law23300

Chapter 300

2023 -- H 5853 SUBSTITUTE A
Enacted 06/24/2023

A N A C T

RELATING TO PUBLIC UTILITIES AND CARRIERS -- NET METERING

Introduced By: Representatives Speakman, Boylan, Ajello, McGaw, Donovan, Tanzi, Cortvriend, Knight, Kislak, and Potter

Date Introduced: March 01, 2023

It is enacted by the General Assembly as follows:

SECTION 1. Sections 39-26.4-1, 39-26.4-2 and 39-26.4-3 of the General Laws in Chapter

39-26.4 entitled "Net Metering" are hereby amended to read as follows:

39-26.4-1. Purpose.

The purpose of this chapter is to facilitate and promote installation of customer-sited, grid-

connected generation of renewable energy; to support and encourage customer development of

renewable generation systems; to reduce environmental and siting impacts; to reduce carbon

emissions that contribute to climate change by encouraging the local siting of renewable energy

projects; to diversify the state’s energy generation sources; to stimulate economic development; to

improve distribution system resilience and reliability; and to reduce distribution system costs.

39-26.4-2. Definitions.

Terms not defined in this section herein shall have the same meaning as contained in

chapter 26 of this title. When used in this chapter:

(1) “Community remote net-metering system” means a facility generating electricity using

an eligible net-metering resource that allocates net-metering credits to a minimum of one account

for a system associated with low- or moderate-income housing eligible credit recipients, or three

(3) eligible credit-recipient customer accounts, provided that no more than fifty percent (50%) of

the credits produced by the system are allocated to one eligible credit recipient, and provided further

at least fifty percent (50%) of the credits produced by the system are allocated to the remaining

eligible credit recipients in an amount not to exceed that which is produced annually by twenty-

five kilowatt (25 KW) AC capacity. The community remote net-metering system may transfer

credits to eligible credit recipients in an amount that is equal to or less than the sum of the usage of

the eligible credit recipient accounts measured by the three-year (3) average annual consumption

of energy over the previous three (3) years. A projected annual consumption of energy may be used

until the actual three-year (3) average annual consumption of energy over the previous three (3)

years at the eligible credit recipient accounts becomes available for use in determining eligibility

of the generating system. The community remote net-metering system may be owned by the same

entity that is the customer of record on the net-metered account or may be owned by a third party.

(2) “Core forest” refers to unfragmented forest blocks of single or multiple parcels totaling two

hundred fifty (250) acres or greater unbroken by development and at least twenty-five (25) yards

from mapped roads, with eligibility questions to be resolved by the director of the department of

environmental management. Such determination shall constitute a contested case as defined in §

42-35-1(5).

(2)(3) “Electric distribution company” shall have the same meaning as § 39-1-2, but shall

not include Block Island Power Company or Pascoag Utility District, each of whom shall be

required to offer net metering to customers through a tariff approved by the public utilities

commission after a public hearing. Any tariff or policy on file with the public utilities commission

on the date of passage of this chapter shall remain in effect until the commission approves a new

tariff.

(3)(4) “Eligible credit recipient” means one of the following eligible recipients in the

electric distribution company’s service territory whose electric service account or accounts may

receive net-metering credits from a community remote net-metering system. Eligible credit

recipients include the following definitions:

(i) Residential accounts in good standing.

(ii) “Low- or moderate-income housing eligible credit recipient” means an electric service

account or accounts in good standing associated with any housing development or developments

owned or operated by a public agency, nonprofit organization, limited-equity housing cooperative,

or private developer that receives assistance under any federal, state, or municipal government

program to assist the construction or rehabilitation of housing affordable to low- or moderate-

income households, as defined in the applicable federal or state statute, or local ordinance,

encumbered by a deed restriction or other covenant recorded in the land records of the municipality

in which the housing is located, that:

(A) Restricts occupancy of no less than fifty percent (50%) of the housing to households

with a gross, annual income that does not exceed eighty percent (80%) of the area median income

as defined annually by the United States Department of Housing and Urban Development (HUD);

(B) Restricts the monthly rent, including a utility allowance, that may be charged to

residents, to an amount that does not exceed thirty percent (30%) of the gross, monthly income of

a household earning eighty percent (80%) of the area median income as defined annually by HUD;

Electric service account or accounts in good standing associated with housing

developments that are under common ownership or control may be considered a single low- or

moderate-income housing eligible credit recipient for purposes of this section. The value of the

credits shall be used to provide benefits to tenants.

(iii) “Educational institutions” means public and private schools at the primary, secondary,

and postsecondary levels.

(iv) “Commercial or industrial customers” means any non-residential nonresidential

customer of the electric distribution company.

(4)(5) “Eligible net-metering resource” means eligible renewable energy resource, as

defined in § 39-26-5 including biogas created as a result of anaerobic digestion, but, specifically

excluding all other listed eligible biomass fuels.

(5)(6) “Eligible net-metering system” means a facility generating electricity using an

eligible net-metering resource that is reasonably designed and sized to annually produce electricity

in an amount that is equal to, or less than, the renewable self-generator’s usage at the eligible net-

metering system site measured by the three-year (3) average annual consumption of energy over

the previous three (3) years at the electric distribution account(s) located at the eligible net-metering

system site. A projected annual consumption of energy may be used until the actual three-year (3)

average annual consumption of energy over the previous three (3) years at the electric distribution

account(s) located at the eligible net-metering system site becomes available for use in determining

eligibility of the generating system. The eligible net-metering system may be owned by the same

entity that is the customer of record on the net-metered accounts or may be owned by a third party

that is not the customer of record at the eligible net-metering system site and which may offer a

third-party, net-metering financing arrangement or net-metering financing arrangement, as

applicable. Notwithstanding any other provisions of this chapter, any eligible net-metering

resource: (i) Owned by a public entity, educational institution, hospital, nonprofit, or multi-

municipal collaborative; or (ii) Owned and operated by a renewable-generation developer on behalf

of a public entity, educational institution, hospital, nonprofit, or multi-municipal collaborative

through a net-metering financing arrangement shall be treated as an eligible net-metering system

and all accounts designated by the public entity, educational institution, hospital, nonprofit, or

multi-municipal collaborative for net metering shall be treated as accounts eligible for net metering

within an eligible net-metering system site,; or (iii) Owned and operated by a renewable-generation

developer on behalf of one or more commercial or industrial customer(s) through net-metering

financing arrangement(s) shall be treated as an eligible net-metering system within an eligible net-

metering system site. Notwithstanding any other provision to the contrary, effective July 1, 2060,

an eligible net-metering system means a facility generating electricity using an eligible net-

metering resource that is interconnected behind the same meter as the net-metering customer’s load.

