UTILITIES-INTERCONNECTIONS

Illinois General Assembly - Full Text of SB3273

Select Language

×

The Illinois General Assembly offers the Google Translate™ service for visitor convenience. In no way should it be considered accurate as to the translation of any content herein.

Visitors of the Illinois General Assembly website are encouraged to use other translation services available on the internet.

The English language version is always the official and authoritative version of this website.

NOTE: To return to the original English language version, select the "Show Original" button on the Google Translate™ menu bar at the top of the window.

Choose Language

English

Afrikaans

Albanian

Arabic

Armenian

Azerbaijani

Basque

Bengali

Bosnian

Catalan

Croatian

Czech

Danish

Dutch

Esperanto

Estonian

Filipino

Finnish

French

Galician

Georgian

German

Greek

Gujarati

Haitian Creole

Hausa

Hawaiian

Hebrew

Hindi

Hungarian

Icelandic

Indonesian

Interlingua

Interlingue

Inuktitut

Irish

Italian

Japanese

Javanese

Kannada

Khmer

Korean

Latin

Latvian

Lithuanian

Luxembourgish

Macedonian

Malagasy

Malayalam

Maltese

Maori

Marathi

Myanmar

Nepali

Norwegian

Odia

Pashto

Punjabi

Romanian

Russian

Samoan

Sango

Sanskrit

Sardinian

Sindhi

Sinhala

Slovak

Slovenian

Somali

Southern Sotho

Spanish

Sundanese

Swahili

Swedish

Tamil

Telugu

Thai

Tigrinya

Tonga

Turkish

Ukrainian

Urdu

Vietnamese

Welsh

Xhosa

Yiddish

Yoruba

Zulu

Powered by
Translate

Close

Illinois General Assembly

Top Navigation Bar

Translate

Learn

Select General Assembly

Search the 104th General Assembly

Enter search terms for legislation, members, committees, or schedules.

ILGA.GOV

LEGISLATION & LAWS

Bills & Resolutions

Public Acts

Illinois Compiled Statutes

Illinois Constitution

Search Legislation

Glossary

Guide

Reports & Inquiry

Legislative Reports

Special Reports

FTP Site

Legislator Lookup

Capitol Complex Phone Numbers

Rules & Regulations

Illinois Register

Administrative Rules

Senate

Members

Schedules

Committees

Request for Remote Testimony

Journals

Transcripts

Rules

Audio/Video

FOIA Information

Senate Employment Opportunities

Media Guidelines

House

Members

Schedules

Committees

Submit testimony for House Committees

Journals

Transcripts

Rules

Audio/Video

FOIA Information

House Employment Opportunities

Log In

Mobile Top Bar

Search the 104th General Assembly

Enter keywords to search the Illinois General Assembly website.

Full Text of SB3273

Home

Legislation

Full Text

SB3273 - 104th General Assembly

Bill Status

Full Text

Votes

Witness Slips

Select Menu

Bill Status

Full Text

Votes

Witness Slips

Printer Friendly Version

Introduced

Engrossed

Enrolled

Senate Amendment 001

House Amendment 001

Printer Friendly Version

Introduced

Engrossed

Enrolled

Senate Amendment 001

House Amendment 001

Open PDF

SB3273 Enrolled
LRB104 18411 AAS 31853 b
1

AN ACT concerning regulation.

2

Be it enacted by the People of the State of Illinois,
3
represented in the General Assembly:

4

Section 5.
The Public Utilities Act is amended by changing
5
Section 16-107.5 and by adding Section 17-1000 as follows:

6

(220 ILCS 5/16-107.5)
7

(Text of Section before amendment by P.A. 104-458
)
8

Sec. 16-107.5.
Net electricity metering.
9

(a) The General Assembly finds and declares that a program
10
to provide net electricity metering, as defined in this
11
Section, for eligible customers can encourage private
12
investment in renewable energy resources, stimulate economic
13
growth, enhance the continued diversification of Illinois'
14
energy resource mix, and protect the Illinois environment.
15
Further, to achieve the goals of this Act that robust options
16
for customer-site distributed generation continue to thrive in
17
Illinois, the General Assembly finds that a predictable
18
transition must be ensured for customers between full net
19
metering at the retail electricity rate to the distribution
20
generation rebate described in Section 16-107.6.
21

(b) As used in this Section, (i) "community renewable
22
generation project" shall have the meaning set forth in
23
Section 1-10 of the Illinois Power Agency Act; (ii) "eligible

SB3273 Enrolled
- 2 -
LRB104 18411 AAS 31853 b
1
customer" means a retail customer that owns, hosts, or
2
operates, including any third-party owned systems, a solar,
3
wind, or other eligible renewable electrical generating
4
facility that is located on the customer's premises or
5
customer's side of the billing meter and is intended primarily
6
to offset the customer's own current or future electrical
7
requirements; (iii) "electricity provider" means an electric
8
utility or alternative retail electric supplier; (iv)
9
"eligible renewable electrical generating facility" means a
10
generator, which may include the co-location of an energy
11
storage system, that is interconnected under rules adopted by
12
the Commission and is powered by solar electric energy, wind,
13
dedicated crops grown for electricity generation, agricultural
14
residues, untreated and unadulterated wood waste, livestock
15
manure, anaerobic digestion of livestock or food processing
16
waste, fuel cells or microturbines powered by renewable fuels,
17
or hydroelectric energy; (v) "net electricity metering" (or
18
"net metering") means the measurement, during the billing
19
period applicable to an eligible customer, of the net amount
20
of electricity supplied by an electricity provider to the
21
customer or provided to the electricity provider by the
22
customer or subscriber; (vi) "subscriber" shall have the
23
meaning as set forth in Section 1-10 of the Illinois Power
24
Agency Act; (vii) "subscription" shall have the meaning set
25
forth in Section 1-10 of the Illinois Power Agency Act; (viii)
26
"energy storage system" means commercially available

SB3273 Enrolled
- 3 -
LRB104 18411 AAS 31853 b
1
technology that is capable of absorbing energy and storing it
2
for a period of time for use at a later time, including, but
3
not limited to, electrochemical, thermal, and
4
electromechanical technologies, and may be interconnected
5
behind the customer's meter or interconnected behind its own
6
meter; and (ix) "future electrical requirements" means modeled
7
electrical requirements upon occupation of a new or vacant
8
property, and other reasonable expectations of future
9
electrical use, as well as, for occupied properties, a
10
reasonable approximation of the annual load of 2 electric
11
vehicles and, for non-electric heating customers, a reasonable
12
approximation of the incremental electric load associated with
13
fuel switching. The approximations shall be applied to the
14
appropriate net metering tariff and do not need to be unique to
15
each individual eligible customer. The utility shall submit
16
these approximations to the Commission for review,
17
modification, and approval.
18

(c) A net metering facility shall be equipped with
19
metering equipment that can measure the flow of electricity in
20
both directions at the same rate.
21

(1) For eligible customers whose electric service has
22

not been declared competitive pursuant to Section 16-113
23

of this Act as of July 1, 2011 and whose electric delivery
24

service is provided and measured on a kilowatt-hour basis
25

and electric supply service is not provided based on
26

hourly pricing, this shall typically be accomplished

SB3273 Enrolled
- 4 -
LRB104 18411 AAS 31853 b
1

through use of a single, bi-directional meter. If the
2

eligible customer's existing electric revenue meter does
3

not meet this requirement, the electricity provider shall
4

arrange for the local electric utility or a meter service
5

provider to install and maintain a new revenue meter at
6

the electricity provider's expense, which may be the smart
7

meter described by subsection (b) of Section 16-108.5 of
8

this Act.
9

(2) For eligible customers whose electric service has
10

not been declared competitive pursuant to Section 16-113
11

of this Act as of July 1, 2011 and whose electric delivery
12

service is provided and measured on a kilowatt demand
13

basis and electric supply service is not provided based on
14

hourly pricing, this shall typically be accomplished
15

through use of a dual channel meter capable of measuring
16

the flow of electricity both into and out of the
17

customer's facility at the same rate and ratio. If such
18

customer's existing electric revenue meter does not meet
19

this requirement, then the electricity provider shall
20

arrange for the local electric utility or a meter service
21

provider to install and maintain a new revenue meter at
22

the electricity provider's expense, which may be the smart
23

meter described by subsection (b) of Section 16-108.5 of
24

this Act.
25

(3) For all other eligible customers, until such time
26

as the local electric utility installs a smart meter, as

SB3273 Enrolled
- 5 -
LRB104 18411 AAS 31853 b
1

described by subsection (b) of Section 16-108.5 of this
2

Act, the electricity provider may arrange for the local
3

electric utility or a meter service provider to install
4

and maintain metering equipment capable of measuring the
5

flow of electricity both into and out of the customer's
6

facility at the same rate and ratio, typically through the
7

use of a dual channel meter. If the eligible customer's
8

existing electric revenue meter does not meet this
9

requirement, then the costs of installing such equipment
10

shall be paid for by the customer.
11

(d) An electricity provider shall measure and charge or
12
credit for the net electricity supplied to eligible customers
13
or provided by eligible customers whose electric service has
14
not been declared competitive pursuant to Section 16-113 of
15
this Act as of July 1, 2011 and whose electric delivery service
16
is provided and measured on a kilowatt-hour basis and electric
17
supply service is not provided based on hourly pricing in the
18
following manner:
19

(1) If the amount of electricity used by the customer
20

during the billing period exceeds the amount of
21

electricity produced by the customer, the electricity
22

provider shall charge the customer for the net electricity
23

supplied to and used by the customer as provided in
24

subsection (e-5) of this Section.
25

(2) If the amount of electricity produced by a
26

customer during the billing period exceeds the amount of

SB3273 Enrolled
- 6 -
LRB104 18411 AAS 31853 b
1

electricity used by the customer during that billing
2

period, the electricity provider supplying that customer
3

shall apply a 1:1 kilowatt-hour credit to a subsequent
4

bill for service to the customer for the net electricity
5

supplied to the electricity provider. The electricity
6

provider shall continue to carry over any excess
7

kilowatt-hour credits earned and apply those credits to
8

subsequent billing periods to offset any
9

customer-generator consumption in those billing periods
10

until all credits are used or until the end of the
11

annualized period.
12

(3) At the end of the year or annualized over the
13

period that service is supplied by means of net metering,
14

or in the event that the retail customer terminates
15

service with the electricity provider prior to the end of
16

the year or the annualized period, any remaining credits
17

in the customer's account shall expire.
18

(d-5) An electricity provider shall measure and charge or
19
credit for the net electricity supplied to eligible customers
20
or provided by eligible customers whose electric service has
21
not been declared competitive pursuant to Section 16-113 of
22
this Act as of July 1, 2011 and whose electric delivery service
23
is provided and measured on a kilowatt-hour basis and electric
24
supply service is provided based on hourly pricing or
25
time-of-use rates in the following manner:
26

