Smart Meter Integration with EV Charging in Indiana

Smart meter integration with EV charging combines advanced metering infrastructure (AMI) with residential and commercial charging equipment to enable data-driven load management, time-of-use billing, and grid-responsive charging behavior. This page covers how AMI systems communicate with EV supply equipment (EVSE) in Indiana, the regulatory and utility framework governing that interaction, and the decision points that determine whether integration is technically feasible or contractually required at a given site. Understanding this integration is essential for anyone assessing Indiana electric utility EV programs or evaluating the electrical design of a new charging installation.

Definition and scope

A smart meter, in the context of utility infrastructure, is an advanced metering infrastructure device that records electricity consumption at short intervals — typically 15 or 60 minutes — and transmits that data bidirectionally between the utility and the customer premises. Indiana's two largest investor-owned utilities, Indianapolis Power & Light (now AES Indiana) and Duke Energy Indiana, have completed AMI rollouts across their service territories, with the Indiana Utility Regulatory Commission (IURC) providing regulatory oversight of those deployments under Indiana Code Title 8, Article 1.

Smart meter integration with EV charging means that the metering device and the EVSE — or a home energy management system (HEMS) bridging the two — exchange data or control signals that can shift, throttle, or schedule charging based on grid conditions, time-of-use (TOU) pricing windows, or demand response event triggers. This is distinct from simple interval metering, where the meter records usage passively without influencing charger behavior.

Scope of this page: Coverage applies to Indiana residential, commercial, and light-industrial sites within AES Indiana, Duke Energy Indiana, Indiana Michigan Power, and Vectren (now CenterPoint Energy Indiana) service territories. Federal bulk-power grid regulation by the Federal Energy Regulatory Commission (FERC) and NERC reliability standards operate above the utility-customer interface and are not addressed here. Vehicle-to-grid (V2G) bidirectional export scenarios are treated separately at Vehicle-to-Grid Electrical in Indiana.

How it works

The integration architecture involves at least 3 distinct layers:

  1. Meter layer — The AMI meter records interval consumption data and communicates with the utility head-end system via radio frequency (RF) mesh, power line carrier, or cellular backhaul. AES Indiana's AMI deployment, which covers approximately 500,000 meters in central Indiana (per AES Indiana's IURC-filed AMI deployment reports), uses RF mesh technology.

  2. EVSE layer — A smart EVSE (Level 2, SAE J1772-compliant or DC fast charger with OCPP support) exposes a network interface — Wi-Fi, Zigbee, Z-Wave, or Ethernet — that accepts scheduling commands or responds to demand response signals. The Open Charge Point Protocol (OCPP), maintained by the Open Charge Alliance, is the dominant standard for back-end communication in commercial deployments.

  3. Control layer — A utility demand response platform, a HEMS, or a third-party aggregator (operating under FERC Order 2222 frameworks) mediates between the meter data and the EVSE control interface. This layer may use the OpenADR 2.0 protocol, published by the OpenADR Alliance, which standardizes automated demand response signals.

The charging session lifecycle under integration follows a structured sequence:

  1. Customer enrolls in a utility TOU rate or demand response program.
  2. The utility's AMI system or a HEMS retrieves pricing or event signals from the utility's head-end.
  3. The control layer translates those signals into EVSE scheduling commands.
  4. The EVSE delays, throttles, or permits charging based on the command.
  5. Interval consumption data flows back to the meter for billing settlement.

NEC Article 625 governs EV charging equipment wiring at the premises level; Article 220 load calculation methods apply when determining whether smart-managed EV loads qualify for demand factor reductions. A broader discussion of applicable code articles appears in NEC Code Compliance for EV Chargers in Indiana.

Common scenarios

Residential TOU rate integration is the most prevalent use case. A customer subscribes to Duke Energy Indiana's or AES Indiana's time-of-use rate structure, which prices off-peak hours (typically 9 p.m. to 9 a.m.) at a lower rate than on-peak periods. The smart EVSE — using a built-in scheduler or a HEMS — delays charging start until the off-peak window opens. The AMI meter records consumption in the correct rate period for billing. No dedicated communication channel between meter and EVSE is required; the scheduling is managed at the EVSE or HEMS level using pre-programmed price windows. Time-of-use rates for EV charging in Indiana covers the rate design structure in detail.

Utility demand response enrollment involves the utility sending a curtailment signal during grid stress events. The EVSE — if OpenADR-compatible — receives the signal via a virtual end node (VEN) installed on the customer's gateway device and reduces charging output or suspends the session for the event duration. Duke Energy Indiana has operated demand response programs under IURC-approved tariffs; enrollment eligibility and signal protocols vary by program cycle.

Subpanel-level load management applies in multifamily and commercial settings where a single service feeds multiple EVSEs. A load management controller monitors the AMI meter's real-time consumption feed (where the utility provides a data access API or a secondary CT-based local signal) and distributes available capacity across chargers. This scenario intersects with EV Charging Load Management in Indiana and requires careful panel and feeder sizing as described in Load Calculation for EV Charging in Indiana.

Solar-plus-EV integration uses smart meter net-metering data alongside inverter production data to route excess photovoltaic generation into EV charging before export. This topology is covered in Solar Integration for EV Chargers in Indiana.

Decision boundaries

Type A: Passive scheduling (no meter-EVSE communication)
The EVSE operates on a pre-programmed timer without receiving live utility signals. The AMI meter records consumption in the appropriate TOU window, but no data channel exists between meter and charger. This configuration works for customers on flat TOU schedules but cannot respond dynamically to real-time pricing or demand response events.

Type B: HEMS-mediated integration
A home energy management system pulls interval data from the utility's customer-facing API (such as Green Button Connect, supported by utilities participating in the Green Button Alliance), then passes scheduling signals to the EVSE. This adds one integration layer but requires no direct meter-to-EVSE communication hardware.

Type C: Direct utility-to-EVSE demand response
The EVSE is enrolled as a controllable load in the utility's demand response platform. The utility sends OpenADR signals directly to the customer's VEN. This requires EVSE OpenADR 2.0 compatibility and utility program enrollment. Commercial installations seeking this capability must confirm program availability with the serving utility's interconnection and demand response departments — see Indiana Utility Interconnection for EV Charging for interconnection context.

Permitting implications: Smart meter integration does not alter the EVSE's physical electrical installation permit requirements. The EV charger still requires a permit under the Indiana Department of Homeland Security (IDHS) electrical inspection program, and the circuit must meet NEC Article 625 and applicable load calculation requirements. Integration software and communication equipment installed on the customer side of the meter are generally not separately permitted as electrical equipment, but any modifications to metering equipment on the utility side of the meter are exclusively within the utility's jurisdiction. A full permitting and inspection overview is at EV Charger Electrical Inspection in Indiana.

The conceptual overview of Indiana electrical systems provides foundational grounding for understanding how smart meter integration sits within the broader electrical service architecture. The regulatory context for Indiana electrical systems details the IURC, IDHS, and NEC adoption framework that governs both the utility-side and premises-side components involved in this integration. For a broad orientation to EV charging electrical topics across Indiana, the Indiana EV Charger Authority index organizes the full scope of coverage.

References

📜 3 regulatory citations referenced  ·  ✅ Citations verified Feb 28, 2026  ·  View update log

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