(6)(7) “Eligible net-metering system site” means the site where the eligible net-metering

system or community remote net-metering system is located or is part of the same campus or

complex of sites contiguous to one another and the site where the eligible net-metering system or

community remote net-metering system is located or a farm in on which the eligible net-metering

system or community remote net-metering system is located. Except for an eligible net-metering

system owned by or operated on behalf of a public entity, educational institution, hospital,

nonprofit, or multi-municipal collaborative through a net-metering financing arrangement or for a

commercial or industrial customer through a net-metering financing arrangement, the purpose of

this definition is to reasonably assure that energy generated by the eligible net-metering system is

consumed by net-metered electric service account(s) that are actually located in the same

geographical location as the eligible net-metering system. All energy generated from any eligible

net-metering system is, and will be considered, consumed at the meter where the renewable energy

resource is interconnected for valuation purposes. Except for an eligible net-metering system

owned by, or operated on behalf of, a public entity, educational institution, hospital, nonprofit, or

multi-municipal collaborative, or for a commercial or industrial customer through a net-metering

financing arrangement, or except for a community remote net-metering system, all of the net-

metered accounts at the eligible net-metering system site must be the accounts of the same customer

of record and customers are not permitted to enter into agreements or arrangements to change the

name on accounts for the purpose of artificially expanding the eligible net-metering system site to

contiguous sites in an attempt to avoid this restriction. However, a property owner may change the

nature of the metered service at the accounts at the site to be master metered in the owner’s name,

or become the customer of record for each of the accounts, provided that the owner becoming the

customer of record actually owns the property at which the account is located. As long as the net-

metered accounts meet the requirements set forth in this definition, there is no limit on the number

of accounts that may be net metered within the eligible net-metering system site.

(7)(8) “Excess renewable net-metering credit” means a credit that applies to an eligible net-

metering system or community remote net-metering system for that portion of the production of

electrical energy beyond one hundred percent (100%) and no greater than one hundred twenty-five

percent (125%) of the renewable self-generator’s own consumption 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 applicable billing period. Such excess

renewable net-metering credit shall be equal to the electric distribution company’s avoided cost

rate, which is hereby declared to be the electric distribution company’s standard-offer last resort

service kilowatt hour (KWh) charge for the rate class and time-of-use billing period (if applicable)

applicable to the customer of record for the eligible net-metering system or applicable to the

customer of record for the community remote net-metering system. The commission shall have the

authority to make determinations as to the applicability of this credit to specific generation facilities

to the extent there is any uncertainty or disagreement.

(8)(9) “Farm” shall be defined in accordance with § 44-27-2, except that all buildings

associated with the farm shall be eligible for net-metering credits as long as: (i) The buildings are

owned by the same entity operating the farm or persons associated with operating the farm; and (ii)

The buildings are on the same farmland as the project on either a tract of land contiguous with, or

reasonably proximate to, such farmland or across a public way from such farmland.

(9)(10) “Hospital” means and shall be defined and established as set forth in chapter 17 of

title 23.

(10)(11) “Multi-municipal collaborative” means a group of towns and/or cities that enter

into an agreement for the purpose of co-owning a renewable-generation facility or entering into a

financing arrangement pursuant to subsection (14) (15).

(11)(12) “Municipality” means any Rhode Island town or city, including any agency or

instrumentality thereof, with the powers set forth in title 45.

(12)(13) “Net metering” means using electrical energy generated by an eligible net-

metering system for the purpose of self-supplying electrical energy and power at the eligible net-

metering system site, or with respect to a community remote net-metering system, for the purpose

of generating net-metering credits to be applied to the electric bills of the eligible credit recipients

associated with the community net-metering system. The amount so generated will thereby offset

consumption at the eligible net-metering system site through the netting process established in this

chapter, or with respect to a community remote net-metering system, the amounts generated in

excess of that amount will result in credits being applied to the eligible credit-recipient accounts

associated with the community remote net-metering system.

(13)(14) “Net-metering customer” means a customer of the electric distribution company

receiving and being billed for distribution service whose distribution account(s) are being net

metered.

(14)(15) “Net-metering financing arrangement” means arrangements entered into by a

public entity, educational institution, hospital, nonprofit, or multi-municipal collaborative, or a

commercial or industrial customer with a private entity to facilitate the financing and operation of

a net-metering resource, in which the private entity owns and operates an eligible net-metering

resource on behalf of a public entity, educational institution, hospital, nonprofit, or multi-municipal

collaborative, or commercial or industrial customer, where: (i) The eligible net-metering resource

is located on property owned or controlled by the public entity, educational institution, hospital, or

one of the municipalities, municipality, multi-municipal collaborative, or commercial or industrial

customer as applicable; and (ii) The production from the eligible net-metering resource and primary

compensation paid by the public entity, educational institution, hospital, nonprofit, or multi-

municipal collaborative, or commercial or industrial customer to the private entity for such

production is directly tied to the consumption of electricity occurring at the designated net-metered

accounts.