(1) If the amount of electricity used by the customer

SB3273 Enrolled
- 7 -
LRB104 18411 AAS 31853 b
1

during any hourly period or time-of-use period exceeds the
2

amount of electricity produced by the customer, the
3

electricity provider shall charge the customer for the net
4

electricity supplied to and used by the customer according
5

to the terms of the contract or tariff to which the same
6

customer would be assigned to or be eligible for if the
7

customer was not a net metering customer.
8

(2) If the amount of electricity produced by a
9

customer during any hourly period or time-of-use period
10

exceeds the amount of electricity used by the customer
11

during that hourly period or time-of-use period, the
12

energy provider shall apply a credit for the net
13

kilowatt-hours produced in such period. The credit shall
14

consist of an energy credit and a delivery service credit.
15

The energy credit shall be valued at the same price per
16

kilowatt-hour as the electric service provider would
17

charge for kilowatt-hour energy sales during that same
18

hourly period or time-of-use period. The delivery credit
19

shall be equal to the net kilowatt-hours produced in such
20

hourly period or time-of-use period times a credit that
21

reflects all kilowatt-hour based charges in the customer's
22

electric service rate, excluding energy charges.
23

(e) An electricity provider shall measure and charge or
24
credit for the net electricity supplied to eligible customers
25
whose electric service has not been declared competitive
26
pursuant to Section 16-113 of this Act as of July 1, 2011 and

SB3273 Enrolled
- 8 -
LRB104 18411 AAS 31853 b
1
whose electric delivery service is provided and measured on a
2
kilowatt demand basis and electric supply service is not
3
provided based on hourly pricing in the following manner:
4

(1) If the amount of electricity used by the customer
5

during the billing period exceeds the amount of
6

electricity produced by the customer, then the electricity
7

provider shall charge the customer for the net electricity
8

supplied to and used by the customer as provided in
9

subsection (e-5) of this Section. The customer shall
10

remain responsible for all taxes, fees, and utility
11

delivery charges that would otherwise be applicable to the
12

net amount of electricity used by the customer.
13

(2) If the amount of electricity produced by a
14

customer during the billing period exceeds the amount of
15

electricity used by the customer during that billing
16

period, then the electricity provider supplying that
17

customer shall apply a 1:1 kilowatt-hour credit that
18

reflects the kilowatt-hour based charges in the customer's
19

electric service rate to a subsequent bill for service to
20

the customer for the net electricity supplied to the
21

electricity provider. The electricity provider shall
22

continue to carry over any excess kilowatt-hour credits
23

earned and apply those credits to subsequent billing
24

periods to offset any customer-generator consumption in
25

those billing periods until all credits are used or until
26

the end of the annualized period.

SB3273 Enrolled
- 9 -
LRB104 18411 AAS 31853 b
1

(3) At the end of the year or annualized over the
2

period that service is supplied by means of net metering,
3

or in the event that the retail customer terminates
4

service with the electricity provider prior to the end of
5

the year or the annualized period, any remaining credits
6

in the customer's account shall expire.
7

(e-5) An electricity provider shall provide electric
8
service to eligible customers who utilize net metering at
9
non-discriminatory rates that are identical, with respect to
10
rate structure, retail rate components, and any monthly
11
charges, to the rates that the customer would be charged if not
12
a net metering customer. An electricity provider shall not
13
charge net metering customers any fee or charge or require
14
additional equipment, insurance, or any other requirements not
15
specifically authorized by interconnection standards
16
authorized by the Commission, unless the fee, charge, or other
17
requirement would apply to other similarly situated customers
18
who are not net metering customers. The customer will remain
19
responsible for all taxes, fees, and utility delivery charges
20
that would otherwise be applicable to the net amount of
21
electricity used by the customer. Subsections (c) through (e)
22
of this Section shall not be construed to prevent an
23
arms-length agreement between an electricity provider and an
24
eligible customer that sets forth different prices, terms, and
25
conditions for the provision of net metering service,
26
including, but not limited to, the provision of the

SB3273 Enrolled
- 10 -
LRB104 18411 AAS 31853 b
1
appropriate metering equipment for non-residential customers.
2

(f) Notwithstanding the requirements of subsections (c)
3
through (e-5) of this Section, an electricity provider must
4
require dual-channel metering for customers operating eligible
5
renewable electrical generating facilities to whom the
6
provisions of neither subsection (d), (d-5), nor (e) of this
7
Section apply. In such cases, electricity charges and credits
8
shall be determined as follows:
9

(1) The electricity provider shall assess and the
10

customer remains responsible for all taxes, fees, and
11

utility delivery charges that would otherwise be
12

applicable to the gross amount of kilowatt-hours supplied
13

to the eligible customer by the electricity provider.
14

(2) Each month that service is supplied by means of
15

dual-channel metering, the electricity provider shall
16

compensate the eligible customer for any excess
17

kilowatt-hour credits at the electricity provider's
18

avoided cost of electricity supply over the monthly period
19

or as otherwise specified by the terms of a power-purchase
20

agreement negotiated between the customer and electricity
21

provider.
22

(3) For all eligible net metering customers taking
23

service from an electricity provider under contracts or
24

tariffs employing hourly or time-of-use rates, any monthly
25

consumption of electricity shall be calculated according
26

to the terms of the contract or tariff to which the same

SB3273 Enrolled
- 11 -
LRB104 18411 AAS 31853 b
1

customer would be assigned to or be eligible for if the
2

customer was not a net metering customer. When those same
3

customer-generators are net generators during any discrete
4

hourly or time-of-use period, the net kilowatt-hours
5

produced shall be valued at the same price per
6

kilowatt-hour as the electric service provider would
7

charge for retail kilowatt-hour sales during that same
8

time-of-use period.
9

(g) For purposes of federal and State laws providing
10
renewable energy credits or greenhouse gas credits, the
11
eligible customer shall be treated as owning and having title
12
to the renewable energy attributes, renewable energy credits,
13
and greenhouse gas emission credits related to any electricity
14
produced by the qualified generating unit. The electricity
15
provider may not condition participation in a net metering
16
program on the signing over of a customer's renewable energy
17
credits; provided, however, this subsection (g) shall not be
18
construed to prevent an arms-length agreement between an
19
electricity provider and an eligible customer that sets forth
20
the ownership or title of the credits.
21

(h) Within 120 days after the effective date of this
22
amendatory Act of the 95th General Assembly, the Commission
23
shall establish standards for net metering and, if the
24
Commission has not already acted on its own initiative,
25
standards for the interconnection of eligible renewable
26
generating equipment to the utility system. The

SB3273 Enrolled
- 12 -
LRB104 18411 AAS 31853 b
1
interconnection standards shall address any procedural
2
barriers, delays, and administrative costs associated with the
3
interconnection of customer-generation while ensuring the
4
safety and reliability of the units and the electric utility
5
system. The Commission shall consider the Institute of
6
Electrical and Electronics Engineers (IEEE) Standard 1547 and
7
the issues of (i) reasonable and fair fees and costs, (ii)
8
clear timelines for major milestones in the interconnection
9
process, (iii) nondiscriminatory terms of agreement, and (iv)
10
any best practices for interconnection of distributed
11
generation.
12

(h-5) Within 90 days after the effective date of this
13
amendatory Act of the 102nd General Assembly, the Commission
14
shall:
15

(1) establish an Interconnection Working Group. The
16

working group shall include representatives from electric
17

utilities, developers of renewable electric generating
18

facilities, other industries that regularly apply for
19

interconnection with the electric utilities,
20

representatives of distributed generation customers, the
21

Commission Staff, and such other stakeholders with a
22

substantial interest in the topics addressed by the
23

Interconnection Working Group. The Interconnection Working
24

Group shall address at least the following issues:
25

(A) cost and best available technology for
26

interconnection and metering, including the

SB3273 Enrolled
- 13 -
LRB104 18411 AAS 31853 b
1

standardization and publication of standard costs;
2

(B) transparency, accuracy and use of the
3

distribution interconnection queue and hosting
4

capacity maps;
5

(C) distribution system upgrade cost avoidance
6

through use of advanced inverter functions;
7

(D) predictability of the queue management process
8

and enforcement of timelines;
9

(E) benefits and challenges associated with group
10

studies and cost sharing;
11

(F) minimum requirements for application to the
12

interconnection process and throughout the
13

interconnection process to avoid queue clogging
14

behavior;
15

(G) process and customer service for
16

interconnecting customers adopting distributed energy
17

resources, including energy storage;
18

(H) options for metering distributed energy
19

resources, including energy storage;
20

(I) interconnection of new technologies, including
21

smart inverters and energy storage;
22

(J) collect, share, and examine data on Level 1
23

interconnection costs, including cost and type of
24

upgrades required for interconnection, and use this
25

data to inform the final standardized cost of Level 1
26

interconnection; and

SB3273 Enrolled
- 14 -
LRB104 18411 AAS 31853 b
1

(K) such other technical, policy, and tariff
2

issues related to and affecting interconnection
3

performance and customer service as determined by the
4

Interconnection Working Group.
5

The Commission may create subcommittees of the
6

Interconnection Working Group to focus on specific issues
7

of importance, as appropriate. The Interconnection Working
8

Group shall report to the Commission on recommended
9

improvements to interconnection rules and tariffs and
10

policies as determined by the Interconnection Working
11

Group at least every 6 months. Such reports shall include
12

consensus recommendations of the Interconnection Working
13

Group and, if applicable, additional recommendations for
14

which consensus was not reached. The Commission shall use
15

the report from the Interconnection Working Group to
16

determine whether processes should be commenced to
17

formally codify or implement the recommendations;
18

(2) create or contract for an Ombudsman to resolve
19

interconnection disputes through non-binding arbitration.
20

The Ombudsman may be paid in full or in part through fees
21

levied on the initiators of the dispute; and
22

(3) determine a single standardized cost for Level 1
23

interconnections, which shall not exceed $200.
24

(h-7) After an electric distribution company determines
25
that an interconnection request from an applicant for a public
26
school project has been completed, the electric distribution

SB3273 Enrolled
- 15 -
LRB104 18411 AAS 31853 b
1
company must immediately begin all evaluations, reviews, and
2
screenings of the interconnection request. Projects pending in
3
the interconnection queue on the same feeder and substation as
4
an interconnection request for a public school project shall
5
be paused until the public school project has received a fully
6
executed interconnection agreement, regardless of queue
7
position assignments under 83 Ill. Adm. Code 466, to ensure
8
that available feeder and substation capacity is reserved for
9
the public school project. If the electric distribution
10
company determines that there is no requirement for the
11
construction of facilities by the electric distribution
12
company on its own system, the electric distribution company
13
shall provide the applicant with an interconnection agreement,
14
as provided under 83 Ill. Adm. Code 466. If the electric
15
distribution company determines that the public school project
16
has a nameplate capacity that is less than 500 kilowatts (kW)
17
with no colocated distribution resources and determines that
18
no system modifications are required, the electric
19
distribution company must complete all required
20
interconnection-related evaluations, reviews, and screenings
21
within 30 days after making such a determination and issue an
22
interconnection agreement as soon as possible after the
23
evaluations, reviews, and screenings are completed. If the
24
electric distribution company determines that only minor
25
system modifications are required, the electric distribution
26
company shall provide the applicant with an interconnection

SB3273 Enrolled
- 16 -
LRB104 18411 AAS 31853 b
1
agreement within 60 days after the applicant elects to
2
continue the application and pays any necessary fees or costs
3
required under 83 Ill. Adm. Code 466. If the electric
4
distribution company determines that more than minor
5
modifications are required, the electric distribution company
6
shall provide the applicant with an interconnection agreement
7
within 90 days after the applicant elects to continue the
8
application and pays any necessary fees or costs required
9
under 83 Ill. Adm. Code 466.
10

For all net metering credits earned on a monthly basis or
11
other credits owed to a customer who has elected to install a
12
distributed renewable generation project on public school
13
land, all credits intended for the benefit of the consumer
14
must be credited by the public utility or retail energy
15
supplier within 90 days after the public utility or retail
16
energy supplier determines that the criteria for the credit
17
have been met.

