Managing C&I Load Flexibility: How DERMS Extends Beyond Residential DERs

Demand flexibility programs often start with the residential customer: distributed energy resources (DERs) like smart thermostats, water heaters, and rooftop solar aggregated into a single dispatchable resource. But the largest, most reliable megawatts often sit behind commercial and industrial (C&I) meters. Bringing those loads into a virtual power plant (VPP) requires a different set of capabilities than a residential program does — more complex telemetry, custom baselines, and integration with building and industrial control systems that were never designed to talk to a utility.

Fortunately, distributed energy resource management systems (DERMS) are built for scalability and designed to handle both customer classes. So, what utilities should look for as they expand demand-side programs into the C&I segment?

 

In This Article

• Why C&I load flexibility is different from residential demand response
• Where residential-first DERMS platforms hit limits with C&I sites
• The core capabilities a grid-edge DERMS needs to manage C&I resources
• The regulatory and market forces pushing utilities toward C&I flexibility
• Frequently asked questions
• A glossary of key terms

Why C&I Load Flexibility Looks Different

Residential demand response programs are built on volume: thousands of small, relatively homogeneous DER assets — thermostats, water heaters, EV chargers — aggregated to produce a meaningful load shape. C&I sites work in the opposite direction. A single facility can represent hundreds of kilowatts or several megawatts on its own, but that capacity comes wrapped in operational complexity:

• Diverse equipment. C&I sites might combine chillers, compressed air systems, industrial process loads, backup generation, battery storage, and fleet EV charging, each with its own controls and constraints.
• Custom load baselines. A home’s baseline is fairly predictable. A manufacturing facility’s baseline shifts with production schedules and order volume, so DERMS has to build and continually recalibrate site-specific baselines instead of applying a standard model.
• Operational and safety constraints. Curtailing a water heater is low-risk; curtailing a refrigeration system or a critical process carries real operational consequences, so dispatch logic needs facility-specific override rules and rate limits.
• Direct system integration. Many C&I sites already run building management systems (BMS), SCADA, or energy management systems (EMS). Extending into this segment means integrating with those systems, not replacing them with new customer-facing hardware.
• Concentrated value per site. Because each C&I site can deliver outsized capacity, utilities need more granular measurement and verification per participant than residential aggregate reporting requires.

According to the Federal Energy Regulatory Commission’s most recent Assessment of Demand Response and Advanced Metering, the industrial customer class alone accounted for roughly 45% of reported potential peak demand savings from retail demand response programs in 2023 — the largest share of any customer class — even though industrial customers represent a small fraction of total demand response participants. That concentration of capacity in relatively few accounts is exactly why C&I requires a more tailored operational approach than residential programs.

 

Where Residential-First Platforms Hit a Wall

Many demand-side platforms were built to solve residential aggregation first, then had C&I features added later. That approach tends to break down in a few predictable places:

• Device-count logic doesn’t translate. Systems designed around large numbers of identical, low-value devices often lack the flexibility to model a handful of high-value, highly variable industrial loads.
• Communication protocols diverge. Residential programs typically rely on consumer IoT and smart-device protocols. C&I sites more often communicate through BACnet, Modbus, OpenADR, or direct EMS/SCADA integrations that a residential-first platform may not natively support.
• Enrollment and incentive structures differ. C&I contracts frequently involve custom performance-based incentives, non-performance penalties, and negotiated curtailment windows that residential mass-enrollment workflows aren’t built to handle.
• Dispatch granularity matters more. A residential aggregation can absorb some imprecision because the pool is large. A C&I program dispatching a handful of large sites needs precise, auditable dispatch and settlement per account.

What a Grid-Edge DERMS Needs to Manage Both Segments

Extending demand flexibility into the C&I segment without duplicating platforms means the underlying DERMS needs to support a wider range of resource types and integration methods from a single operational layer. In practice, that includes:

• Protocol-agnostic integration with BMS, SCADA, EMS, and industrial control systems, alongside the consumer-facing device APIs used for residential programs.
• Flexible baselining that can model variable, production-driven load patterns rather than only relying on standard residential baseline methodologies.
• Granular, per-site dispatch controls that respect operational limits (minimum runtimes, ramp rates, safety overrides) defined by facility operators.
• Unified visibility across residential, commercial, and industrial resources in one system, so utility program managers aren’t reconciling data between separate residential and C&I tools.
• Measurement and verification workflows suited to performance-based and negotiated C&I contracts, not just program-level aggregate reporting.
• Locational and program-level segmentation, so C&I capacity can be dispatched independently, in combination with residential resources, or targeted to specific feeders or substations experiencing localized stress.