(15)(16) “Nonprofit” means a nonprofit corporation as defined and established through

chapter 6 of title 7, and shall include religious organizations that are tax exempt pursuant to 26

U.S.C. § 501(d).

(16)(17) “Person” means an individual, firm, corporation, association, partnership, farm,

town or city of the state of Rhode Island, multi-municipal collaborative, or the state of Rhode Island

or any department of the state government, governmental agency, or public instrumentality of the

state.

(18) “Preferred site” means a location for a renewable energy system that has had prior

development, including, but not limited to,: landfills, gravel pits and quarries, highway and major

road median strips, brownfields, superfund sites, parking lots or sites that are designated

appropriate for carports, and all rooftops including, but not limited to, residential, commercial,

industrial, and municipal buildings.

(17)(19) “Project” means a distinct installation of an eligible net-metering system or a

community remote net-metering system. An installation will be considered distinct if it is installed

in a different location, or at a different time, or involves a different type of renewable energy.

Subject to the safe-harbor provisions in § 39-26.4-3(a)(1), new and distinct projects cannot be

located on adjoining parcels of land within core forests, except for preferred sites.

(18)(20) “Public entity” means the federal government, the state of Rhode Island,

municipalities, wastewater treatment facilities, public transit agencies, or any water distributing

plant or system employed for the distribution of water to the consuming public within this state

including the water supply board of the city of Providence.

(21) "Public entity net-metering system" means a system generating renewable energy at a

property owned or controlled by the public entity which that is participating in a net-metering

financing arrangement where the public entity has designated accounts in its name to receive net-

metering credits.

(19)(22) “Renewable net-metering credit” means a credit that applies to an eligible net-

metering system or a community remote net-metering system up to one hundred percent (100%) of

either the renewable self-generator’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 over the applicable billing period. This credit shall be equal to the total kilowatt

hours of electrical energy generated up to the amount consumed on-site, and/or generated up to the

sum of the eligible credit-recipient account usage during the billing period multiplied by the sum

of the distribution company’s:

(i) Standard-offer Last resort service kilowatt-hour charge for the rate class applicable to

the net-metering customer, except that for remote public entity and multi-municipality

collaborative net-metering systems that submit an application for an interconnection study on or

after July 1, 2017, and community remote net-metering systems, the standard-offer last resort

service kilowatt-hour charge shall be net of the renewable energy standard charge or credit;

(ii) Distribution kilowatt-hour charge;

(iii) Transmission kilowatt-hour charge; and

(iv) Transition kilowatt-hour charge.

For projects after April 15, 2023, subject to the allowable two hundred seventy-five

megawatts alternating current (275MWac), under § 39-26.4-3(a)(1)(vi), the credit shall be reduced

by twenty percent (20%).

Notwithstanding the foregoing, except for systems that 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 December 31, 2018, the

renewable net-metering credit for all remote public entity and multi-municipal collaborative net-

metering systems shall not include the distribution kilowatt-hour charge commencing on January

1, 2050.

(20)(23) “Renewable self-generator” means an electric distribution service customer of

record for the eligible net-metering system or community remote net-metering system at the eligible

net-metering system site which system is primarily designed to produce electrical energy for

consumption by that same customer at its distribution service account(s), and/or, with respect to

community remote net-metering systems, electrical energy which generates net-metering credits to

be applied to offset the eligible credit-recipient account usage.

(21)(24) “Third party” means and includes any person or entity, other than the renewable

self-generator, who or that owns or operates the eligible net-metering system or community remote

net-metering system on the eligible net-metering system site for the benefit of the renewable self-

generator.

(22)(25) “Third-party, net-metering financing arrangement” means the financing of

eligible net-metering systems or community remote net-metering systems through lease

arrangements or power/credit purchase agreements between a third party and renewable self-

generator, except for those entities under a public entity net-metering financing arrangement. A

third party engaged in providing financing arrangements related to such net-metering systems with

a public or private entity is not a public utility as defined in § 39-1-2.

39-26.4-3. Net metering.

(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), effective sixty (60) days after passage.

(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, (iA) have Have submitted a complete application to the appropriate municipality for any

required permits and/or zoning changes, or, (iiB) have Have requested an interconnection study for

which payment has been received by the distribution company, or (iiiC) if 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; and .

(ii)(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. After December 31, 2018, the commission may

expand or modify the aggregate amount after a public hearing upon petition by the office of energy

resources. The commission shall determine within six (6) months of such petition being docketed

by the commission whether the benefits of the proposed expansion exceed the cost. This aggregate

amount shall not apply to any net-metering financing arrangement involving public entity facilities,

multi-municipal collaborative facilities, educational institutions, the federal government, hospitals,

or nonprofits. By June 30, 2018, the commission shall conduct a study examining the cost and

benefit to all customers of the inclusion of the distribution charge as a part of the net-metering

calculation.

(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 MWACac),

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: (1A) the The eligible-

net metering system is interconnected behind the same meter as the net-metering customer’s load;

and/or (2B) the 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.

(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.

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-(20)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.

SECTION 2. Sections 39-26.6-1, 39-26.6-3, 39-26.6-5, 39-26.6-7, 39-26.6-10, and 39-

26.6-12, 39-26.6-15, 39-26.6-22 and 39-26.6-25 of the General Laws in Chapter 39-26.6 entitled

"The Renewable Energy Growth Program" are hereby amended to read as follows:

39-26.6-1. Purpose.