18

As soon as practicable after the effective date of this
19
amendatory Act of the 104th General Assembly, the Commission
20
shall adopt revisions to its standards for the interconnection
21
of eligible renewable generating equipment and net metering
22
credit rules to conform with the requirements of this
23
amendatory Act of the 104th General Assembly.
24

As used in this subsection:
25

"Electric distribution company" means any electric utility
26
subject to the jurisdiction of the Commission serving more

SB3273 Enrolled
- 17 -
LRB104 18411 AAS 31853 b
1
than 100,000 customers in this State.
2

"Public schools" has the meaning set forth in Section 1-3
3
of the School Code and includes public institutions of higher
4
education, as defined in the Board of Higher Education Act.
5

"Public school project" means a renewable electrical
6
generating facility that is located on the premises of a
7
public school on the customer's side of the billing meter, is
8
intended primarily to offset the customer's current or future
9
electrical requirements, and is eligible only for renewable
10
energy credits apportioned to distributed renewable generation
11
devices installed on public school land under subparagraph
12
(iv) of paragraph (K) of subsection (c) of Section 1-75 of the
13
Illinois Power Agency Act.

14

(i) All electricity providers shall begin to offer net
15
metering no later than April 1, 2008.
16

(j) An electricity provider shall provide net metering to
17
eligible customers according to subsections (d), (d-5), and
18
(e). Eligible renewable electrical generating facilities for
19
which eligible customers registered for net metering before
20
January 1, 2025 shall continue to receive net metering
21
services according to subsections (d), (d-5), and (e) of this
22
Section for the lifetime of the system, regardless of whether
23
those retail customers change electricity providers or whether
24
the retail customer benefiting from the system changes. On and
25
after January 1, 2025, any eligible customer that applies for
26
net metering and previously would have qualified under

SB3273 Enrolled
- 18 -
LRB104 18411 AAS 31853 b
1
subsections (d), (d-5), or (e) shall only be eligible for net
2
metering as described in subsection (n).
3

(k) Each electricity provider shall maintain records and
4
report annually to the Commission the total number of net
5
metering customers served by the provider, as well as the
6
type, capacity, and energy sources of the generating systems
7
used by the net metering customers. Nothing in this Section
8
shall limit the ability of an electricity provider to request
9
the redaction of information deemed by the Commission to be
10
confidential business information.
11

(l)(1) Notwithstanding the definition of "eligible
12
customer" in item (ii) of subsection (b) of this Section, each
13
electricity provider shall allow net metering as set forth in
14
this subsection (l) and for the following projects, provided
15
that only electric utilities serving more than 200,000
16
customers as of January 1, 2021 shall provide net metering for
17
projects that are eligible for subparagraph (C) of this
18
paragraph (1) and have energized after the effective date of
19
this amendatory Act of the 102nd General Assembly:
20

(A) properties owned or leased by multiple customers
21

that contribute to the operation of an eligible renewable
22

electrical generating facility through an ownership or
23

leasehold interest of at least 200 watts in such facility,
24

such as a community-owned wind project, a community-owned
25

biomass project, a community-owned solar project, or a
26

community methane digester processing livestock waste from

SB3273 Enrolled
- 19 -
LRB104 18411 AAS 31853 b
1

multiple sources, provided that the facility is also
2

located within the utility's service territory;
3

(B) individual units, apartments, or properties
4

located in a single building that are owned or leased by
5

multiple customers and collectively served by a common
6

eligible renewable electrical generating facility, such as
7

an office or apartment building, a shopping center or
8

strip mall served by photovoltaic panels on the roof; and
9

(C) subscriptions to community renewable generation
10

projects, including community renewable generation
11

projects on the customer's side of the billing meter of a
12

host facility and partially used for the customer's own
13

load.
14

In addition, the nameplate capacity of the eligible
15
renewable electric generating facility that serves the demand
16
of the properties, units, or apartments identified in
17
paragraphs (1) and (2) of this subsection (l) shall not exceed
18
5,000 kilowatts in nameplate capacity in total. Any eligible
19
renewable electrical generating facility or community
20
renewable generation project that is powered by photovoltaic
21
electric energy and installed after the effective date of this
22
amendatory Act of the 99th General Assembly must be installed
23
by a qualified person in compliance with the requirements of
24
Section 16-128A of the Public Utilities Act and any rules or
25
regulations adopted thereunder.
26

(2) Notwithstanding anything to the contrary, an

SB3273 Enrolled
- 20 -
LRB104 18411 AAS 31853 b
1
electricity provider shall provide credits for the electricity
2
produced by the projects described in paragraph (1) of this
3
subsection (l). The electricity provider shall provide credits
4
that include at least energy supply, capacity, transmission,
5
and, if applicable, the purchased energy adjustment on the
6
subscriber's monthly bill equal to the subscriber's share of
7
the production of electricity from the project, as determined
8
by paragraph (3) of this subsection (l). For customers with
9
transmission or capacity charges not charged on a
10
kilowatt-hour basis, the electricity provider shall prepare a
11
reasonable approximation of the kilowatt-hour equivalent value
12
and provide that value as a monetary credit. The electricity
13
provider shall submit these approximation methodologies to the
14
Commission for review, modification, and approval.
15
Notwithstanding anything to the contrary, customers on payment
16
plans or participating in budget billing programs shall have
17
credits applied on a monthly basis.
18

(3) Notwithstanding anything to the contrary and
19
regardless of whether a subscriber to an eligible community
20
renewable generation project receives power and energy service
21
from the electric utility or an alternative retail electric
22
supplier, for projects eligible under paragraph (C) of
23
subparagraph (1) of this subsection (l), electric utilities
24
serving more than 200,000 customers as of January 1, 2021
25
shall provide the monetary credits to a subscriber's
26
subsequent bill for the electricity produced by community

SB3273 Enrolled
- 21 -
LRB104 18411 AAS 31853 b
1
renewable generation projects. The electric utility shall
2
provide monetary credits to a subscriber's subsequent bill at
3
the utility's total price to compare equal to the subscriber's
4
share of the production of electricity from the project, as
5
determined by paragraph (5) of this subsection (l). For the
6
purposes of this subsection, "total price to compare" means
7
the rate or rates published by the Illinois Commerce
8
Commission for energy supply for eligible customers receiving
9
supply service from the electric utility, and shall include
10
energy, capacity, transmission, and the purchased energy
11
adjustment. Notwithstanding anything to the contrary,
12
customers on payment plans or participating in budget billing
13
programs shall have credits applied on a monthly basis. Any
14
applicable credit or reduction in load obligation from the
15
production of the community renewable generating projects
16
receiving a credit under this subsection shall be credited to
17
the electric utility to offset the cost of providing the
18
credit. To the extent that the credit or load obligation
19
reduction does not completely offset the cost of providing the
20
credit to subscribers of community renewable generation
21
projects as described in this subsection, the electric utility
22
may recover the remaining costs through its Multi-Year Rate
23
Plan. All electric utilities serving 200,000 or fewer
24
customers as of January 1, 2021 shall only provide the
25
monetary credits to a subscriber's subsequent bill for the
26
electricity produced by community renewable generation

SB3273 Enrolled
- 22 -
LRB104 18411 AAS 31853 b
1
projects if the subscriber receives power and energy service
2
from the electric utility. Alternative retail electric
3
suppliers providing power and energy service to a subscriber
4
located within the service territory of an electric utility
5
not subject to Sections 16-108.18 and 16-118 shall provide the
6
monetary credits to the subscriber's subsequent bill for the
7
electricity produced by community renewable generation
8
projects.
9

(4) If requested by the owner or operator of a community
10
renewable generating project, an electric utility serving more
11
than 200,000 customers as of January 1, 2021 shall enter into a
12
net crediting agreement with the owner or operator to include
13
a subscriber's subscription fee on the subscriber's monthly
14
electric bill and provide the subscriber with a net credit
15
equivalent to the total bill credit value for that generation
16
period minus the subscription fee, provided the subscription
17
fee is structured as a fixed percentage of bill credit value.
18
The net crediting agreement shall set forth payment terms from
19
the electric utility to the owner or operator of the community
20
renewable generating project, and the electric utility may
21
charge a net crediting fee to the owner or operator of a
22
community renewable generating project that may not exceed 2%
23
of the bill credit value. Notwithstanding anything to the
24
contrary, an electric utility serving 200,000 customers or
25
fewer as of January 1, 2021 shall not be obligated to enter
26
into a net crediting agreement with the owner or operator of a

SB3273 Enrolled
- 23 -
LRB104 18411 AAS 31853 b
1
community renewable generating project.
2

(5) For the purposes of facilitating net metering, the
3
owner or operator of the eligible renewable electrical
4
generating facility or community renewable generation project
5
shall be responsible for determining the amount of the credit
6
that each customer or subscriber participating in a project
7
under this subsection (l) is to receive in the following
8
manner:
9

