Consumers Energy C&I demand response and battery economics

Consumers Energy serves businesses under secondary (GSD) and primary (GPD) demand rates set in the MPSC-approved rate book. It holds its customers’ capacity in MISO Zone 7 and passes market value back through programs, not market access. The MPSC approves the rates and the IRP that decides how much capacity comes from customers.

Every deep dive on this site has one feature that changes how its economics read. For a Consumers Energy business it is when a kilowatt counts. GSD bills a peak demand charge of $24.27 per kW-month in summer and $19.06 in winter, plus a $1.00 capacity delivery charge, and the billed peak is never less than 60% of the highest June–September peak (rate book D, sheets D-45 to D-52). A site with a sharp summer air-conditioning peak pays for it all winter.

The wholesale market has the same shape. MISO’s 2026 auction for June 2026 to May 2027 cleared summer capacity at $424.3 per MW-day in Zones 1–7, against $33.92 in fall, $35.97 in winter and $7.61 in spring (MISO auction release); the annualized price was $126.19 (IURC summary of the MISO auction). Consumers’ Demand Response pays more than twice as much per kW for summer as for any other season (C&I Demand Response page).

C&I Demand Response pays for kW pledged, whether or not an event is called. Events run 11 a.m. to 7 p.m. on weekdays, no more than five in summer and winter and three in fall and spring, and an energy solutions manager writes a reduction plan with each site (program overview). Paid participation reached $9.5 million in 2025. A separate bill-credit page describes $25 per kW on a one-year contract plus 5¢ per kWh for extra reductions (bill credit terms); confirm which schedule applies in a given year.

Large primary customers can take interruptible service instead, with credits of $8.50 per kW-month in summer and $7.50 in winter (MPSC tariff filing). Business PowerMIDrive pays up to $7,500 for Level 2 workplace charging and $70,000 for DC fast charging (business EV support).

Stacking here means combining the bill, Demand Response and the federal credit. Businesses do not sell to MISO directly; the utility carries their capacity.

Stacking needs care, depending on M&V methodology. Demand Response measures event reductions against a site baseline, while the demand charge is the raw monthly peak. A battery that already flattens the site’s afternoon load lowers its own event baseline, so the pledge should count only what it can add on an event day.

Shaving the peak every month is worth about $262 per kW-year, roughly six times the Demand Response pay. The program matters as a second stream on the same battery, not as the reason to buy one.

The site’s line above is only half of the deal. The developer pays the full $240k, carries maintenance, insurance and performance risk, and prices all of it into the contract to earn a return on its capital (Morgan Lewis). Third-party storage contracts usually run 15 years or more (Peak Power), and lenders treat 15- to 20-year terms as financeable (Illinois Power Agency). The chart below values each deal from the developer’s side.

With 25% of savings left to the site, a 15-year deal covers about 73% of the developer’s cost on our model. At the modeled cost, a developer cannot earn 8% and still leave the site a share of demand savings. Battery-service offers are not priced the other way around, as a fee on top of handing over the savings: shared-savings providers promote a guaranteed share from day one (Gridwealth Electric), and Peak Power’s projects in Westchester, New York, split bill savings and market revenue with the building owner (NYSERDA case study). A deal that cannot fund a share is usually not offered at all. A guaranteed 15% share would need an installed cost about 43% lower, near $137k, or a larger site where cost per kWh falls; providers such as Peak Power focus on facilities with more than 1 MW of load (Peak Power’s overview). The battery-service line above shows that 15% share. Michigan’s winter demand charge does much of the work: a battery that only shaved summer peaks would fall well short.

The 2026 IRP targets 3,500 MW of VPP capability and 3,300 MW of new storage by 2040 (SEPA policy tracker), and the MPSC’s March order makes customer resources part of how future investments are judged (Renewable Energy World). For businesses, the open question is whether Demand Response grows into a program that dispatches batteries daily rather than calling a few events a season.

The future of VPP to grow at scale will depend on multiple assets in unison at any given site: building controls, refrigeration, EV charging and batteries, dispatched together. For Michigan businesses, the next steps are battery rules in Demand Response and a summer value that reflects MISO’s seasonal prices.

Compare: the Consumers Energy residential deep dive, the Ameren Missouri C&I deep dive for another MISO utility, and the ComEd C&I deep dive for PJM.