The purpose of this chapter is to facilitate and promote installation of grid-connected

generation of renewable energy; support and encourage development of distributed renewable

energy generation systems; reduce environmental impacts; reduce carbon emissions that contribute

to climate change by encouraging the siting of renewable energy projects in the load zone of the

electric distribution company; diversify the energy-generation sources within the load zone of the

electric distribution company; stimulate economic development; improve distribution-system

resilience and reliability within the load zone of the electric distribution company; and reduce

distribution system costs enable the state to meet its climate and resilience goals, including those

established in the act on climate. This includes the goals to facilitate and promote installation of

grid-connected generation of renewable energy; support and encourage development of distributed

renewable energy generation systems while protecting important core forest areas essential to

climate resilience and complying with Rhode Island’s climate change mandates; reduce

environmental impacts; reduce carbon emissions that contribute to climate change by encouraging

the siting of renewable energy projects in the load zone of the electric distribution company and in

preferred areas that have already been disturbed by industry or other uses; diversify the energy-

generation sources within the load zone of the electric distribution company; stimulate economic

development; and improve distribution-system resilience and reliability with the load zone of the

electric distribution company.

39-26.6-3. Definitions.

When used in this chapter, the following terms shall have the following meanings:

(1) “Board” shall mean the distributed-generation board as established pursuant to the

provisions of § 39-26.2-10 under the title distributed generation standard contract board, but shall

also fulfill the responsibilities set forth in this chapter.

(2) “Ceiling price” means the bidding price cap(s) applicable to an each annual enrollment

for a given distributed-generation class, that shall be approved annually for each renewable energy

class pursuant to the procedure established in this chapter. the The ceiling price(s) are not required

to, but may be, approved for up to three years. The ceiling price for each technology should be a

price that would allow a private owner to invest in a given project at a reasonable rate of return,

based on recently reported and forecast information on the cost of capital and the cost of generation

equipment. The calculation of the reasonable rate of return for a project shall include, where

applicable, any state or federal incentives, including, but not limited to, tax incentives. Nothing

shall prohibit the distributed-generation board from proposing revised ceiling prices prior to a

program year to account for changes to available federal or state tax incentives, trade tariffs, or

other federal or state incentives which that would affect the calculation of the rate of return on a

project.

(3) “Commercial-scale solar project” means a solar distributed-generation project with the

nameplate capacity specified in § 39-26.6-7.

(4) “Commission” means the Rhode Island public utilities commission.

(5) “Community remote distributed-generation system” means a distributed-generation

facility greater than two hundred fifty kilowatt (250 KW) nameplate direct current that allocates

bill credits for each kilowatt hour (KWh) generated to a minimum of three (3), eligible recipient-

customer accounts, provided that no more than fifty percent (50%) of the credits produced by the

system are allocated to one eligible recipient-customer account, and provided further that at least

fifty percent (50%) of the credits produced by the system are allocated to eligible recipients in an

amount not to exceed that which is produced annually by twenty-five kilowatt (25 KW) AC

capacity. The community remote distributed-generation system may transfer credits to eligible

recipient-customer accounts in an amount that is equal to, or less than, the sum of the usage of the

eligible recipient-customer accounts measured by the three-year-average (3) annual consumption

of energy over the previous three (3) years. A projected, annual consumption of energy may be

used until the actual three-year-average (3) annual consumption of energy over the previous three

(3) years at the eligible recipient-customer accounts becomes available for use in determining

eligibility of the generating system. The community remote distributed-generation system may be

owned by the same entity that is the customer of record on the net-metered account or may be

owned by a third party.

(6) “Core forest” refers to unfragmented forest blocks of single or multiple parcels totaling

two hundred fifty (250) acres or greater unbroken by development and at least twenty-five (25)

acres from mapped roads, with eligibility questions to be resolved by the director of the department

of environmental management. Such determination shall constitute a contested case as defined in

§ 42-35-1. Notwithstanding any other provisions of this chapter, no renewable-distributed-

generation project that is located or planned to be located in or on a core forest, shall be considered

an eligible renewable-distributed-generation project or otherwise be eligible to participate in this

program, unless it is on a preferred site.

(6)(7) “Distributed-generation facility” means an electrical-generation facility located in

the electric distribution company’s load zone with a nameplate capacity no greater than five

megawatts (5 MW), except for solar projects as described in § 39-26.6-7 that may exceed five

megawatts (5 MW) but shall not be greater than fifteen megawatts (15 MW), unless located on

preferred sites, in which case they may be sized up to thirty-nine megawatts (39 MW), using eligible

renewable energy resources as defined by § 39-26-5, including biogas created as a result of

anaerobic digestion, but, specifically excluding all other listed eligible biomass fuels, and

connected to an electrical power system owned, controlled, or operated by the electric distribution

company. For facilities 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. For purposes of this

chapter, a distributed-generation facility must be a new resource that:

(i) Has not begun operation;

(ii) Is not under construction, but excluding preparatory site work that is less than twenty-

five percent (25%) of the estimated total project cost; and

(iii) Except for small-scale solar projects, does not have in place investment or lending

agreements necessary to finance the construction of the facility prior to the submittal of an

application or bid for which the payment of performance-based incentives is sought under this

chapter except to the extent that such financing agreements are conditioned upon the project owner

being awarded performance-based incentives under the provisions of this chapter. For purposes of

this definition, preexisting hydro generation shall be exempt from the provisions of subsection

(67)(i) regarding operation, if the hydro-generation facility will need a material investment to

restore or maintain reliable and efficient operation and meet all regulatory, environmental, or

operational requirements. For purposes of this provision, “material investment” shall mean

investment necessary to allow the project to qualify as a new, renewable energy resource under §

39-26-2. To be eligible for this exemption, the hydro-project developer at the time of submitting a

bid in the applicable procurement must provide reasonable evidence with its bid application

showing the level of investment needed, along with any other facts that support a finding that the

investment is material, the determination of which shall be a part of the bid review process set forth

in § 39-26.6-16 for the award of bids.

(7)(8) “Distributed-generation project” means a distinct installation of a distributed-

generation facility. An installation will be considered distinct if it does not violate the segmentation

prohibition set forth in § 39-26.6-9.

(8)(9) “Electric distribution company” means a company defined in § 39-1-2(a)(12),

supplying standard-offer service, last-resort service, or any successor service to end-use customers,

but not including the Block Island Power Company or the Pascoag Utility District.