(A) The owner or operator shall, on a monthly basis,
10

provide to the electric utility the kilowatthours of
11

generation attributable to each of the utility's retail
12

customers and subscribers participating in projects under
13

this subsection (l) in accordance with the customer's or
14

subscriber's share of the eligible renewable electric
15

generating facility's or community renewable generation
16

project's output of power and energy for such month. The
17

owner or operator shall electronically transmit such
18

calculations and associated documentation to the electric
19

utility, in a format or method set forth in the applicable
20

tariff, on a monthly basis so that the electric utility
21

can reflect the monetary credits on customers' and
22

subscribers' electric utility bills. The electric utility
23

shall be permitted to revise its tariffs to implement the
24

provisions of this amendatory Act of the 102nd General
25

Assembly. The owner or operator shall separately provide
26

the electric utility with the documentation detailing the

SB3273 Enrolled
- 24 -
LRB104 18411 AAS 31853 b
1

calculations supporting the credit in the manner set forth
2

in the applicable tariff.
3

(B) For those participating customers and subscribers
4

who receive their energy supply from an alternative retail
5

electric supplier, the electric utility shall remit to the
6

applicable alternative retail electric supplier the
7

information provided under subparagraph (A) of this
8

paragraph (3) for such customers and subscribers in a
9

manner set forth in such alternative retail electric
10

supplier's net metering program, or as otherwise agreed
11

between the utility and the alternative retail electric
12

supplier. The alternative retail electric supplier shall
13

then submit to the utility the amount of the charges for
14

power and energy to be applied to such customers and
15

subscribers, including the amount of the credit associated
16

with net metering.
17

(C) A participating customer or subscriber may provide
18

authorization as required by applicable law that directs
19

the electric utility to submit information to the owner or
20

operator of the eligible renewable electrical generating
21

facility or community renewable generation project to
22

which the customer or subscriber has an ownership or
23

leasehold interest or a subscription. Such information
24

shall be limited to the components of the net metering
25

credit calculated under this subsection (l), including the
26

bill credit rate, total kilowatthours, and total monetary

SB3273 Enrolled
- 25 -
LRB104 18411 AAS 31853 b
1

credit value applied to the customer's or subscriber's
2

bill for the monthly billing period.
3

(l-5) Within 90 days after the effective date of this
4
amendatory Act of the 102nd General Assembly, each electric
5
utility subject to this Section shall file a tariff or tariffs
6
to implement the provisions of subsection (l) of this Section,
7
which shall, consistent with the provisions of subsection (l),
8
describe the terms and conditions under which owners or
9
operators of qualifying properties, units, or apartments may
10
participate in net metering. The Commission shall approve, or
11
approve with modification, the tariff within 120 days after
12
the effective date of this amendatory Act of the 102nd General
13
Assembly.
14

(m) Nothing in this Section shall affect the right of an
15
electricity provider to continue to provide, or the right of a
16
retail customer to continue to receive service pursuant to a
17
contract for electric service between the electricity provider
18
and the retail customer in accordance with the prices, terms,
19
and conditions provided for in that contract. Either the
20
electricity provider or the customer may require compliance
21
with the prices, terms, and conditions of the contract.
22

(n) On and after January 1, 2025, the net metering
23
services described in subsections (d), (d-5), and (e) of this
24
Section shall no longer be offered, except as to those
25
eligible renewable electrical generating facilities for which
26
retail customers are receiving net metering service under

SB3273 Enrolled
- 26 -
LRB104 18411 AAS 31853 b
1
these subsections at the time the net metering services under
2
those subsections are no longer offered; those systems shall
3
continue to receive net metering services described in
4
subsections (d), (d-5), and (e) of this Section for the
5
lifetime of the system, regardless of if those retail
6
customers change electricity providers or whether the retail
7
customer benefiting from the system changes. The electric
8
utility serving more than 200,000 customers as of January 1,
9
2021 is responsible for ensuring the billing credits continue
10
without lapse for the lifetime of systems, as required in
11
subsection (o). Those retail customers that begin taking net
12
metering service after the date that net metering services are
13
no longer offered under such subsections shall be subject to
14
the provisions set forth in the following paragraphs (1)
15
through (3) of this subsection (n):
16

(1) An electricity provider shall charge or credit for
17

the net electricity supplied to eligible customers or
18

provided by eligible customers whose electric supply
19

service is not provided based on hourly pricing in the
20

following manner:
21

(A) If the amount of electricity used by the
22

customer during the monthly billing period exceeds the
23

amount of electricity produced by the customer, then
24

the electricity provider shall charge the customer for
25

the net kilowatt-hour based electricity charges
26

reflected in the customer's electric service rate

SB3273 Enrolled
- 27 -
LRB104 18411 AAS 31853 b
1

supplied to and used by the customer as provided in
2

paragraph (3) of this subsection (n).
3

(B) If the amount of electricity produced by a
4

customer during the monthly billing period exceeds the
5

amount of electricity used by the customer during that
6

billing period, then the electricity provider
7

supplying that customer shall apply a 1:1
8

kilowatt-hour energy or monetary credit kilowatt-hour
9

supply charges to the customer's subsequent bill. The
10

customer shall choose between 1:1 kilowatt-hour or
11

monetary credit at the time of application. For the
12

purposes of this subsection, "kilowatt-hour supply
13

charges" means the kilowatt-hour equivalent values for
14

energy, capacity, transmission, and the purchased
15

energy adjustment, if applicable. Notwithstanding
16

anything to the contrary, customers on payment plans
17

or participating in budget billing programs shall have
18

credits applied on a monthly basis. The electricity
19

provider shall continue to carry over any excess
20

kilowatt-hour or monetary energy credits earned and
21

apply those credits to subsequent billing periods. For
22

customers with transmission or capacity charges not
23

charged on a kilowatt-hour basis, the electricity
24

provider shall prepare a reasonable approximation of
25

the kilowatt-hour equivalent value and provide that
26

value as a monetary credit. The electricity provider

SB3273 Enrolled
- 28 -
LRB104 18411 AAS 31853 b
1

shall submit these approximation methodologies to the
2

Commission for review, modification, and approval.
3

(C) (Blank).
4

(2) An electricity provider shall charge or credit for
5

the net electricity supplied to eligible customers or
6

provided by eligible customers whose electric supply
7

service is provided based on hourly pricing in the
8

following manner:
9

(A) If the amount of electricity used by the
10

customer during any hourly period exceeds the amount
11

of electricity produced by the customer, then the
12

electricity provider shall charge the customer for the
13

net electricity supplied to and used by the customer
14

as provided in paragraph (3) of this subsection (n).
15

(B) If the amount of electricity produced by a
16

customer during any hourly period exceeds the amount
17

of electricity used by the customer during that hourly
18

period, the energy provider shall calculate an energy
19

credit for the net kilowatt-hours produced in such
20

period, and shall apply that credit as a monetary
21

credit to the customer's subsequent bill. The value of
22

the energy credit shall be calculated using the same
23

price per kilowatt-hour as the electric service
24

provider would charge for kilowatt-hour energy sales
25

during that same hourly period and shall also include
26

values for capacity and transmission. For customers

SB3273 Enrolled
- 29 -
LRB104 18411 AAS 31853 b
1

with transmission or capacity charges not charged on a
2

kilowatt-hour basis, the electricity provider shall
3

prepare a reasonable approximation of the
4

kilowatt-hour equivalent value and provide that value
5

as a monetary credit. The electricity provider shall
6

submit these approximation methodologies to the
7

Commission for review, modification, and approval.
8

Notwithstanding anything to the contrary, customers on
9

payment plans or participating in budget billing
10

programs shall have credits applied on a monthly
11

basis.
12

(3) An electricity provider shall provide electric
13

service to eligible customers who utilize net metering at
14

non-discriminatory rates that are identical, with respect
15

to rate structure, retail rate components, and any monthly
16

charges, to the rates that the customer would be charged
17

if not a net metering customer. An electricity provider
18

shall charge the customer for the net electricity supplied
19

to and used by the customer according to the terms of the
20

contract or tariff to which the same customer would be
21

assigned or be eligible for if the customer was not a net
22

metering customer. An electricity provider shall not
23

charge net metering customers any fee or charge or require
24

additional equipment, insurance, or any other requirements
25

not specifically authorized by interconnection standards
26

authorized by the Commission, unless the fee, charge, or

SB3273 Enrolled
- 30 -
LRB104 18411 AAS 31853 b
1

other requirement would apply to other similarly situated
2

customers who are not net metering customers. The customer
3

remains responsible for the gross amount of delivery
4

services charges, supply-related charges that are kilowatt
5

based, and all taxes and fees related to such charges. The
6

customer also remains responsible for all taxes and fees
7

that would otherwise be applicable to the net amount of
8

electricity used by the customer. Paragraphs (1) and (2)
9

of this subsection (n) shall not be construed to prevent
10

an arms-length agreement between an electricity provider
11

and an eligible customer that sets forth different prices,
12

terms, and conditions for the provision of net metering
13

service, including, but not limited to, the provision of
14

the appropriate metering equipment for non-residential
15

customers. Nothing in this paragraph (3) shall be
16

interpreted to mandate that a utility that is only
17

required to provide delivery services to a given customer
18

must also sell electricity to such customer.
19

(o) Within 90 days after the effective date of this
20
amendatory Act of the 102nd General Assembly, each electric
21
utility subject to this Section shall file a tariff, which
22
shall, consistent with the provisions of this Section, propose
23
the terms and conditions under which a customer may
24
participate in net metering. The tariff for electric utilities
25
serving more than 200,000 customers as of January 1, 2021
26
shall also provide a streamlined and transparent bill

SB3273 Enrolled
- 31 -
LRB104 18411 AAS 31853 b
1
crediting system for net metering to be managed by the
2
electric utilities. The terms and conditions shall include,
3
but are not limited to, that an electric utility shall manage
4
and maintain billing of net metering credits and charges
5
regardless of if the eligible customer takes net metering
6
under an electric utility or alternative retail electric
7
supplier. The electric utility serving more than 200,000
8
customers as of January 1, 2021 shall process and approve all
9
net metering applications, even if an eligible customer is
10
served by an alternative retail electric supplier; and the
11
utility shall forward application approval to the appropriate
12
alternative retail electric supplier. Eligibility for net
13
metering shall remain with the owner of the utility billing
14
address such that, if an eligible renewable electrical
15
generating facility changes ownership, the net metering
16
eligibility transfers to the new owner. The electric utility
17
serving more than 200,000 customers as of January 1, 2021
18
shall manage net metering billing for eligible customers to
19
ensure full crediting occurs on electricity bills, including,
20
but not limited to, ensuring net metering crediting begins
21
upon commercial operation date, net metering billing transfers
22
immediately if an eligible customer switches from an electric
23
utility to alternative retail electric supplier or vice versa,
24
and net metering billing transfers between ownership of a
25
valid billing address. All transfers referenced in the
26
preceding sentence shall include transfer of all banked

SB3273 Enrolled
- 32 -
LRB104 18411 AAS 31853 b
1
credits. All electric utilities serving 200,000 or fewer
2
customers as of January 1, 2021 shall manage net metering
3
billing for eligible customers receiving power and energy
4
service from the electric utility to ensure full crediting
5
occurs on electricity bills, ensuring net metering crediting
6
begins upon commercial operation date, net metering billing
7
transfers immediately if an eligible customer switches from an
8
electric utility to alternative retail electric supplier or
9
vice versa, and net metering billing transfers between
10
ownership of a valid billing address. Alternative retail
11
electric suppliers providing power and energy service to
12
eligible customers located within the service territory of an
13
electric utility serving 200,000 or fewer customers as of
14
January 1, 2021 shall manage net metering billing for eligible
15
customers to ensure full crediting occurs on electricity
16
bills, including, but not limited to, ensuring net metering
17
crediting begins upon commercial operation date, net metering
18
billing transfers immediately if an eligible customer switches
19
from an electric utility to alternative retail electric
20
supplier or vice versa, and net metering billing transfers
21
between ownership of a valid billing address.
22
(Source: P.A. 102-662, eff. 9-15-21.)

