(a)  The following policies regarding net metering of electricity from eligible net-metering systems and community remote net-metering systems and regarding any person that is a renewable self-generator shall apply:

(1)(i)  The maximum allowable capacity for eligible net-metering systems, based on nameplate capacity, shall be ten megawatts (10 MW).

(ii)  Eligible net-metering systems shall be sited outside of core forests with the exception of development on preferred sites in the core forest and the exception of systems that, as of April 15, 2023, (A) Have submitted a complete application to the appropriate municipality for any required permits and/or zoning changes, or (B) Have requested an interconnection study for which payment has been received by the distribution company, or (C) If an interconnection study is not required, systems that have a completed and paid interconnection application.

(iii)  For systems developed in core forests on preferred sites, no more than one hundred thousand square feet (100,000 sq. ft) of core forest shall be removed, including for work required for utility interconnection or development of a brownfield, in which case no more core forest than necessary for interconnection or brownfield development shall be removed.

(iv)  The aggregate amount of net metering in the Block Island Utility District doing business as Block Island Power Company and the Pascoag Utility District shall not exceed a maximum percentage of peak load for each utility district as set by the utility district based on its operational characteristics, subject to commission approval.

(v)  Through December 31, 2018, the maximum aggregate amount of community remote net-metering systems built shall be thirty megawatts (30 MW). Any of the unused MW amount after December 31, 2018, shall remain available to community remote net-metering systems until the MW aggregate amount is interconnected.

(vi)  The maximum aggregate capacity of remote net metering allowable for ground-mounted eligible net-metering systems, as defined by § 39-26.4-2(6), with the exception of systems that have, as of April 15, 2023, submitted a complete application to the appropriate municipality for any required permits and/or zoning changes or have requested an interconnection study for which payment has been received by the distribution company, or if an interconnection study is not required, a completed and paid interconnection application by the distribution company date of passage, shall be two hundred seventy-five megawatts, alternating current (275 MWac), excluding off-shore wind. None of the systems to which this cap applies shall be in core forests unless on a preferred site located within the core forest. A project counts against this maximum if it is in operation or under construction by July 1, 2030, as determined by the local distribution company. All eligible ground-mounted net-metering systems must be under construction or in operation by July 1, 2030. This restriction shall not apply to the following: (A) The eligible net-metering system is interconnected behind the same meter as the net-metering customer‘s load; and/or (B) The energy generated by the eligible net-metering system is consumed by net-metered electric service account(s) of the same owner of record that are actually located on the same or contiguous parcels as the eligible net-metering system.

(2)  For ease of administering net-metered accounts and stabilizing net-metered account bills, the electric distribution company may elect (but is not required) to estimate for any twelve-month (12) period:

(i)  The production from the eligible net-metering system or community remote net-metering system; and

(ii)  Aggregate consumption of the net-metered accounts at the eligible net-metering system site or the sum of the consumption of the eligible credit-recipient accounts associated with the community remote net-metering system, and establish a monthly billing plan that reflects the expected credits that would be applied to the net-metered accounts over twelve (12) months. The billing plan would be designed to even out monthly billings over twelve (12) months, regardless of actual production and usage. If such election is made by the electric distribution company, the electric distribution company would reconcile payments and credits under the billing plan to actual production and consumption at the end of the twelve-month (12) period and apply any credits or charges to the net-metered accounts for any positive or negative difference, as applicable. Should there be a material change in circumstances at the eligible net-metering system site or associated accounts during the twelve-month (12) period, the estimates and credits may be adjusted by the electric distribution company during the reconciliation period. The electric distribution company also may elect (but is not required) to issue checks to any net-metering customer in lieu of billing credits or carry-forward credits or charges to the next billing period. For residential-eligible net-metering systems and community remote net-metering systems twenty-five kilowatts (25 KW) or smaller, the electric distribution company, at its option, may administer renewable net-metering credits month to month allowing unused credits to carry forward into the following billing period.

(3)  If the electricity generated by an eligible net-metering system or community remote net-metering system during a billing period is equal to, or less than, the net-metering customer’s usage at the eligible net-metering system site or the sum of the usage of the eligible credit-recipient accounts associated with the community remote net-metering system during the billing period, the customer shall receive renewable net-metering credits, that shall be applied to offset the net-metering customer’s usage on accounts at the eligible net-metering system site, or shall be used to credit the eligible credit-recipient’s electric account.

(4)  If the electricity generated by an eligible net-metering system or community remote net-metering system during a billing period is greater than the net-metering customer’s usage on accounts at the eligible net-metering system site or the sum of the usage of the eligible credit-recipient accounts associated with the community remote net-metering system during the billing period, the customer shall be paid by excess renewable net-metering credits for the excess electricity generated up to an additional twenty-five percent (25%) beyond the net-metering customer’s usage at the eligible net-metering system site, or the sum of the usage of the eligible credit-recipient accounts associated with the community remote net-metering system during the billing period; unless the electric distribution company and net-metering customer have agreed to a billing plan pursuant to subsection (a)(2).

(5)  The rates applicable to any net-metered account shall be the same as those that apply to the rate classification that would be applicable to such account in the absence of net metering, including customer and demand charges, and no other charges may be imposed to offset net-metering credits.

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(b)  The commission shall exempt electric distribution company customer accounts associated with an eligible net-metering system from back-up or standby rates commensurate with the size of the eligible net-metering system, provided that any revenue shortfall caused by any such exemption shall be fully recovered by the electric distribution company through rates.

(c)  Any prudent and reasonable costs incurred by the electric distribution company pursuant to achieving compliance with subsection (a) and the annual amount of any renewable net-metering credits or excess renewable net-metering credits provided to accounts associated with eligible net-metering systems or community remote net-metering systems, shall be aggregated by the distribution company and billed to all distribution customers on an annual basis through a uniform, per-kilowatt-hour (KWh) surcharge embedded in the distribution component of the rates reflected on customer bills.

(d)  The billing process set out in this section shall be applicable to electric distribution companies thirty (30) days after the enactment of this chapter.

(e)  The Rhode Island office of energy resources shall redesign the community solar remote net metering program to reflect the provisions of this chapter and to include a commercial or industrial anchor tenant up to but not to exceed fifty percent (50%) of the project. The remaining fifty percent (50%) must be allocated or subscribed to low- and moderate-income (LMI) residents and/or those living in areas defined as disadvantaged and environmental justice communities. The Rhode Island office of energy resources shall design the net metering credit rate and factor in federal energy funding and tax credits to develop the most cost-effective rate for community solar projects. It is expected that these projects will be operational for a twenty-year (20) period. The Rhode Island office of energy resources shall file a benefit and cost analysis with any program proposal filed to the Rhode Island public utilities commission. Once the Rhode Island office of energy resources files a program proposal to the Rhode Island public utilities commission, a docket shall be established, and the Rhode Island public utilities commission shall issue a ruling on the program no later than one hundred and fifty (150) days. If a program is approved, it will be subject to no greater than twenty megawatts (20 MW) per year for two years until the forty megawatts (40 MW) cap is met. Eligible net-metering systems shall be sited outside of core forests with the exception of development on preferred sites in the core forest.