(9)(10) “ISO-NE” means Independent System Operator-New England, the Regional

Transmission Organization for New England designated by the Federal Energy Regulatory

Commission.

(10)(11) “Large distributed-generation project” means a distributed-generation project that

has a nameplate capacity that exceeds the size of a small distributed-generation project in a given

year, but is no greater than five megawatts (5 MW) nameplate capacity.

(11)(12) “Large-scale solar project” means a solar distributed-generation project with the

nameplate capacity specified in § 39-26.6-7.

(12)(13) “Medium-scale solar project” means a solar distributed-generation project with

the nameplate capacity specified in § 39-26.6-7.

(13)(14) “Office” means the Rhode Island office of energy resources.

(15) “Preferred sites” means a location for a renewable energy system that has had prior

development, including, but not limited to, landfills, gravel pits and quarries, highway and major

road median strips, brownfields, superfund sites, parking lots or sites that are designated

appropriate for carports, and all rooftops including, but not limited to, residential, commercial,

industrial and municipal buildings.

(14)(16) “Program year” means a year beginning April 1 and ending March 31, except for

the first program year, that may commence after April 1, 2015, subject to commission approval.

(15)(17) “Renewable energy certificate” means a New England Generation Information

System renewable energy certificate as defined in § 39-26-2(14).

(16)(18) “Renewable energy classes” means categories for different renewable energy

technologies using eligible renewable energy resources as defined by § 39-26-5, including biogas

created as a result of anaerobic digestion, but, specifically excluding all other listed eligible biomass

fuels specified in § 39-26-2(6). For each program year, in addition to the classes of solar distributed

generation specified in § 39-26.6-7, the board shall determine the renewable energy classes as are

reasonably feasible for use in meeting distributed-generation objectives from renewable energy

resources and are consistent with the goal of meeting the annual target for the program year. The

board may make recommendations to the commission to add, eliminate, or adjust renewable energy

classes for each program year, provided that the solar classifications set forth in § 39-26.6-7 shall

remain in effect for at least the first two (2) program years and no distributed-generation project

may exceed five megawatts (5 MW) of nameplate capacity except for solar projects as described

in § 39-26.6-7.

(17)(19) “Shared solar facility” means a single small-scale or medium-scale solar facility

that must allocate bill credits to at least two (2), and no more than fifty (50), accounts in the same

customer class and on the same or adjacent parcels of land. Public entities may allocate such bill

credits to at least two (2), and up to fifty (50), accounts without regard to physical location so long

as the facility and accounts are within the same municipality. In no case will the annual allocated

credits in KWh exceed the prior three-year (3) annual average usage, less any reductions for verified

energy-efficiency measures installed at the customer premises, of the customer account to which

the bill credits are transferred.

(18)(20) “Small distributed-generation project” means a distributed-generation renewable

energy project that has a nameplate capacity within the following: Wind: fifty kilowatts (50 KW)

to one and one-half megawatts (1.5 MW); small-scale solar projects and medium-scale solar

projects with the capacity limits as specified in § 39-26.6-7. For technologies other than solar and

wind, the board shall set the nameplate capacity-size limits, but such limits may not exceed one

megawatt (1 MW).

(19)(21) “Small-scale solar project” means a solar distributed-generation project with the

nameplate capacity specified in § 39-26.6-7.

39-26.6-5. Tariffs proposed and approved.

(a) Each year, for a period of at least five (5) program years, the electric distribution

company shall file tariffs with the commission that are designed to provide a multiyear stream of

performance-based incentives to eligible renewable-distributed-generation projects for a term of

years, under terms and conditions set forth in the tariffs and approved by the commission. The

tariffs shall set forth the rights and obligations of the owner of the distributed-generation project

and the conditions upon which payment of performance-based incentives by the electric

distribution company will be paid. The tariffs shall include the non-price conditions set forth in §§

39-26.2-7(2)(i) — (vii) for small distributed-generation projects (other than small- and medium-

scale solar) and large distributed-generation projects; provided, however, that the time periods for

the projects to reach ninety percent (90%) of output shall be extended to twenty-four (24) months

(other than eligible anaerobic-digestion projects, which shall be thirty-six (36) months, and eligible

small-scale hydro, and large-scale solar projects which shall be forty-eight (48) months). The non-

price conditions in the tariffs for small- and medium-scale solar shall take into account the different

circumstances for distributed-generation projects of the smaller sizes.

(b) In addition to the tariff(s), the filing shall include the rules governing the solicitation

and enrollment process. The solicitation rules will be designed to ensure the orderly functioning of

the distributed-generation growth program and shall be consistent with the legislative purposes of

this chapter.

rules shall be developed by the electric distribution company and will be reviewed by the office

and the board before being sent to the commission for its approval. The proposed tariffs shall

include the ceiling prices and term lengths for each tariff that are recommended by the board. The

term lengths shall be from fifteen (15) to twenty (20) years; provided, however, that the board may

recommend shorter terms for small-scale solar projects. Whatever term lengths between fifteen

(15) and twenty (20) years are chosen for any given tariff, the evaluation of the bids for that tariff

shall be done on a consistent basis such that the same term lengths for competing bids are used to

determine the winning bids.

(d) The board shall use the same standards for setting ceiling prices as set forth in § 39-

26.2-5. In setting the ceiling prices, the board may specifically consider:

(1) Transactions for newly developed renewable energy resources, by technology and size,

in the ISO-NE control area and the northeast corridor;

(2) Pricing from bids received during the previous program year;

(3) Environmental benefits, including, but not limited to, reducing carbon emissions;

(4) For community remote distributed-generation systems, administrative costs and

financial benefits for participating customers;

(5) System benefits; and

(6) Cost-effectiveness;

(7) Location of projects, including climate resilience and conservation benefits; and

(8) Labor standards pursuant to chapter 26.9 of this title 39.