23

(Text of Section after amendment by P.A. 104-458
)
24

Sec. 16-107.5.
Net electricity metering.
25

(a) The General Assembly finds and declares that a program

SB3273 Enrolled
- 33 -
LRB104 18411 AAS 31853 b
1
to provide net electricity metering, as defined in this
2
Section, for eligible customers can encourage private
3
investment in renewable energy resources, stimulate economic
4
growth, enhance the continued diversification of Illinois'
5
energy resource mix, and protect the Illinois environment.
6
Further, to achieve the goals of this Act that robust options
7
for customer-site distributed generation and storage continue
8
to thrive in Illinois, the General Assembly finds that a
9
predictable transition must be ensured for customers between
10
full net metering at the retail electricity rate to the
11
distribution generation rebate described in Section 16-107.6.
12

(b) As used in this Section:
13

(i) "Community renewable generation project" shall
14

have the meaning set forth in Section 1-10 of the Illinois
15

Power Agency Act.
16

(ii) "Eligible customer" means a retail customer that
17

owns, hosts, or operates, including any third-party owned
18

systems, a solar, wind, or other eligible renewable
19

electrical generating facility or an eligible storage
20

device that is located on the customer's premises or
21

customer's side of the billing meter and is intended
22

primarily to offset the customer's own current or future
23

electrical requirements.
24

(iii) "Electricity provider" means an electric utility
25

or alternative retail electric supplier.
26

(iv) "Eligible renewable electrical generating

SB3273 Enrolled
- 34 -
LRB104 18411 AAS 31853 b
1

facility" means a generator, which may include the
2

colocation of an energy storage system, that is
3

interconnected under rules adopted by the Commission and
4

is powered by solar electric energy, wind, dedicated crops
5

grown for electricity generation, agricultural residues,
6

untreated and unadulterated wood waste, livestock manure,
7

anaerobic digestion of livestock or food processing waste,
8

fuel cells or microturbines powered by renewable fuels, or
9

hydroelectric energy.
10

(v) "Net electricity metering" (or "net metering")
11

means the measurement, during the billing period
12

applicable to an eligible customer, of the net amount of
13

electricity supplied by an electricity provider to the
14

customer or provided to the electricity provider by the
15

customer or subscriber.
16

(vi) "Subscriber" shall have the meaning as set forth
17

in Section 1-10 of the Illinois Power Agency Act.
18

(vii) "Subscription" shall have the meaning set forth
19

in Section 1-10 of the Illinois Power Agency Act.
20

(viii) "Energy storage system" means commercially
21

available technology that is capable of absorbing energy
22

and storing it for a period of time for use at a later
23

time, including, but not limited to, electrochemical,
24

thermal, and electromechanical technologies, and may be
25

interconnected behind the customer's meter or
26

interconnected behind its own meter.

SB3273 Enrolled
- 35 -
LRB104 18411 AAS 31853 b
1

(ix) "Future electrical requirements" means modeled
2

electrical requirements upon occupation of a new or vacant
3

property, and other reasonable expectations of future
4

electrical use, as well as, for occupied properties, a
5

reasonable approximation of the annual load of 2 electric
6

vehicles and, for non-electric heating customers, a
7

reasonable approximation of the incremental electric load
8

associated with fuel switching. The approximations shall
9

be applied to the appropriate net metering tariff and do
10

not need to be unique to each individual eligible
11

customer. The utility shall submit these approximations to
12

the Commission for review, modification, and approval.
13

(x) "Vehicle storage system" means a vehicle that when
14

connected to an electric utility's distribution system is
15

capable of being an energy storage system, as defined in
16

Section 16-107.6.
17

(c) A net metering facility shall be equipped with
18
metering equipment that can measure the flow of electricity in
19
both directions at the same rate.
20

(1) For eligible customers whose electric service has
21

not been declared competitive pursuant to Section 16-113
22

of this Act as of July 1, 2011 and whose electric delivery
23

service is provided and measured on a kilowatt-hour basis
24

and electric supply service is not provided based on
25

hourly pricing, this shall typically be accomplished
26

through use of a single, bi-directional meter. If the

SB3273 Enrolled
- 36 -
LRB104 18411 AAS 31853 b
1

eligible customer's existing electric revenue meter does
2

not meet this requirement, the electricity provider shall
3

arrange for the local electric utility or a meter service
4

provider to install and maintain a new revenue meter at
5

the electricity provider's expense, which may be the smart
6

meter described by subsection (b) of Section 16-108.5 of
7

this Act.
8

(2) For eligible customers whose electric service has
9

not been declared competitive pursuant to Section 16-113
10

of this Act as of July 1, 2011 and whose electric delivery
11

service is provided and measured on a kilowatt demand
12

basis and electric supply service is not provided based on
13

hourly pricing, this shall typically be accomplished
14

through use of a dual channel meter capable of measuring
15

the flow of electricity both into and out of the
16

customer's facility at the same rate and ratio. If such
17

customer's existing electric revenue meter does not meet
18

this requirement, then the electricity provider shall
19

arrange for the local electric utility or a meter service
20

provider to install and maintain a new revenue meter at
21

the electricity provider's expense, which may be the smart
22

meter described by subsection (b) of Section 16-108.5 of
23

this Act.
24

(3) For all other eligible customers, until such time
25

as the local electric utility installs a smart meter, as
26

described by subsection (b) of Section 16-108.5 of this

SB3273 Enrolled
- 37 -
LRB104 18411 AAS 31853 b
1

Act, the electricity provider may arrange for the local
2

electric utility or a meter service provider to install
3

and maintain metering equipment capable of measuring the
4

flow of electricity both into and out of the customer's
5

facility at the same rate and ratio, typically through the
6

use of a dual channel meter. If the eligible customer's
7

existing electric revenue meter does not meet this
8

requirement, then the costs of installing such equipment
9

shall be paid for by the customer.
10

(d) An electricity provider shall measure and charge or
11
credit for the net electricity supplied to eligible customers
12
or provided by eligible customers whose electric service has
13
not been declared competitive pursuant to Section 16-113 of
14
this Act as of July 1, 2011 and whose electric delivery service
15
is provided and measured on a kilowatt-hour basis and electric
16
supply service is not provided based on hourly pricing in the
17
following manner:
18

(1) If the amount of electricity used by the customer
19

during the billing period exceeds the amount of
20

electricity produced by the customer, the electricity
21

provider shall charge the customer for the net electricity
22

supplied to and used by the customer as provided in
23

subsection (e-5) of this Section.
24

(2) If the amount of electricity produced by a
25

customer during the billing period exceeds the amount of
26

electricity used by the customer during that billing

SB3273 Enrolled
- 38 -
LRB104 18411 AAS 31853 b
1

period, the electricity provider supplying that customer
2

shall apply a 1:1 kilowatt-hour credit to a subsequent
3

bill for service to the customer for the net electricity
4

supplied to the electricity provider. The electricity
5

provider shall continue to carry over any excess
6

kilowatt-hour credits earned and apply those credits to
7

subsequent billing periods to offset any
8

customer-generator consumption in those billing periods
9

until all credits are used or until the end of the
10

annualized period.
11

(3) At the end of the year or annualized over the
12

period that service is supplied by means of net metering,
13

or in the event that the retail customer terminates
14

service with the electricity provider prior to the end of
15

the year or the annualized period, any remaining credits
16

in the customer's account shall expire.
17

(d-5) An electricity provider shall measure and charge or
18
credit for the net electricity supplied to eligible customers
19
or provided by eligible customers whose electric service has
20
not been declared competitive pursuant to Section 16-113 of
21
this Act as of July 1, 2011 and whose electric delivery service
22
is provided and measured on a kilowatt-hour basis and electric
23
supply service is provided based on hourly pricing or
24
time-of-use rates in the following manner:
25

(1) If the amount of electricity used by the customer
26

during any hourly period or time-of-use period exceeds the

SB3273 Enrolled
- 39 -
LRB104 18411 AAS 31853 b
1

amount of electricity produced by the customer, the
2

electricity provider shall charge the customer for the net
3

electricity supplied to and used by the customer according
4

to the terms of the contract or tariff to which the same
5

customer would be assigned to or be eligible for if the
6

customer was not a net metering customer.
7

(2) If the amount of electricity produced by a
8

customer during any hourly period or time-of-use period
9

exceeds the amount of electricity used by the customer
10

during that hourly period or time-of-use period, the
11

energy provider shall apply a credit for the net
12

kilowatt-hours produced in such period. The credit shall
13

consist of an energy credit and a delivery service credit.
14

The energy credit shall be valued at the same price per
15

kilowatt-hour as the electric service provider would
16

charge for kilowatt-hour energy sales during that same
17

hourly period or time-of-use period. The delivery credit
18

shall be equal to the net kilowatt-hours produced in such
19

hourly period or time-of-use period times a credit that
20

reflects all kilowatt-hour based charges in the customer's
21

electric service rate, excluding energy charges.
22

(e) An electricity provider shall measure and charge or
23
credit for the net electricity supplied to eligible customers
24
whose electric service has not been declared competitive
25
pursuant to Section 16-113 of this Act as of July 1, 2011 and
26
whose electric delivery service is provided and measured on a

SB3273 Enrolled
- 40 -
LRB104 18411 AAS 31853 b
1
kilowatt demand basis and electric supply service is not
2
provided based on hourly pricing in the following manner:
3

(1) If the amount of electricity used by the customer
4

during the billing period exceeds the amount of
5

electricity produced by the customer, then the electricity
6

provider shall charge the customer for the net electricity
7

supplied to and used by the customer as provided in
8

subsection (e-5) of this Section. The customer shall
9

remain responsible for all taxes, fees, and utility
10

delivery charges that would otherwise be applicable to the
11

net amount of electricity used by the customer.
12

(2) If the amount of electricity produced by a
13

customer during the billing period exceeds the amount of
14

electricity used by the customer during that billing
15

period, then the electricity provider supplying that
16

customer shall apply a 1:1 kilowatt-hour credit that
17

reflects the kilowatt-hour based charges in the customer's
18

electric service rate to a subsequent bill for service to
19

the customer for the net electricity supplied to the
20

electricity provider. The electricity provider shall
21

continue to carry over any excess kilowatt-hour credits
22

earned and apply those credits to subsequent billing
23

periods to offset any customer-generator consumption in
24

those billing periods until all credits are used or until
25

the end of the annualized period.
26

(3) At the end of the year or annualized over the

SB3273 Enrolled
- 41 -
LRB104 18411 AAS 31853 b
1

period that service is supplied by means of net metering,
2

or in the event that the retail customer terminates
3

service with the electricity provider prior to the end of
4

the year or the annualized period, any remaining credits
5

in the customer's account shall expire.
6

(e-5) An electricity provider shall provide electric
7
service to eligible customers who utilize net metering at
8
non-discriminatory rates that are identical, with respect to
9
rate structure, retail rate components, and any monthly
10
charges, to the rates that the customer would be charged if not
11
a net metering customer. An electricity provider shall not
12
charge net metering customers any fee or charge or require
13
additional equipment, insurance, or any other requirements not
14
specifically authorized by interconnection standards
15
authorized by the Commission, unless the fee, charge, or other
16
requirement would apply to other similarly situated customers
17
who are not net metering customers. The customer will remain
18
responsible for all taxes, fees, and utility delivery charges
19
that would otherwise be applicable to the net amount of
20
electricity used by the customer. Subsections (c) through (e)
21
of this Section shall not be construed to prevent an
22
arms-length agreement between an electricity provider and an
23
eligible customer that sets forth different prices, terms, and
24
conditions for the provision of net metering service,
25
including, but not limited to, the provision of the
26
appropriate metering equipment for non-residential customers.

