Indiana Administrative Code
Title 170 - INDIANA UTILITY REGULATORY COMMISSION
Article 4 - ELECTRIC UTILITIES
Rule 7 - Guidelines for Integrated Resource Planning by an Electric Utility
Section 7-6 - Description of available resources

Universal Citation: 170 IN Admin Code 7-6

Current through September 18, 2024

Authority: IC 8-1-1-3; IC 8-1-8.5-3

Affected: IC 8-1-8.5; IC 8-1.5

Sec. 6.

(a) In describing its existing electric power resources, the utility must include in its IRP the following information relevant to the twenty (20) year planning period being evaluated:

(1) The net and gross dependable generating capacity of the system and each generating unit.

(2) The expected changes to existing generating capacity, including the following:
(A) Retirements.

(B) Deratings.

(C) Plant life extensions.

(D) Repowering.

(E) Refurbishment.

(3) A fuel price forecast by generating unit.

(4) The significant environmental effects, including:
(A) air emissions;

(B) solid waste disposal;

(C) hazardous waste;

(D) subsequent disposal; and

(E) water consumption and discharge; at existing fossil fueled generating units.

(5) An analysis of the existing utility transmission system that includes the following:
(A) An evaluation of the adequacy to support load growth and expected power transfers.

(B) An evaluation of the supply-side resource potential of actions to reduce:
(i) transmission losses;

(ii) congestion; and

(iii) energy costs.

(C) An evaluation of the potential impact of demand-side resources on the transmission network.

(6) A discussion of demand-side resources and their estimated impact on the utility's historical and forecasted peak demand and energy.

The information listed in subdivisions (1) through (4) and in subdivision (6) shall be provided for each year of the future planning period.

(b) In describing possible alternative methods of meeting future demand for electric service, a utility must analyze the following resources as alternatives in meeting future electric service requirements:

(1) Rate design as a resource in meeting future electric service requirements.

(2) Demand-side resources. For potential demand-side resources, the utility shall include the following:
(A) A description of the potential demand-side resource, including its costs, characteristics, and parameters.

(B) The method by which the costs, characteristics, and other parameters of the demand-side resource are determined.

(C) The customer class or end-use, or both, affected by the demand-side resource.

(D) Estimated annual and lifetime energy (kWh) and demand (kW) savings.

(E) The estimated impact of a demand-side resource on the utility's load, generating capacity, and transmission and distribution requirements.

(F) Whether the program provides an opportunity for all ratepayers to participate, including low-income residential ratepayers.

(3) Supply-side resources. For potential supply-side resources, the utility shall include the following:
(A) Identification and description of the supply-side resource considered, including the following:
(i) Size in megawatts.

(ii) Utilized technology and fuel type.

(iii) Energy profile of nondispatchable resources.

(iv) Additional transmission facilities necessitated by the resource.

(B) A discussion of the utility's effort to coordinate planning, construction, and operation of the supply-side resource with other utilities to reduce cost.

(C) A description of significant environmental effects, including the following:
(i) Air emissions.

(ii) Solid waste disposal.

(iii) Hazardous waste and subsequent disposal.

(iv) Water consumption and discharge.

(4) Transmission facilities as resources. In analyzing transmission resources, the utility shall include the following:
(A) The type of the transmission resource, including whether the resource consists of one (1) of the following:
(i) New projects.

(ii) Upgrades to transmission facilities.

(iii) Efficiency improvements.

(iv) Smart grid technology.

(B) A description of the timing, types of expansion, and alternative options considered.

(C) The approximate cost of expected expansion and alteration of the transmission network.

(D) A description of how the IRP accounts for the value of new or upgraded transmission facilities increasing power transfer capability, thereby increasing the utilization of geographically constrained cost effective resources.

(E) A description of how:
(i) IRP data and information affect the planning and implementation processes of the RTO of which the utility is a member; and

(ii) RTO planning and implementation processes affect the IRP.

Disclaimer: These regulations may not be the most recent version. Indiana may have more current or accurate information. We make no warranties or guarantees about the accuracy, completeness, or adequacy of the information contained on this site or the information linked to on the state site. Please check official sources.
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