Net Metering

March 21, 2023

Summary

Note: In April 2021, the Indiana Utility Regulatory Commission approved a proposal from CenterPoint South (formerly Vectren, Southern Indiana Gas & Electric Company) for a new distributed generation rate under the framework established by S.B. 309. The new rate uses a net billing system with instantaneous netting, with exported electricity compensated at 1.25* the locational marginal price (LMP) at Vectren's load node. As of March 2023, AES Indiana, NIPSCO, and Duke Energy Indiana have filed updated tariffs with similar structures.

Note: Senate Bill 309, signed into law in May 2017, makes important changes to Indiana's compensation system for distributed generation, including an eventual phaseout of retail rate net metering (to occur by July 1, 2022, or when individual utilities reach 1.5% peak summer load caps, whichever is earlier). Current net metering customers and customers who enter into net metering contracts before December 2017 will be able to continue their existing contracts until July 1, 2047, and customers who sign up before the earlier of July 1, 2022 or their utility reaching a 1.5% peak summer load cap, can continue net metering until July 1, 2032.

The Indiana Utility Regulatory Commission (IURC) adopted rules for net metering in September 2004, requiring the state's investor-owned utilities (IOUs) to offer net metering to all electric customers. 

Eligible Resources and System Size

Facilities with a maximum capacity of 1 megawatt (MW) are eligible for net metering. Eligible net metering energy resources include wind, solar, hydro, fuel cells, hydrogen, organic waste biomass and dedicated crops powered generation.

Aggregate Cap

A utility may limit the aggregate amount of net-metering nameplate capacity to 1% of its most recent summer peak load.  Nameplate capacity for inverter-based net metering facilities is defined as "the aggregate output rating of all inverters in the facility, measured in kW." At least 40% of a utility's net metering capacity must be residential customers.  

IOUs may choose to offer larger net metering capacity limits.

Net Excess Generation (NEG)

NEG during a billing period is credited to the customer's next monthly bill in the form of a kilowatt-hour (kWh) credit at the retail rate. NEG credits rollover indefinitely. If a customer elects to cease net metering, any unused credit will revert to the utility.

Excess Distributed Generation (EDG)

EDG rates are successors to the NEG calculations. EDG uses an instantaneous netting period to calculate the excess generation over the course of a billing month. Excess generation is credited at 125% of the wholesale electricity cost for each utility.

Interconnection

An interconnection agreement between the utility and the customer must be executed before the facility may be interconnected. Net-metered systems must comply with Indiana's interconnection standards (170 IAC 4-4.3).

Metering

Either a single meter or a dual-meter arrangement may be used. Utilities may not charge customers any fees for additional metering for single-phase configurations installed by the utility, for customers' requests to net meter, or for an initial net-metering facility inspection.

Insurance

Net metering customers must maintain homeowners, commercial, or other insurance providing coverage of at least $100,000 against loss arising out of the use of a net metered facility. Utilities may not require additional liability insurance in excess of this limit.

Reporting

The IURC's 2014 net metering report is available here.

Program Overview

Implementing Sector: State
Category: Regulatory Policy
State: Indiana
Incentive Type: Net Metering
Web Site: https://www.in.gov/iurc/news-and-notices/newsroom/2017-technical-conference-addressing-questions-re-implementation-of-net-metering-legislation-sea-309/net-metering-resource-page/
Administrator:
Start Date:
Eligible Renewable/Other Technologies:
  • Solar Thermal Electric
  • Solar Photovoltaics
  • Wind (All)
  • Biomass
  • Hydroelectric
  • Hydrogen
  • Fuel Cells using Non-Renewable Fuels
  • Wind (Small)
  • Hydroelectric (Small)
  • Fuel Cells using Renewable Fuels
Applicable Utilities: Investor-owned utilities
System Capacity Limit: 1 MW
Aggregate Capacity Limit: 1.5% of utility's most recent peak summer load (new DG compensation mechanism after this is reached)
Net Excess Generation: Determined by instantaneous comparison of generation and consumption. Excess kWh credited at 125% of avoided cost.
Ownership of Renewable Energy Credits: Not addressed
Meter Aggregation: Not addressed

Authorities

Name: 170 IAC 4-4.2
Date Enacted: 9/8/2004
Effective Date: 10/22/2004
Name: RM #09-10 LSA #10-662
Date Enacted: 05/11/2011
Effective Date: 07/13/2011
Name: S.B. 309
Date Enacted: 05/02/2017
Effective Date: 07/01/2017

Contact

Name: Brad Borum
Organization: Indiana Utility Regulatory Commission
Address: 101 West Washington Street, Suite 1500E
Indianapolis IN 46204
Phone: (317) 232-2304
Email: bborum@urc.in.gov

This information is sourced from DSIRE; the most comprehensive source of information on incentives and policies that support renewables and energy efficiency in the United States. Established in 1995, DSIRE is operated by the N.C. Clean Energy Technology Center at N.C. State University.