SB3273 Enrolled
- 42 -
LRB104 18411 AAS 31853 b
1

(f) Notwithstanding the requirements of subsections (c)
2
through (e-5) of this Section, an electricity provider must
3
require dual-channel metering for customers operating eligible
4
renewable electrical generating facilities to whom the
5
provisions of neither subsection (d), (d-5), nor (e) of this
6
Section apply. In such cases, electricity charges and credits
7
shall be determined as follows:
8

(1) The electricity provider shall assess and the
9

customer remains responsible for all taxes, fees, and
10

utility delivery charges that would otherwise be
11

applicable to the gross amount of kilowatt-hours supplied
12

to the eligible customer by the electricity provider.
13

(2) Each month that service is supplied by means of
14

dual-channel metering, the electricity provider shall
15

compensate the eligible customer for any excess
16

kilowatt-hour credits at the electricity provider's
17

avoided cost of electricity supply over the monthly period
18

or as otherwise specified by the terms of a power-purchase
19

agreement negotiated between the customer and electricity
20

provider.
21

(3) For all eligible net metering customers taking
22

service from an electricity provider under contracts or
23

tariffs employing hourly or time-of-use rates, any monthly
24

consumption of electricity shall be calculated according
25

to the terms of the contract or tariff to which the same
26

customer would be assigned to or be eligible for if the

SB3273 Enrolled
- 43 -
LRB104 18411 AAS 31853 b
1

customer was not a net metering customer. When those same
2

customer-generators are net generators during any discrete
3

hourly or time-of-use period, the net kilowatt-hours
4

produced shall be valued at the same price per
5

kilowatt-hour as the electric service provider would
6

charge for retail kilowatt-hour sales during that same
7

time-of-use period.
8

(g) For purposes of federal and State laws providing
9
renewable energy credits or greenhouse gas credits, the
10
eligible customer shall be treated as owning and having title
11
to the renewable energy attributes, renewable energy credits,
12
and greenhouse gas emission credits related to any electricity
13
produced by the qualified generating unit. The electricity
14
provider may not condition participation in a net metering
15
program on the signing over of a customer's renewable energy
16
credits; provided, however, this subsection (g) shall not be
17
construed to prevent an arms-length agreement between an
18
electricity provider and an eligible customer that sets forth
19
the ownership or title of the credits.
20

(h) Within 120 days after the effective date of this
21
amendatory Act of the 95th General Assembly, the Commission
22
shall establish standards for net metering and, if the
23
Commission has not already acted on its own initiative,
24
standards for the interconnection of eligible renewable
25
generating equipment to the utility system. The
26
interconnection standards shall address any procedural

SB3273 Enrolled
- 44 -
LRB104 18411 AAS 31853 b
1
barriers, delays, and administrative costs associated with the
2
interconnection of customer-generation while ensuring the
3
safety and reliability of the units and the electric utility
4
system. The Commission shall consider the Institute of
5
Electrical and Electronics Engineers (IEEE) Standard 1547 and
6
the issues of (i) reasonable and fair fees and costs, (ii)
7
clear timelines for major milestones in the interconnection
8
process, (iii) nondiscriminatory terms of agreement, and (iv)
9
any best practices for interconnection of distributed
10
generation.
11

(h-7) After an electric distribution company determines
12
that an interconnection request from an applicant for a public
13
school project has been completed, the electric distribution
14
company must immediately begin all evaluations, reviews, and
15
screenings of the interconnection request. Projects pending in
16
the interconnection queue on the same feeder and substation as
17
an interconnection request for a public school project shall
18
be paused until the public school project has received a fully
19
executed interconnection agreement, regardless of queue
20
position assignments under 83 Ill. Adm. Code 466, to ensure
21
that available feeder and substation capacity is reserved for
22
the public school project. If the electric distribution
23
company determines that there is no requirement for the
24
construction of facilities by the electric distribution
25
company on its own system, the electric distribution company
26
shall provide the applicant with an interconnection agreement,

SB3273 Enrolled
- 45 -
LRB104 18411 AAS 31853 b
1
as provided under 83 Ill. Adm. Code 466. If the electric
2
distribution company determines that the public school project
3
has a nameplate capacity that is less than 500 kilowatts (kW)
4
with no colocated distribution resources and determines that
5
no system modifications are required, the electric
6
distribution company must complete all required
7
interconnection-related evaluations, reviews, and screenings
8
within 30 days after making such a determination and issue an
9
interconnection agreement as soon as possible after the
10
evaluations, reviews, and screenings are completed. If the
11
electric distribution company determines that only minor
12
system modifications are required, the electric distribution
13
company shall provide the applicant with an interconnection
14
agreement within 60 days after the applicant elects to
15
continue the application and pays any necessary fees or costs
16
required under 83 Ill. Adm. Code 466. If the electric
17
distribution company determines that more than minor
18
modifications are required, the electric distribution company
19
shall provide the applicant with an interconnection agreement
20
within 90 days after the applicant elects to continue the
21
application and pays any necessary fees or costs required
22
under 83 Ill. Adm. Code 466.
23

For all net metering credits earned on a monthly basis or
24
other credits owed to a customer who has elected to install a
25
distributed renewable generation project on public school
26
land, all credits intended for the benefit of the consumer

SB3273 Enrolled
- 46 -
LRB104 18411 AAS 31853 b
1
must be credited by the public utility or retail energy
2
supplier within 90 days after the public utility or retail
3
energy supplier determines that the criteria for the credit
4
have been met.

5

As soon as practicable after the effective date of this
6
amendatory Act of the 104th General Assembly, the Commission
7
shall adopt revisions to its standards for the interconnection
8
of eligible renewable generating equipment and net metering
9
credit rules to conform with the requirements of this
10
amendatory Act of the 104th General Assembly.
11

As used in this subsection:
12

"Electric distribution company" means any electric utility
13
subject to the jurisdiction of the Commission serving more
14
than 100,000 customers in this State.
15

"Public schools" has the meaning set forth in Section 1-3
16
of the School Code and includes public institutions of higher
17
education, as defined in the Board of Higher Education Act.
18

"Public school project" means a renewable electrical
19
generating facility that is located on the premises of a
20
public school on the customer's side of the billing meter, is
21
intended primarily to offset the customer's current or future
22
electrical requirements, and is eligible only for renewable
23
energy credits apportioned to distributed renewable generation
24
devices installed on public school land under subparagraph
25
(iv) of paragraph (K) of subsection (c) of Section 1-75 of the
26
Illinois Power Agency Act.

SB3273 Enrolled
- 47 -
LRB104 18411 AAS 31853 b
1

(i) All electricity providers shall begin to offer net
2
metering no later than April 1, 2008.
3

(j) An electricity provider shall provide net metering to
4
eligible customers according to subsections (d), (d-5), and
5
(e). Eligible renewable electrical generating facilities for
6
which eligible customers registered for net metering before
7
January 1, 2025 shall continue to receive net metering
8
services according to subsections (d), (d-5), and (e) of this
9
Section for the lifetime of the system, regardless of whether
10
those retail customers change electricity providers or whether
11
the retail customer benefiting from the system changes. On and
12
after January 1, 2025, any eligible customer that applies for
13
net metering and previously would have qualified under
14
subsections (d), (d-5), or (e) shall only be eligible for net
15
metering as described in subsection (n).
16

(k) Each electricity provider shall maintain records and
17
report annually to the Commission the total number of net
18
metering customers served by the provider, as well as the
19
type, capacity, and energy sources of the generating systems
20
used by the net metering customers. Nothing in this Section
21
shall limit the ability of an electricity provider to request
22
the redaction of information deemed by the Commission to be
23
confidential business information.
24

(l)(1) Notwithstanding the definition of "eligible
25
customer" in item (ii) of subsection (b) of this Section, each
26
electricity provider shall allow net metering as set forth in

SB3273 Enrolled
- 48 -
LRB104 18411 AAS 31853 b
1
this subsection (l) and for the following projects, provided
2
that only electric utilities serving more than 200,000
3
customers as of January 1, 2021 shall provide net metering for
4
projects that are eligible for subparagraph (C) of this
5
paragraph (1) and have energized after the effective date of
6
this amendatory Act of the 102nd General Assembly:
7

(A) properties owned or leased by multiple customers
8

that contribute to the operation of an eligible renewable
9

electrical generating facility through an ownership or
10

leasehold interest of at least 200 watts in such facility,
11

such as a community-owned wind project, a community-owned
12

biomass project, a community-owned solar project, or a
13

community methane digester processing livestock waste from
14

multiple sources, provided that the facility is also
15

located within the utility's service territory;
16

(B) individual units, apartments, or properties
17

located in a single building that are owned or leased by
18

multiple customers and collectively served by a common
19

eligible renewable electrical generating facility, such as
20

an office or apartment building, a shopping center or
21

strip mall served by photovoltaic panels on the roof; and
22

(C) subscriptions to community renewable generation
23

projects, including community renewable generation
24

projects on the customer's side of the billing meter of a
25

host facility and partially used for the customer's own
26

load.