(e) At least forty-five (45) days before filing the tariff(s) and solicitation rules, the electric

distribution company shall provide the tariff(s) and rules in draft form to the board for review. The

commission shall have the authority to determine the final terms and conditions in the tariff and

rules. Once approved, the commission shall retain exclusive jurisdiction over the performance-

based incentive payments, terms, conditions, rights, enforcement, and implementation of the tariffs

and rules, subject to appeals pursuant to chapter 5 of this title.

39-26.6-7. Solar project size categories.

(a) Tariff(s) shall be proposed for each of the following solar distributed-generation

classes:

(1) Small-scale solar projects;

(2) Medium-scale solar projects;

(3) Commercial-scale solar projects; and

(4) Large-scale solar projects.

(b) Such classes of solar distributed-generation projects shall be established based on

nameplate megawatt size as follows:

(1) Large scale: solar projects from one megawatt (1 MW), up to and including, five

megawatts (5 MW) nameplate capacity; shall be comprised of four (4) classes as follows:

(i) One megawatt (1 MW) but less than five megawatts (5 MW), nameplate capacity;

(ii) Five megawatts (5 MW), but less than ten megawatts (10 MW), nameplate capacity;

(iii) Ten megawatts (10 MW), but less than fifteen megawatts (15 MW), nameplate

capacity; and

(iv) Fifteen megawatts (15 MW), but less than thirty-nine megawatts (39 MW), nameplate

capacity for projects located on preferred sites.;

(2) Commercial scale: shall be comprised of solar projects greater than two hundred fifty

kilowatts (250 KW), but less than one megawatt (1 MW) nameplate capacity;

(3) Medium scale: shall be comprised of solar projects greater than twenty-five kilowatts

(25 KW), up to and including, two hundred fifty kilowatts (250 KW) nameplate capacity; and

(4) Small scale: shall be comprised of solar projects, up to and including, twenty-five

kilowatts (25 KW) nameplate capacity.

approval of the commission. After the second program year, the board may make recommendations

to the commission to adjust the size categories of the solar classes, provided that the medium-scale

solar projects may not exceed two hundred fifty kilowatts (250 KW); and/or allocated capacity to

community distributed-generation facilities, allowing them to compete or enroll under a distinct

ceiling price.

39-26.6-10. Timing and schedule of tariff filings.

(a) The electric distribution company shall file with the commission the first set of tariffs

and solicitation rules pursuant to this chapter no later than November 15, 2014. Thereafter, the

electric distribution company shall make annual tariff and solicitation rules filings with the

commission no later than November 15 prior to the beginning of the applicable program year when

necessary, which tariffs and rules shall be applicable for the next program year(s).

(b) Upon receiving the filing from the electric distribution company, the commission shall

open a docket to consider the filing. The commission shall issue an order approving the proposed

tariffs and solicitation rules; provided, however, that the commission may make any modifications

that it deems appropriate consistent with the legislative purposes of this chapter as set forth herein.

solicitation rules by no later than March 31, 2015. Thereafter, the The commission shall approve

them by February 15 tariff(s) and solicitation rules prior to the commencement of each succeeding

the applicable year(s).

(d) During the course of any program year, the electric distribution company may, at any

time, in consultation with the office and the board, propose tariff or solicitation rules modifications.

The commission shall consider the proposed modifications through an already open or new docket,

and shall issue its order within one hundred five (105) days of the filing of the proposed

modification. If approved, the proposed modification shall take effect for the next enrollment event

following the issuance of the commission’s order.

39-26.6-12. Annual bidding and enrollments.

(a) With the exception of the first program year (2015), the The electric distribution

company, in consultation with the board and office, shall conduct at least three (3) tariff enrollments

for each distributed-generation class each program year. For the first program year, the board may

recommend that either two (2) or three (3) enrollments be conducted.

(b) During each program year, the tariff enrollments shall have both an annual targeted

amount of nameplate megawatts (“annual MW target”) and a nameplate megawatt target for each

separate enrollment event (“enrollment MW target”). The enrollment MW target shall comprise the

specific portion of the annual MW target sought to be obtained in that enrollment. The annual MW

target(s) and enrollment MW targets shall be recommended by the board each year no less

frequently than every three (3) years, subject to commission approval. The board shall also

recommend a megawatt target for each class (“class MW target”) that comprises a specified portion

of the enrollment MW target, subject to commission approval. If the electric distribution company,

the office, and the board mutually agree, they may reallocate megawatts during an enrollment from

one class to another without commission approval if there is an over-subscription in one class and

an under-subscription in another, provided that the annual MW target is not being exceeded, except

as provided in § 39-26.6-7 39-26.6-17. No reallocation of megawatts from a competitive pricing

class to a non-competitive pricing class shall be made until after the completion of the three (3)

enrollment periods in the program year and in no case may the annual MW target be exceeded as a

result of a reallocation of megawatts.

The annual target for each program year shall be up to three hundred megawatts (300 MW);

provided that, thirty megawatts (30 MW) shall be reserved for projects less than one megawatt (1

MW). The board may petition the commission for approval of multi-year annual targets and

associated-ceiling prices. established as follows; provided, however, that at least three megawatts

(3 MW) of nameplate capacity shall be carved out exclusively for small-scale solar projects in each

of the first four (4) program years:

(1) For the first program year (2015), the annual MW target shall be twenty-five nameplate

megawatts (25 MW);

(2) For the second program year, the annual targets shall be forty nameplate megawatts (40

MW);

(3) For the third and fourth program years, the annual target shall be forty nameplate

megawatts (40 MW), subject to the conditions set forth in subsection (f) of this section having been

met for the applicable prior program year as determined in the manner specified in subsection (g)

of this section;

(4) For the fifth program year, the annual target shall be set to obtain the balance of capacity

needed to achieve one hundred sixty nameplate megawatts (160 MW) within the five-year (5)

distributed-generation growth program, subject to subsection (e) of this section and the conditions

set forth in subsection (f) of this section having been met for the fourth program year as determined

in the manner specified in subsection (g) of this section; and

(5) From the year 2020 through the year 2029, the annual target for each program year shall

be an additional forty nameplate megawatts (40 MW) above the annual target for the preceding the

program year.

