DOE Orders Indiana Coal Plants Online Despite Court Ruling

Federal energy regulators have ordered two Indiana coal plants to stay online through 18 December 2026, invoking emergency powers for the fourth consecutive time in nine months, even as a federal appeals court ruled last week that an identical order for a Michigan plant was an unlawful usurpation of state authority.

Energy Secretary Chris Wright issued the latest round of Federal Power Act Section 202(c) directives to Northern Indiana Public Service Company (NIPSCO) and CenterPoint Energy, requiring the R.M. Schahfer Generating Station’s Units 17 and 18 (each rated at approximately 423.5 MW) and F.B. Culley Unit 2 in Warrick County to remain operationally available through mid-December. The directives also bind the Midcontinent Independent System Operator (MISO), the regional grid operator.

This is the fourth order in an unbroken chain reaching back to 23 December 2025, when the U.S. Department of Energy (DOE) first declared a Midwest grid emergency. It is a federal energy confrontation with real consequences for ratepayers, grid operators, and investors watching coal-to-clean transitions across the MISO footprint.

Here is what the renewal actually settles: the DOE has bought another quarter of dispatchable coal capacity. What it leaves unresolved is the legal ground beneath that strategy, which is shifting fast.

A third emergency renewal: what the new DOE orders actually require

The new directives cover the period from 20 September 2026 through 18 December 2026, and they impose a specific operational obligation. NIPSCO, CenterPoint, and MISO must take all necessary steps to keep the named units ready and available, including using economic dispatch to hold down consumer costs.

The units in question are concrete and named. Schahfer Units 17 and 18 sit in Wheatfield, Indiana, each rated at roughly 423.5 MW. Culley Unit 2 sits in Warrick County. Certain units at both plants had been scheduled for decommissioning at the close of 2025 before the DOE intervened.

What matters most is the pattern. This is not a fresh emergency declared each quarter; it is the same policy position extended three times over.

Each order cites the same statutory basis, Federal Power Act Section 202(c), and the same rationale: shortages of electric energy and generation facilities, rising demand, and the public interest.

The fact that the DOE has renewed the directive three times without returning to Congress or the Federal Energy Regulatory Commission (FERC) tells you the administration now treats emergency powers as a standing tool for resource adequacy, not a temporary measure. Each renewal extends the policy, and the cumulative legal exposure grows with every order issued.

A parallel case underscores the pattern: the DOE issued a fourth emergency order for a coal plant that never ran under any of the prior directives, raising pointed questions about how the department defines operational necessity under its resource adequacy rationale.

What Winter Storm Fern revealed about Midwest grid stress

The DOE’s strongest argument is the winter itself. Winter Storm Fern (22-27 January 2026) pushed the MISO grid to its limits and became the primary test case for the reliability rationale.

The operational record shows genuine strain:

• MISO average hourly demand rose from roughly 74.6 GW to about 95 GW at the storm’s peak.
• MISO declared two Maximum Generation Events (Step 2c) in its North and Central regions on 24 January 2026 to access emergency capacity.
• Unplanned outages across the broader system peaked at approximately 68,169 MW on 26 January 2026.

That is a stressed grid by any measure. But the record complicates the DOE’s framing more than the department acknowledges.

Available reporting and official documents do not specifically attribute a documented operational role during Winter Storm Fern to the Schahfer or Culley units, beyond the DOE’s general characterisation of coal plants contributing to reliability. The original claim of essential Indiana plant support during the storm is not backed by plant-level evidence in the public record, and that distinction matters.

The system also held together without the failures the reliability narrative implies.

A FERC-NERC joint review found that despite the high level of unplanned outages, the bulk power system weathered Winter Storm Fern without significant reliability failures. Most customer outages were driven by distribution-system damage, not generation shortfalls.

Renewables carried more of the load than the coal-centric framing suggests. Wind and solar supplied 20-27% of electricity during peak MISO and SPP hours during the storm, reducing capacity need by nearly 9.5 GW. The DOE, for its part, stated that coal generation across impacted regions rose roughly 25% year-over-year during the period.

Coal generation during Winter Storm Fern did rise materially across the MISO and SPP footprint, and the plant-level data from that period is central to evaluating whether the DOE’s reliability justification holds for the specific Indiana units named in its orders.

Both things are true, and that is the point. The Midwest grid was genuinely stressed, but the specific contribution of these two Indiana plants to keeping it stable is less documented than the emergency orders imply. Before accepting the reliability rationale at face value, you should weigh that gap.

Legal blowback, ratepayer costs, and the Campbell ruling’s direct relevance

The sharpest immediate threat to the DOE’s strategy did not come from the market. It came from the courts, nine days before this renewal was issued.