SB3273 Enrolled
- 49 -
LRB104 18411 AAS 31853 b
1

In addition, the nameplate capacity of the eligible
2
renewable electric generating facility that serves the demand
3
of the properties, units, or apartments identified in
4
paragraphs (1) and (2) of this subsection (l) shall not exceed
5
5,000 kilowatts in nameplate capacity in total. Any eligible
6
renewable electrical generating facility or community
7
renewable generation project that is powered by photovoltaic
8
electric energy and installed after the effective date of this
9
amendatory Act of the 99th General Assembly must be installed
10
by a qualified person in compliance with the requirements of
11
Section 16-128A of the Public Utilities Act and any rules or
12
regulations adopted thereunder.
13

(2) Notwithstanding anything to the contrary, an
14
electricity provider shall provide credits for the electricity
15
produced by the projects described in paragraph (1) of this
16
subsection (l). The electricity provider shall provide credits
17
that include at least energy supply, capacity, transmission,
18
and, if applicable, the purchased energy adjustment on the
19
subscriber's monthly bill equal to the subscriber's share of
20
the production of electricity from the project, as determined
21
by paragraph (3) of this subsection (l). For customers with
22
transmission or capacity charges not charged on a
23
kilowatt-hour basis, the electricity provider shall prepare a
24
reasonable approximation of the kilowatt-hour equivalent value
25
and provide that value as a monetary credit. The electricity
26
provider shall submit these approximation methodologies to the

SB3273 Enrolled
- 50 -
LRB104 18411 AAS 31853 b
1
Commission for review, modification, and approval.
2
Notwithstanding anything to the contrary, customers on payment
3
plans or participating in budget billing programs shall have
4
credits applied on a monthly basis.
5

(3) Notwithstanding anything to the contrary and
6
regardless of whether a subscriber to an eligible community
7
renewable generation project receives power and energy service
8
from the electric utility or an alternative retail electric
9
supplier, for projects eligible under paragraph (C) of
10
subparagraph (1) of this subsection (l), electric utilities
11
serving more than 200,000 customers as of January 1, 2021
12
shall provide the monetary credits to a subscriber's
13
subsequent bill for the electricity produced by community
14
renewable generation projects. The electric utility shall
15
provide monetary credits to a subscriber's subsequent bill at
16
the utility's total price to compare equal to the subscriber's
17
share of the production of electricity from the project, as
18
determined by paragraph (5) of this subsection (l). For the
19
purposes of this subsection, "total price to compare" means
20
the rate or rates published by the Illinois Commerce
21
Commission for energy supply for eligible customers receiving
22
supply service from the electric utility, and shall include
23
energy, capacity, transmission, and the purchased energy
24
adjustment. Notwithstanding anything to the contrary,
25
customers on payment plans or participating in budget billing
26
programs shall have credits applied on a monthly basis. Any

SB3273 Enrolled
- 51 -
LRB104 18411 AAS 31853 b
1
applicable credit or reduction in load obligation from the
2
production of the community renewable generating projects
3
receiving a credit under this subsection shall be credited to
4
the electric utility to offset the cost of providing the
5
credit. To the extent that the credit or load obligation
6
reduction does not completely offset the cost of providing the
7
credit to subscribers of community renewable generation
8
projects as described in this subsection, the electric utility
9
may recover the remaining costs through its Multi-Year Rate
10
Plan. All electric utilities serving 200,000 or fewer
11
customers as of January 1, 2021 shall only provide the
12
monetary credits to a subscriber's subsequent bill for the
13
electricity produced by community renewable generation
14
projects if the subscriber receives power and energy service
15
from the electric utility. Alternative retail electric
16
suppliers providing power and energy service to a subscriber
17
located within the service territory of an electric utility
18
not subject to Sections 16-108.18 and 16-118 shall provide the
19
monetary credits to the subscriber's subsequent bill for the
20
electricity produced by community renewable generation
21
projects.
22

(4) If requested by the owner or operator of a community
23
renewable generating project, an electric utility serving more
24
than 200,000 customers as of January 1, 2021 shall enter into a
25
net crediting agreement with the owner or operator to include
26
a subscriber's subscription fee on the subscriber's monthly

SB3273 Enrolled
- 52 -
LRB104 18411 AAS 31853 b
1
electric bill and provide the subscriber with a net credit
2
equivalent to the total bill credit value for that generation
3
period minus the subscription fee, provided the subscription
4
fee is structured as a fixed percentage of bill credit value.
5
The net crediting agreement shall set forth payment terms from
6
the electric utility to the owner or operator of the community
7
renewable generating project, and the electric utility may
8
charge a net crediting fee to the owner or operator of a
9
community renewable generating project that may not exceed 1%
10
of the subscription fee. Notwithstanding anything to the
11
contrary, an electric utility serving 200,000 customers or
12
fewer as of January 1, 2021 shall not be obligated to enter
13
into a net crediting agreement with the owner or operator of a
14
community renewable generating project. An electric utility
15
shall use the same net crediting format for subscribers on
16
payment plans and subscribers participating in budget billing
17
programs. For the purposes of this paragraph (4), "net
18
crediting" means a program offered by an electric utility
19
under which the electric utility, upon authorization by or on
20
behalf of a subscriber, remits the cash value of the
21
subscription fee to the owner or operator of the community
22
renewable generation facility without regard to whether the
23
subscriber has paid the subscriber's monthly electric bill and
24
places the cash value of the remaining bill credit on the
25
subscriber's bill.
26

(5) For the purposes of facilitating net metering, the

SB3273 Enrolled
- 53 -
LRB104 18411 AAS 31853 b
1
owner or operator of the eligible renewable electrical
2
generating facility or community renewable generation project
3
shall be responsible for determining the amount of the credit
4
that each customer or subscriber participating in a project
5
under this subsection (l) is to receive in the following
6
manner:
7

(A) The owner or operator shall, on a monthly basis,
8

provide to the electric utility the kilowatthours of
9

generation attributable to each of the utility's retail
10

customers and subscribers participating in projects under
11

this subsection (l) in accordance with the customer's or
12

subscriber's share of the eligible renewable electric
13

generating facility's or community renewable generation
14

project's output of power and energy for such month. The
15

owner or operator shall electronically transmit such
16

calculations and associated documentation to the electric
17

utility, in a format or method set forth in the applicable
18

tariff, on a monthly basis so that the electric utility
19

can reflect the monetary credits on customers' and
20

subscribers' electric utility bills. The electric utility
21

shall be permitted to revise its tariffs to implement the
22

provisions of this amendatory Act of the 102nd General
23

Assembly. The owner or operator shall separately provide
24

the electric utility with the documentation detailing the
25

calculations supporting the credit in the manner set forth
26

in the applicable tariff.

SB3273 Enrolled
- 54 -
LRB104 18411 AAS 31853 b
1

(B) For those participating customers and subscribers
2

who receive their energy supply from an alternative retail
3

electric supplier, the electric utility shall remit to the
4

applicable alternative retail electric supplier the
5

information provided under subparagraph (A) of this
6

paragraph (3) for such customers and subscribers in a
7

manner set forth in such alternative retail electric
8

supplier's net metering program, or as otherwise agreed
9

between the utility and the alternative retail electric
10

supplier. The alternative retail electric supplier shall
11

then submit to the utility the amount of the charges for
12

power and energy to be applied to such customers and
13

subscribers, including the amount of the credit associated
14

with net metering.
15

(C) A participating customer or subscriber may provide
16

authorization as required by applicable law that directs
17

the electric utility to submit information to the owner or
18

operator of the eligible renewable electrical generating
19

facility or community renewable generation project to
20

which the customer or subscriber has an ownership or
21

leasehold interest or a subscription. Such information
22

shall be limited to the components of the net metering
23

credit calculated under this subsection (l), including the
24

bill credit rate, total kilowatthours, and total monetary
25

credit value applied to the customer's or subscriber's
26

bill for the monthly billing period.

SB3273 Enrolled
- 55 -
LRB104 18411 AAS 31853 b
1

(l-5) Within 90 days after the effective date of this
2
amendatory Act of the 102nd General Assembly, each electric
3
utility subject to this Section shall file a tariff or tariffs
4
to implement the provisions of subsection (l) of this Section,
5
which shall, consistent with the provisions of subsection (l),
6
describe the terms and conditions under which owners or
7
operators of qualifying properties, units, or apartments may
8
participate in net metering. The Commission shall approve, or
9
approve with modification, the tariff within 120 days after
10
the effective date of this amendatory Act of the 102nd General
11
Assembly.
12

(l-10) Within 30 days after the effective date of this
13
amendatory Act of the 104th General Assembly, each electricity
14
provider shall modify its tariffs to allow net metering as set
15
forth in this subsection for an energy storage system or
16
vehicle storage system energized after the effective date of
17
this amendatory Act of the 104th General Assembly with a
18
nameplate capacity of not more than 5,000 kilowatts. If the
19
Commission chooses to suspend the modified tariffs, the
20
Commission shall issue a final order approving, or approving
21
with modification, the modified tariffs no later than 90 days
22
after the Commission initiates the docket.
23

An energy storage system or vehicle storage system
24
eligible for net metering under this subsection may be
25
interconnected behind the meter of a retail customer or at the
26
distribution system level of an electric utility as follows:

SB3273 Enrolled
- 56 -
LRB104 18411 AAS 31853 b
1

(A) if the energy storage system or vehicle storage
2

system is interconnected behind the meter of a retail
3

customer, in order to receive net metering under this
4

subsection, the eligible customer behind whose meter the
5

energy storage system is interconnected must receive
6

service from an electricity provider under an hourly
7

supply tariff, a time-of-use supply tariff, or a
8

time-of-use contract with an alternative retail electric
9

supplier; or
10

(B) if the energy storage system or vehicle storage
11

system is interconnected at the distribution system level
12

of an electric utility and not behind the meter of a retail
13

customer, the energy storage system or vehicle storage
14

system must receive service from an electricity provider
15

as a retail customer under an hourly supply tariff
16

authorized by Section 16-107, a supply tariff or contract
17

on substantially similar terms and conditions with an
18

alternative retail electric supplier, a time-of-use supply
19

tariff, or a time-of-use supply contract with an
20

alternative retail electric supplier.
21

If the energy storage system or vehicle storage system is
22
interconnected behind the meter of an eligible customer, the
23
eligible customer shall receive net metering based on hourly
24
or time-of-use rates in accordance with the terms of
25
subsection (d-5) or (f) or paragraph (2) of subsection (n) of
26
this Section, as applicable to the eligible customer. If the

SB3273 Enrolled
- 57 -
LRB104 18411 AAS 31853 b
1
energy storage system or vehicle storage system is
2
interconnected at the distribution system level of an electric
3
utility and not behind the meter of a retail customer, then the
4
energy storage system or vehicle storage system shall receive
5
net metering pursuant to the terms of subsection (f) of this
6
Section.
7

(m) Nothing in this Section shall affect the right of an
8
electricity provider to continue to provide, or the right of a
9
retail customer to continue to receive service pursuant to a
10
contract for electric service between the electricity provider
11
and the retail customer in accordance with the prices, terms,
12
and conditions provided for in that contract. Either the
13
electricity provider or the customer may require compliance
14
with the prices, terms, and conditions of the contract.
15

(n) On and after January 1, 2025, the net metering
16
services described in subsections (d), (d-5), and (e) of this
17
Section shall no longer be offered, except as to those
18
eligible renewable electrical generating facilities for which
19
retail customers are receiving net metering service under
20
these subsections at the time the net metering services under
21
those subsections are no longer offered; those systems shall
22
continue to receive net metering services described in
23
subsections (d), (d-5), and (e) of this Section for the
24
lifetime of the system, regardless of if those retail
25
customers change electricity providers or whether the retail
26
customer benefiting from the system changes. The electric