(d) During the fifth year of the distributed-generation growth program, the board may

recommend to the commission an extension of time in the event that additional time is required to

achieve the full one hundred sixty nameplate megawatt (160 MW) target of the program. The

commission shall approve the recommendation of the board; provided, however, that the

commission may make any modifications to the board’s recommendation that the commission

deems appropriate, consistent with the legislative purposes of this chapter as set forth herein.

(e) To the extent there was a shortfall of capacity procured under chapter 26.2 of this title

from distributed-generation procurements in 2014, such shortfall amount may be added to the one

hundred sixty megawatt (160 MW) target for acquisition in the fifth program year under this

chapter. In no event shall the electric distribution company be required to exceed the aggregate

amount of one hundred sixty (160) nameplate capacity plus any such shortfall amount over the five

(5) years, but may do so voluntarily, in consultation with the board and subject to commission

approval.

(f) The conditions specified in subsections (c)(3) and (c)(4) of this section are as follows:

(1) That it is reasonable to conclude that the bid prices submitted in the procurements for the large-

scale solar and commercial-scale solar classes were reasonably competitive in the immediately

preceding program year; (2) That it is reasonable to conclude that the annual MW target specified

for the next program year is reasonably achievable; and (3) That the electric distribution company

was able to, or with reasonably prudent efforts should have been able to, perform the studies and

system upgrades on a timely basis necessary to accommodate the number of applications associated

with the targets without materially adversely affecting other electric-distribution construction

projects needed to provide reliable and safe electric-distribution service. To the extent the board or

the commission concludes that any of these conditions have not been met for the applicable

program year, the board may recommend, and/or the commission may adopt, a new annual MW

target, based on the factors set forth in subsection (h) of this section.

(g) Before the third, fourth, and fifth program years, each year the board shall review the

conditions specified in subsection (f) of this section and make a recommendation to the commission

for findings as to whether they have been met for the applicable year. The recommendation shall

be filed with the commission, with copies to the office and the electric distribution company, and

any person who has made a written request to the commission to be included in such notification,

such list which may be obtained from the commission clerk, and a notice of such filing shall be

posted by the commission on its website. If no party files an objection to the recommended findings

within ten (10) business days of the posting, the commission may accept them without hearings. If

an objection is filed with a reasonable explanation for its basis, the commission shall hold hearings

and make the factual determination of whether the conditions have been met.

(h) In the event that the conditions in subsection (f) of this section have not been met for

any program year, then the board and the commission shall take into account the factors set forth

below in setting the annual MW target for the following year. In addition, for every program year

the board and the commission shall take into account these factors in setting the class MW targets,

and the enrollment MW targets for the following year: (1) That the new annual, class, and

enrollment levels reasonably assure that competition among projects for the applicable bidding

classifications remains robust and likely to yield reasonable and competitive program costs; (2)

That, assuming prudent management of the program, the electric distribution company should be

able to perform the studies and system upgrades on a timely basis necessary to accommodate the

number of applications associated with the targets without materially adversely affecting other

electric-distribution construction projects needed to provide reliable and safe electric-distribution

service; and (3) Any other reasonable factors that are consistent with the legislative purpose of this

chapter as set forth herein, including the program purpose to facilitate the development of

renewable distributed generation in the load zone of the electric distribution company at reasonable

cost.

(i) The renewable energy growth program is intended to achieve at least an aggregate

amount of one hundred sixty nameplate megawatts (160 MW) over five (5) years, plus any shortfall

amount added in pursuant to subsection (e) of this section. However, after the second program year,

the board may, based on market data and other information available to it, including pricing

received during previous program years, recommend changes to the annual target for any program

year above or below the specified targets in subsection (c) of this section if the board concludes

that market conditions are likely to produce favorably low or unfavorably high target pricing during

the upcoming program year, provided that the recommendation may not result in the five-year (5),

one-hundred-sixty-megawatt-nameplate (160 MW) target, plus any shortfall added pursuant to

subsection (e) of this section, being exceeded. Any megawatt reduction in an annual target shall be

added to the target in the fifth year of the program (and any subsequent years if necessary) such

that the overall program target of one-hundred-sixty-megawatt-nameplate (160 MW) capacity, plus

any shortfall added pursuant to subsection (e) of this section, is achieved. In considering these

issues, the board and the commission may take into account the reasonableness of current pricing

and its impact on all electric distribution customers and the legislative purpose of this chapter as

set forth herein, including the program purpose to facilitate the development of renewable

distributed generation in the load zone of the electric distribution company at reasonable cost.

(j) The provisions of § 39-26.1-4 shall apply to the annual value of performance-based

incentives (actual payments plus the value of net-metering credits, as applicable) provided by the

electric distribution company to all the distributed-generation projects under this chapter, subject

to the following conditions:

(1) The targets set for the applicable program year for the applicable project classifications

were met or, if not met, such failure was due to factors beyond the reasonable control of the electric

distribution company;

(2) The electric distribution company has processed applications for service and completed

interconnections in a timely and prudent manner for the projects under this chapter, taking into

account factors within the electric distribution company’s reasonable control. The commission is

authorized to establish more specific performance standards to implement the provisions of this

chapter; and

(3) The incentive shall be one and three-quarters percent (1.75%) of the annual value of

performance-based incentives. The commission is authorized to establish more specific

performance standards to implement the provisions of this paragraph.

39-26.6-15. Bidding and incentive award processes for solar DG projects.