The Campbell precedent: what the court actually ruled

On 11 September 2026, the D.C. Circuit Court of Appeals vacated a similar DOE emergency order keeping Michigan’s J.H. Campbell plant open. The parties included Michigan, Illinois, Minnesota, Earthjustice, and the Sierra Club, and the court ruled that the DOE “usurped state authority over generating resources.”

The court’s reasoning cut to the heart of the mechanism. Section 202(c), the judges found, was designed for short-term crisis response, not for managing long-term resource adequacy. Using it to delay planned retirements displaces state authority and the reliability framework the North American Electric Reliability Corporation (NERC) administers under Federal Power Act Section 215.

That same argument applies structurally to the Indiana orders. The legal theory being struck down is the identical Section 202(c) mechanism now applied again to Schahfer and Culley. Anyone relying on the DOE’s emergency framework to hold should understand it is being actively challenged, with opponents already holding an early win.

The Campbell ruling, handed down on 11 September 2026, is the most direct legal threat the DOE’s Indiana strategy now faces, and the D.C. Circuit’s reasoning tracks precisely the Section 202(c) mechanism being applied again to Schahfer and Culley.

Ratepayer costs and the economic case against coal retention

The economic critique is mounting alongside the legal one:

• According to a Sierra Club tracker, extending multiple coal plants under these DOE orders has cost Americans more than $547 million.
• A Congressional Research Service report found Section 202(c) was invoked 26 times between 2000 and February 2026 (12 weather-related), averaging roughly one invocation per year before 2025.
• Post-event reviews by the Institute for Energy Economics and Financial Analysis (IEEFA), covering Winter Storms Uri and Elliott, found coal and gas units accounted for the majority of forced outages during extreme weather, largely from frozen equipment and fuel supply failures.

That last finding undercuts the reliability-versus-retirement framing directly. MISO and PJM had previously concluded through their own analyses that plants targeted by the DOE could safely retire before the department overrode those conclusions.

For energy investors and grid stakeholders, the legal vulnerability of the mechanism is now material. A court has struck down one identical order, and the Indiana renewals are exposed to the same challenge.

The 40 GW campaign: what the broader coal preservation effort means for the energy transition

Indiana is not an isolated decision. It is one front in a nationwide policy wager on coal’s continued role in grid reliability.

The DOE’s use of Section 202(c) is not confined to the MISO footprint; emergency grid directives to PJM have been issued seven times in 2026 alone, establishing a cross-regional pattern of federal intervention that extends well beyond Indiana.

The Energy Department, in a 25 February 2026 fact sheet titled “Unleashing Beautiful, Clean Coal,” stated it had saved more than 17 GW of coal-powered electricity generation from going offline in 2025.

With subsequent announcements stretching into June 2026, the DOE said it will have saved or supported more than 40 GW of coal power across 45 plants, a total covering delayed retirements as well as modernisation and support projects.

The scale indicators tell the story of what the administration is countering:

• 17 GW of coal preserved in 2025 alone.
• More than 40 GW saved or supported across 45 plants through June 2026.
• Roughly 5.8 GW of coal retiring out of 8.6 GW of total retirements in the current NERC planning window.

The department’s justification rests on its own Resource Adequacy Report, which identifies premature retirement of dependable generation as a driver of both outage risk and higher consumer costs.

The 40 GW figure tells you this is a strategic bet on dispatchable thermal capacity, made in direct tension with market and legal forces pulling the other way. For investors in utilities, grid infrastructure, and clean energy, that posture creates uncertainty on both sides. Coal retirements may be delayed longer than integrated resource plans assume, while legal defeats could accelerate them unpredictably.

What the Indiana renewals settle, and what they leave open for winter 2026-2027

The new orders achieve one clear thing. Schahfer Units 17 and 18, a combined roughly 847 MW, and Culley Unit 2 are operationally committed through 18 December 2026, covering the highest-risk stretch of the winter demand curve in MISO North and Central, the regions the DOE identified as facing shortages.

Everything else is unresolved. Three variables will decide how this plays out:

1. Whether courts apply the 11 September 2026 Campbell ruling to the Indiana orders before December, given the identical legal theory at stake.
2. Whether MISO’s winter 2026-2027 reserve margins prove sufficient even with these plants running.
3. Whether the DOE issues a fifth renewal in December or allows the plants to finally retire.

The 18 December 2026 expiry date is not a conclusion. It is a checkpoint that forces the DOE, utilities, the courts, and MISO into a simultaneous decision at the start of winter, and what happens there will set the template for whether Section 202(c) coal policy holds or collapses.

If you are tracking the Midwest energy transition, treat that date as one to watch. It is a legal test, a grid reliability decision, and a signal about whether the administration’s coal preservation strategy can survive the Campbell precedent, all at once.

This article is for informational purposes only and should not be considered financial advice. Investors should conduct their own research and consult with financial professionals before making investment decisions. These statements are speculative and subject to change based on legal, market, and policy developments.