SB3273 Enrolled
- 58 -
LRB104 18411 AAS 31853 b
1
utility serving more than 200,000 customers as of January 1,
2
2021 is responsible for ensuring the billing credits continue
3
without lapse for the lifetime of systems, as required in
4
subsection (o). Those retail customers that begin taking net
5
metering service after the date that net metering services are
6
no longer offered under such subsections shall be subject to
7
the provisions set forth in the following paragraphs (1)
8
through (3) of this subsection (n):
9

(1) An electricity provider shall charge or credit for
10

the net electricity supplied to eligible customers or
11

provided by eligible customers whose electric supply
12

service is not provided based on hourly pricing in the
13

following manner:
14

(A) If the amount of electricity used by the
15

customer during the monthly billing period exceeds the
16

amount of electricity produced by the customer, then
17

the electricity provider shall charge the customer for
18

the net kilowatt-hour based electricity charges
19

reflected in the customer's electric service rate
20

supplied to and used by the customer as provided in
21

paragraph (3) of this subsection (n).
22

(B) If the amount of electricity produced by a
23

customer during the monthly billing period exceeds the
24

amount of electricity used by the customer during that
25

billing period, then the electricity provider
26

supplying that customer shall apply a 1:1

SB3273 Enrolled
- 59 -
LRB104 18411 AAS 31853 b
1

kilowatt-hour energy or monetary credit kilowatt-hour
2

supply charges to the customer's subsequent bill. The
3

customer shall choose between 1:1 kilowatt-hour or
4

monetary credit at the time of application. For the
5

purposes of this subsection, "kilowatt-hour supply
6

charges" means the kilowatt-hour equivalent values for
7

energy, capacity, transmission, and the purchased
8

energy adjustment, if applicable. Notwithstanding
9

anything to the contrary, customers on payment plans
10

or participating in budget billing programs shall have
11

credits applied on a monthly basis. The electricity
12

provider shall continue to carry over any excess
13

kilowatt-hour or monetary energy credits earned and
14

apply those credits to subsequent billing periods. For
15

customers with transmission or capacity charges not
16

charged on a kilowatt-hour basis, the electricity
17

provider shall prepare a reasonable approximation of
18

the kilowatt-hour equivalent value and provide that
19

value as a monetary credit. The electricity provider
20

shall submit these approximation methodologies to the
21

Commission for review, modification, and approval.
22

(C) (Blank).
23

(2) An electricity provider shall charge or credit for
24

the net electricity supplied to eligible customers or
25

provided by eligible customers whose electric supply
26

service is provided based on hourly pricing in the

SB3273 Enrolled
- 60 -
LRB104 18411 AAS 31853 b
1

following manner:
2

(A) If the amount of electricity used by the
3

customer during any hourly period exceeds the amount
4

of electricity produced by the customer, then the
5

electricity provider shall charge the customer for the
6

net electricity supplied to and used by the customer
7

as provided in paragraph (3) of this subsection (n).
8

(B) If the amount of electricity produced by a
9

customer during any hourly period exceeds the amount
10

of electricity used by the customer during that hourly
11

period, the energy provider shall calculate an energy
12

credit for the net kilowatt-hours produced in such
13

period, and shall apply that credit as a monetary
14

credit to the customer's subsequent bill. The value of
15

the energy credit shall be calculated using the same
16

price per kilowatt-hour as the electric service
17

provider would charge for kilowatt-hour energy sales
18

during that same hourly period and shall also include
19

values for capacity and transmission. For customers
20

with transmission or capacity charges not charged on a
21

kilowatt-hour basis, the electricity provider shall
22

prepare a reasonable approximation of the
23

kilowatt-hour equivalent value and provide that value
24

as a monetary credit. The electricity provider shall
25

submit these approximation methodologies to the
26

Commission for review, modification, and approval.

SB3273 Enrolled
- 61 -
LRB104 18411 AAS 31853 b
1

Notwithstanding anything to the contrary, customers on
2

payment plans or participating in budget billing
3

programs shall have credits applied on a monthly
4

basis.
5

(3) An electricity provider shall provide electric
6

service to eligible customers who utilize net metering at
7

non-discriminatory rates that are identical, with respect
8

to rate structure, retail rate components, and any monthly
9

charges, to the rates that the customer would be charged
10

if not a net metering customer. An electricity provider
11

shall charge the customer for the net electricity supplied
12

to and used by the customer according to the terms of the
13

contract or tariff to which the same customer would be
14

assigned or be eligible for if the customer was not a net
15

metering customer. An electricity provider shall not
16

charge net metering customers any fee or charge or require
17

additional equipment, insurance, or any other requirements
18

not specifically authorized by interconnection standards
19

authorized by the Commission, unless the fee, charge, or
20

other requirement would apply to other similarly situated
21

customers who are not net metering customers. The customer
22

remains responsible for the gross amount of delivery
23

services charges, supply-related charges that are kilowatt
24

based, and all taxes and fees related to such charges. The
25

customer also remains responsible for all taxes and fees
26

that would otherwise be applicable to the net amount of

SB3273 Enrolled
- 62 -
LRB104 18411 AAS 31853 b
1

electricity used by the customer. Paragraphs (1) and (2)
2

of this subsection (n) shall not be construed to prevent
3

an arms-length agreement between an electricity provider
4

and an eligible customer that sets forth different prices,
5

terms, and conditions for the provision of net metering
6

service, including, but not limited to, the provision of
7

the appropriate metering equipment for non-residential
8

customers. Nothing in this paragraph (3) shall be
9

interpreted to mandate that a utility that is only
10

required to provide delivery services to a given customer
11

must also sell electricity to such customer.
12

(o) Within 90 days after the effective date of this
13
amendatory Act of the 102nd General Assembly, each electric
14
utility subject to this Section shall file a tariff, which
15
shall, consistent with the provisions of this Section, propose
16
the terms and conditions under which a customer may
17
participate in net metering. The tariff for electric utilities
18
serving more than 200,000 customers as of January 1, 2021
19
shall also provide a streamlined and transparent bill
20
crediting system for net metering to be managed by the
21
electric utilities. The terms and conditions shall include,
22
but are not limited to, that an electric utility shall manage
23
and maintain billing of net metering credits and charges
24
regardless of if the eligible customer takes net metering
25
under an electric utility or alternative retail electric
26
supplier. The electric utility serving more than 200,000

SB3273 Enrolled
- 63 -
LRB104 18411 AAS 31853 b
1
customers as of January 1, 2021 shall process and approve all
2
net metering applications, even if an eligible customer is
3
served by an alternative retail electric supplier; and the
4
utility shall forward application approval to the appropriate
5
alternative retail electric supplier. Eligibility for net
6
metering shall remain with the owner of the utility billing
7
address such that, if an eligible renewable electrical
8
generating facility changes ownership, the net metering
9
eligibility transfers to the new owner. The electric utility
10
serving more than 200,000 customers as of January 1, 2021
11
shall manage net metering billing for eligible customers to
12
ensure full crediting occurs on electricity bills, including,
13
but not limited to, ensuring net metering crediting begins
14
upon commercial operation date, net metering billing transfers
15
immediately if an eligible customer switches from an electric
16
utility to alternative retail electric supplier or vice versa,
17
and net metering billing transfers between ownership of a
18
valid billing address. All transfers referenced in the
19
preceding sentence shall include transfer of all banked
20
credits. All electric utilities serving 200,000 or fewer
21
customers as of January 1, 2021 shall manage net metering
22
billing for eligible customers receiving power and energy
23
service from the electric utility to ensure full crediting
24
occurs on electricity bills, ensuring net metering crediting
25
begins upon commercial operation date, net metering billing
26
transfers immediately if an eligible customer switches from an

SB3273 Enrolled
- 64 -
LRB104 18411 AAS 31853 b
1
electric utility to alternative retail electric supplier or
2
vice versa, and net metering billing transfers between
3
ownership of a valid billing address. Alternative retail
4
electric suppliers providing power and energy service to
5
eligible customers located within the service territory of an
6
electric utility serving 200,000 or fewer customers as of
7
January 1, 2021 shall manage net metering billing for eligible
8
customers to ensure full crediting occurs on electricity
9
bills, including, but not limited to, ensuring net metering
10
crediting begins upon commercial operation date, net metering
11
billing transfers immediately if an eligible customer switches
12
from an electric utility to alternative retail electric
13
supplier or vice versa, and net metering billing transfers
14
between ownership of a valid billing address.
15
(Source: P.A. 104-458, eff. 6-1-26.)

16

(220 ILCS 5/17-1000 new)
17

Sec. 17-1000.
Interconnection application fees for public
18
schools.
A municipal system or electric cooperative shall not
19
charge an application fee to a public school for the
20
interconnection of renewable generating facilities located on
21
the public school's land to the local distribution system that
22
exceeds more than 150% of the cost authorized by law or by rule
23
to be recovered from customers by public utilities for the
24
same or similarly sized facilities with the same or similar
25
electric configurations to the local distribution system. An

SB3273 Enrolled
- 65 -
LRB104 18411 AAS 31853 b
1
interconnection application fee shall be in addition to
2
inspection fees or costs, municipal building permit fees, and
3
other normal fees charged by municipalities for governmental
4
considerations related to non-electric utilities. The limit on
5
an interconnection application fee under this Section does not
6
apply to any required reimbursement by a public school of the
7
cost of any reasonably required metering equipment, system
8
impact studies, or system upgrades, which shall be limited to
9
actual costs reasonably incurred.

10

Section 95.
No acceleration or delay.
Where this Act makes
11
changes in a statute that is represented in this Act by text
12
that is not yet or no longer in effect (for example, a Section
13
represented by multiple versions), the use of that text does
14
not accelerate or delay the taking effect of (i) the changes
15
made by this Act or (ii) provisions derived from any other
16
Public Act.

17

Section 99.
Effective date.
This Act takes effect upon
18
becoming law.

Footer

Disclaimer

This site is maintained for the Illinois General Assembly by the
Legislative Information System, 705 Stratton Building, Springfield, Illinois 62706.

Contact ILGA Webmaster

ILGA.gov uses cookies to ensure you get the best experience on our website. By continuing to browse ILGA.gov you consent to our use of cookies.
Read About Cookies

ILGA.GOV

2026 ILGA.gov | All Rights Reserved |
ADA

|
Disclaimers
|
Learn

This site is maintained for the Illinois General Assembly by the
Legislative Information System, 705 Stratton Building, Springfield, Illinois 62706.
Contact ILGA Webmaster

ILGA.gov uses cookies to ensure you get the best experience on our website. By continuing to browse ILGA.gov you consent to our use of cookies.
Read About Cookies

ILGA.GOV

2026 ILGA.gov | All Rights Reserved |
ADA

|
Disclaimers
|
Learn