Blox has committed to funding the substation and generation costs, which limits the direct exposure — but transmission and distribution upgrades beyond the substation can still be pushed onto existing customers through future rate cases and infrastructure riders. Whether this project raises your all-in power costs depends entirely on how AES structures those downstream infrastructure costs and how Indiana regulators respond.

Q: Who on my team should be tracking utility filings when a large load project is proposed in our territory? A: Someone should own reading the initial filings, attending key hearings, and specifically asking whether transmission and distribution costs are being structured as self-funded by the new customer or allocated across your rate class. If no one on your team has that accountability today, you will not see the cost shift coming until it appears on a bill two or three rate cases from now.

If you want a framework for evaluating how utility capital projects and large load additions could change your long-term power costs, the TEG Energy Decision Blueprint is a starting point.

Watch this TEG Daily on YouTube: TEG Daily — Ball State Renewable Study and DC Blox Indianapolis

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