The Regulatory & Market Case For C&I Flexibility

In some instances, utilities aren’t extending programs into C&I purely for operational reasons — market and regulatory conditions are pushing the same way:

• FERC Order No. 2222 directs regional transmission organizations and independent system operators to let DERs, including demand response and storage, participate in wholesale markets through aggregations. FERC’s Order No. 2222 fact sheet describes the rule as removing barriers to DERs competing on a level playing field with traditional resources in capacity, energy, and ancillary services markets — a framework that treats C&I-scale aggregations the same as any other DER pool.
• Industrial and commercial demand growth is accelerating. The EIA’s outlook projected industrial electricity demand growing faster than other sectors, driven partly by new manufacturing activity, with commercial demand also rising as data-center power consumption increases. Rising baseline demand in these sectors increases the value of flexing load within them.
• Concentrated capacity means concentrated value. Because a comparatively small number of C&I accounts can deliver a large share of potential peak savings, utilities can often unlock meaningful capacity by focusing integration effort on fewer, larger sites rather than scaling residential enrollment alone.

C&I flexibility isn’t a niche add-on to residential demand response — it’s becoming core to how utilities plan for peak load, grid congestion, and capacity procurement. Likewise, C&I programs can help inform how utilities manage increasingly complex DER portfolios, which is needed for programmatic scalability; the more devices available, the broader the customer access.

 

FAQ

Is C&I demand response the same thing as a virtual power plant? Close, but not exactly. Demand response is one mechanism: reducing or shifting load during specific events. A virtual power plant is broader — it aggregates and coordinates multiple DER types, including C&I load flexibility, storage, and generation, to act like a single dispatchable power plant.

Can one Grid-Edge DERMS manage both residential and C&I resources? Yes, if the platform is protocol-agnostic and supports flexible baselining and dispatch logic. Managing both segments on one system gives program managers a single view of total flexible capacity instead of reconciling separate tools.

What makes C&I sites harder to onboard than residential devices? Mainly integration complexity and operational risk. C&I sites often require direct integration with existing BMS, SCADA, or EMS infrastructure, and curtailment strategies must respect equipment and safety constraints that don’t apply to residential devices like thermostats.

Do C&I customers get compensated differently than residential participants? Often, yes. C&I contracts more commonly use negotiated, performance-based incentives tied to measured and verified load reduction, rather than the flat or event-based incentives typical of residential programs.

How does FERC Order 2222 affect C&I load flexibility? It requires RTOs and ISOs to let DER aggregations, which can include C&I demand response and storage, participate directly in wholesale energy, capacity, and ancillary services markets, expanding the revenue potential of aggregated C&I flexibility.

 

Glossary of key terms

• Demand response (DR): A program where customers reduce or shift electricity use during specific periods, typically in exchange for an incentive.
• Distributed energy resource (DER): A small-scale generation, storage, or load-management resource located on the distribution grid or behind a customer meter, such as batteries, solar, or smart thermostats.
• Distributed energy resource management system (DERMS): Software that monitors, controls, and dispatches distributed energy resources to meet grid or program objectives.
• Virtual power plant (VPP): An aggregation of distributed energy resources — residential, commercial, and industrial — coordinated to act collectively as a single, dispatchable capacity resource.
• Baseline: The estimated electricity usage a customer would have had without a demand response event, used to measure and verify curtailment performance.
• Aggregation: The grouping of multiple DERs so their combined capacity can participate in a program or market as a single resource.
• FERC Order No. 2222: A 2020 Federal Energy Regulatory Commission rule requiring RTOs and ISOs to allow DER aggregations to participate in wholesale electricity markets.

Bringing Residential & C&I Flexibility Into One Strategy

C&I load flexibility isn’t a smaller version of residential demand response — it’s a different operational problem that happens to feed the same goal: a more flexible, resilient grid. Utilities that treat it that way, with integration paths built for industrial and commercial complexity rather than retrofitted from residential tools, are better positioned to unlock the capacity that FERC’s own data shows is concentrated in these accounts.

To go deeper on related topics, see how Grid-Edge DERMS can unify resource types, how utilities are approaching C&I resource management alongside residential DERs, and how demand flexibility program design is evolving to accommodate a wider mix of participants.