Free Market Energy Act

To facilitate the free market for distributed energy resources. 1. Short title This Act may be cited as the Free Market Energy Act 2. Definition of distributed energy resource Section 3 of the Federal Power Act ( 16 U.S.C. 796 (30) Distributed energy resource The term distributed energy resource . 3. General right to neutrality of interconnection The Public Utility Regulatory Policies Act of 1978 is amended by inserting after section 4 ( 16 U.S.C. 2603 5. General right to neutrality of interconnection (a) In general Distributed energy resources (as defined in section 3 of the Federal Power Act ( 16 U.S.C. 796 (b) Rates and fees States shall ensure that electric distribution grid operators adopt standards, conditions, and requirements for rates and fees for interconnection of distributed energy resources under this Act, that— (1) are just and reasonable; (2) provide for the 2-way benefit for the distributed energy resource and the electricity grid; and (3) shall not be punitive. (c) Timeframes (1) In general Timeframes for interconnection of distributed energy resources under this Act shall be well-defined, expeditious, and not unduly protracted. (2) Delays or denial An interconnection of distributed energy resources under this Act shall not be delayed or denied unless the electric utility demonstrates that the interconnection is unsafe or impracticable. . 4. Energy and rate treatments for distributed energy resources Section 111(d) of the Public Utility Regulatory Policies Act of 1978 ( 16 U.S.C. 2621(d) (20) Distributed energy resources (A) In general If a State regulatory authority considers, through a rate proceeding or another mechanism (such as consideration of fixed or minimum charges), modifying the treatment of net energy metering customers, the State regulatory authority shall consider requiring that distributed energy resources (as defined in section 3 of the Federal Power Act ( 16 U.S.C. 796 (B) Considerations The considerations for the use of dynamic pricing referred to in subparagraph (A) include— (i) (I) pricing for energy sold to an electric utility; and (II) pricing for energy purchased from an electric utility; (ii) capacity; (iii) the provision of ancillary services; (iv) the societal value of distributed energy resources; (v) transmission and distribution losses; and (vi) any other benefits that the State regulatory authority considers to be appropriate. . 5. Consideration of nontransmission alternatives Section 111(d) of the Public Utility Regulatory Policies Act of 1978 ( 16 U.S.C. 2621(d) (21) Nontransmission alternatives (A) In general Each State regulatory authority or applicable Regional Transmission Organization or Independent System Operator shall consider nontransmission alternatives in instances in which an entity proposes transmission projects seeking cost-of-service rate recovery. (B) Cost To reduce the cost to the ratepayer of a potential transmission upgrade, a nontransmission alternative considered under subparagraph (A), the cost of the nontransmission alternative shall be recovered from the ratebase or regional recovery mechanism in the same manner as the transmission upgrade would have been. . 6. Prior state actions (a) In general Section 112 of the Public Utility Regulatory Policies Act of 1978 ( 16 U.S.C. 2622 (g) Prior state actions Subsections (b) and (c) shall not apply to a standard established under paragraphs (20) and (21) of section 111(d) in the case of any electric utility in a State if, before the date of enactment of this subsection— (1) the State has implemented for the electric utility the standard (or a comparable standard); (2) the State regulatory authority for the State, or the relevant nonregulated electric utility, has conducted a proceeding to consider implementation of the standard (or a comparable standard) for the electric utility; or (3) the State legislature has voted on the implementation of the standard (or a comparable standard) for the electric utility. . (b) Cross-Reference Section 124 of the Public Utility Regulatory Policies Act of 1978 ( 16 U.S.C. 2634 In the case of each standard established under paragraphs (20) and (21) of section 111(d), the reference contained in this subsection to the date of enactment of this Act shall be deemed to be a reference to the date of enactment of those paragraphs. 7. Effect Nothing in this Act (or an amendment made by this Act) shall apply to distributed energy resource contracts in effect on the date of enactment of this Act.

Summary: Free Market Energy Act This bill amends: (1) the Federal Power Act to define &quot;distributed energy resource&quot; as a resource, technology, or service interconnected to the electricity distribution system that generates, manages, or reduces energy use; and (2) the Public Utility Regulatory Policies Act of 1978 to provide that distributed energy resources shall have a general right of interconnection under such Act. States must ensure that electric distribution grid operators adopt requirements for interconnection rates and fees that are just and reasonable, that provide for the two-way benefit for the distributed energy resource and the electricity grid, and that are not punitive. Time frames for interconnection shall be well-defined, expeditious, and not unduly protracted. An interconnection may not be delayed or denied unless the electric utility demonstrates that the interconnection is unsafe or impracticable. A state regulatory authority that considers modifying the treatment of net energy metering customers must consider requiring that distributed energy resources be eligible to receive just and reasonable energy and rate treatment using dynamic pricing, which may account for locational benefit, to be provided on an unbundled basis, after accounting for the two-way valuation of dynamic rates, for services provided to or by the grid. Dynamic pricing considerations shall include: pricing for energy sold to, and pricing for energy purchased from, an electric utility, capacity, the provision of ancillary services, the societal value of distributed energy resources, and transmission and distribution losses. A state regulatory authority or applicable Regional Transmission Organization or Independent System Operator must consider nontransmission alternatives in instances in which an entity proposes transmission projects seeking cost-of-service rate recovery. To reduce the cost to the ratepayer of a potential transmission upgrade, the cost of the nontransmission alternative shall be recovered from the ratebase or regional recovery mechanism in the same manner as the transmission upgrade otherwise would have been.