(a) Large-scale and commercial-scale solar projects and distributed-generation projects for

other eligible technologies shall bid a price-per-kilowatt-hour for the entire output of the facility

(net of any station service) that shall not exceed the applicable ceiling price. Small-scale and

medium-scale solar projects will submit an enrollment application to receive a standard

performance-based incentive for the period of years in the applicable tariff, that shall be a price-

per-kilowatt-hour for the entire output of the facility. Except for megawatts that may be allocated

to the energy-efficiency program pursuant to § 39-26.6-19, small- and medium-scale projects shall

be selected on a first-come, first-served basis, or by means of a commission-approved lottery

system, or such other method as may be recommended by the board and approved by the

commission.

(b) Except for the first program year, the board shall determine, subject to commission

approval, the standard performance-based incentive for small- and medium-sized solar projects

from the average bid price from the last two (2) procurement enrollments conducted in the

commercial-scale and/or large-scale solar projects class. For the first program year, the board may

derive the standard performance incentive for small- and medium-sized solar projects from the

bidding data obtained from the distributed-generation program in effect in 2014 under the

provisions of chapter 26.2 of this title until there is bidding data from the first procurement under

the new program which shall then be used to set a new standard performance incentive. The

standard performance incentive may be set at a higher rate than payments for commercial-scale and

large-scale solar projects in order to take into account the potentially higher per-unit cost of smaller

projects. The standard performance incentive also shall be adjusted upward or downward, as

needed, in order to take into account the term length over which the incentive shall be paid for the

small- and medium-scale solar projects if such terms are different than the terms applicable to the

classes from which the standard performance incentive was derived.

performance incentive for each of the small-scale and medium-scale solar project classifications,

which performance incentives may span up to three program years. Upon receiving the

recommendations from the board, the commission shall open a docket to consider the

recommendations or address the recommendations in its approval process for the applicable

program year(s) in a consolidated docket as provided in § 39-26.6-10. The commission shall issue

its order approving the recommendations no later than concurrently with approval of the entire

program and tariffs applicable to the program year; provided, however, that the commission may

make modifications or changes to the board’s recommendations consistent with the legislative

purposes of this chapter.

(d) If after the first program year, the applications for the medium-scale solar projects are

significantly over-subscribed, then the board and the electric distribution company, in consultation

with the office, may propose to the commission a bidding process for medium-scale projects or a

subset of the medium-scale projects under which project selections would be made based on the

lowest bids, rather than first-come, first-served or such other method previously approved by the

commission. The commission shall approve the proposal from the board and electric company

within ninety (90) days; provided, however, that the commission may make changes to the proposal

consistent with the legislative purposes of this chapter.

(e) The commission shall approve the bidding process for medium-scale solar projects

recommended by the board only if the commission finds that such bidding process is in a

sufficiently simple form that is not administratively burdensome to bidders, and will not have the

effect of discouraging participation in the distributed-generation growth program by developers of

medium-scale solar projects that may be unrepresented by counsel.

39-26.6-22. Zonal and other incentive payments.

In order to provide the electric distribution company and the board with the flexibility to

encourage distributed-generation projects to be located in designated geographical areas within its

load zone where there is an identifiable system benefit, reliability benefit, or cost savings to the

distribution system in that geographical area, the electric distribution company, in consultation with

the board and the office, may propose to include an incentive-payment adder to the bid price of any

winning bidder that proposes a distributed-generation project in the desired geographical area. or

conservation benefit, or climate resilience benefit in that geographical area, the electric distribution

company, the board, or the office, shall propose to include an incentive-payment adder to the bid

price of any winning bidder that proposes a distributed-generation project in the preferred sites that

require remediation. The company, board, or office can also propose disincentive subtractors for

projects outside of preferred sites. The electric distribution company also may propose other

incentive payments to achieve other technical or public policy objectives that provide identifiable

benefits to customers. Any incentive-payment adders must be approved by the commission, and

shall not be counted as part of the bid price when the bids are selected at an enrollment event.

39-26.6-25. Forecasted rate and reconciliation.

(a) Three (3) months prior to the beginning of the first program year On or before

November 15 of each year, the electric distribution company shall file a forecast of the total amount

of payments that is likely to be paid out to distributed-generation projects in the coming program

year within the electric distribution company’s load zone, along with any costs permitted for

recovery pursuant to §§ 39-26.6-4, 39-26.6-13, and 39-26.6-18. The total of all forecasted payments

and costs shall be aggregated, net of forecasted revenues from the sale of the energy, renewable

energy certificates, and any other market products from the distributed-generation projects

participating in the performance-based incentive program. The forecasted net-aggregate amount

shall be used to design a fixed monthly charge per customer to recover the net forecast in rates

charged to all distribution customers during the prospective calendar year, which fixed charge may

be different by rate class in order to reasonably and equitably spread the program costs across all

customer classes. The fixed rate shall stay in effect until changed after the first reconciliation filing

set forth below and the rate reconciliation process shall be repeated annually, as set forth below.

The commission, in its discretion, may move the reconciliation of costs and credits under § 39-

26.1-5(f) into this reconciliation in order to have one reconciliation of all program costs and credits

from the long-term contracting standard, distributed-generation standard contracting, and

renewable energy growth program.

(b) Within three (3) months after the end of each program year, the electric distribution

company shall file a report with the public utilities commission reconcile that reconciles the total

amount recovered from distribution customers against the total of net payments and costs for the

prior program year for review and approval. The electric distribution company shall file the

reconciliation with a report, along with a new forecast of payments to be made for the next twelve-

month (12) period, net of forecasted revenues for the resale of energy, renewable energy

certificates, or any other market attributes sold by the electric distribution company. The forecast

shall be used to set a new rate in the same manner as set forth above and the new rate shall remain

in effect until rates are reset in the next annual reconciliation and the reconciliation balance shall

be reflected in the new rate.

SECTION 3. This act shall take effect upon passage.

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LC002218/SUB A

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