101ST GENERAL ASSEMBLY
State of Illinois
2019 and 2020
HB2956

 

Introduced , by Rep. William Davis

 

SYNOPSIS AS INTRODUCED:
 
220 ILCS 5/8-103B

    Amends the Public Utilities Act. Removes language exempting retail customers of an electric utility that serves more than 3,000,000 retail customers in the State and whose total highest 30-minute demand was more than 10,000 kilowatts and retail customers of an electric utility that serves less than 3,000,000 retail customers but more than 500,000 retail customers in the State and whose total highest 15-minute demand was more than 10,000 kilowatts from certain provisions concerning energy efficiency and demand-response measures. Makes other changes. Effective immediately.


LRB101 09743 JRG 54844 b

 

 

A BILL FOR

 

HB2956LRB101 09743 JRG 54844 b

1    AN ACT concerning regulation.
 
2    Be it enacted by the People of the State of Illinois,
3represented in the General Assembly:
 
4    Section 5. The Public Utilities Act is amended by changing
5Section 8-103B as follows:
 
6    (220 ILCS 5/8-103B)
7    Sec. 8-103B. Energy efficiency and demand-response
8measures.
9    (a) It is the policy of the State that electric utilities
10are required to use cost-effective energy efficiency and
11demand-response measures to reduce delivery load. Requiring
12investment in cost-effective energy efficiency and
13demand-response measures will reduce direct and indirect costs
14to consumers by decreasing environmental impacts and by
15avoiding or delaying the need for new generation, transmission,
16and distribution infrastructure. It serves the public interest
17to allow electric utilities to recover costs for reasonably and
18prudently incurred expenditures for energy efficiency and
19demand-response measures. As used in this Section,
20"cost-effective" means that the measures satisfy the total
21resource cost test. The low-income measures described in
22subsection (c) of this Section shall not be required to meet
23the total resource cost test. For purposes of this Section, the

 

 

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1terms "energy-efficiency", "demand-response", "electric
2utility", and "total resource cost test" have the meanings set
3forth in the Illinois Power Agency Act.
4    (a-5) This Section applies to electric utilities serving
5more than 500,000 retail customers in the State for those
6multi-year plans commencing after December 31, 2017.
7    (b) For purposes of this Section, electric utilities
8subject to this Section that serve more than 3,000,000 retail
9customers in the State shall be deemed to have achieved a
10cumulative persisting annual savings of 6.6% from energy
11efficiency measures and programs implemented during the period
12beginning January 1, 2012 and ending December 31, 2017, which
13percent is based on the deemed average weather normalized sales
14of electric power and energy during calendar years 2014, 2015,
15and 2016 of 88,000,000 MWhs. For the purposes of this
16subsection (b) and subsection (b-5), the 88,000,000 MWhs of
17deemed electric power and energy sales shall be reduced by the
18number of MWhs equal to the sum of the annual consumption of
19customers that are exempt from subsections (a) through (j) of
20this Section under subsection (l) of this Section, as averaged
21across the calendar years 2014, 2015, and 2016. After 2017, the
22deemed value of cumulative persisting annual savings from
23energy efficiency measures and programs implemented during the
24period beginning January 1, 2012 and ending December 31, 2017,
25shall be reduced each year, as follows, and the applicable
26value shall be applied to and count toward the utility's

 

 

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1achievement of the cumulative persisting annual savings goals
2set forth in subsection (b-5):
3        (1) 5.8% deemed cumulative persisting annual savings
4    for the year ending December 31, 2018;
5        (2) 5.2% deemed cumulative persisting annual savings
6    for the year ending December 31, 2019;
7        (3) 4.5% deemed cumulative persisting annual savings
8    for the year ending December 31, 2020;
9        (4) 4.0% deemed cumulative persisting annual savings
10    for the year ending December 31, 2021;
11        (5) 3.5% deemed cumulative persisting annual savings
12    for the year ending December 31, 2022;
13        (6) 3.1% deemed cumulative persisting annual savings
14    for the year ending December 31, 2023;
15        (7) 2.8% deemed cumulative persisting annual savings
16    for the year ending December 31, 2024;
17        (8) 2.5% deemed cumulative persisting annual savings
18    for the year ending December 31, 2025;
19        (9) 2.3% deemed cumulative persisting annual savings
20    for the year ending December 31, 2026;
21        (10) 2.1% deemed cumulative persisting annual savings
22    for the year ending December 31, 2027;
23        (11) 1.8% deemed cumulative persisting annual savings
24    for the year ending December 31, 2028;
25        (12) 1.7% deemed cumulative persisting annual savings
26    for the year ending December 31, 2029; and

 

 

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1        (13) 1.5% deemed cumulative persisting annual savings
2    for the year ending December 31, 2030.
3    For purposes of this Section, "cumulative persisting
4annual savings" means the total electric energy savings in a
5given year from measures installed in that year or in previous
6years, but no earlier than January 1, 2012, that are still
7operational and providing savings in that year because the
8measures have not yet reached the end of their useful lives.
9    (b-5) Beginning in 2018, electric utilities subject to this
10Section that serve more than 3,000,000 retail customers in the
11State shall achieve the following cumulative persisting annual
12savings goals, as modified by subsection (f) of this Section
13and as compared to the deemed baseline of 88,000,000 MWhs of
14electric power and energy sales set forth in subsection (b), as
15reduced by the number of MWhs equal to the sum of the annual
16consumption of customers that are exempt from subsections (a)
17through (j) of this Section under subsection (l) of this
18Section as averaged across the calendar years 2014, 2015, and
192016, through the implementation of energy efficiency measures
20during the applicable year and in prior years, but no earlier
21than January 1, 2012:
22        (1) 7.8% cumulative persisting annual savings for the
23    year ending December 31, 2018;
24        (2) 9.1% cumulative persisting annual savings for the
25    year ending December 31, 2019;
26        (3) 10.4% cumulative persisting annual savings for the

 

 

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1    year ending December 31, 2020;
2        (4) 11.8% cumulative persisting annual savings for the
3    year ending December 31, 2021;
4        (5) 13.1% cumulative persisting annual savings for the
5    year ending December 31, 2022;
6        (6) 14.4% cumulative persisting annual savings for the
7    year ending December 31, 2023;
8        (7) 15.7% cumulative persisting annual savings for the
9    year ending December 31, 2024;
10        (8) 17% cumulative persisting annual savings for the
11    year ending December 31, 2025;
12        (9) 17.9% cumulative persisting annual savings for the
13    year ending December 31, 2026;
14        (10) 18.8% cumulative persisting annual savings for
15    the year ending December 31, 2027;
16        (11) 19.7% cumulative persisting annual savings for
17    the year ending December 31, 2028;
18        (12) 20.6% cumulative persisting annual savings for
19    the year ending December 31, 2029; and
20        (13) 21.5% cumulative persisting annual savings for
21    the year ending December 31, 2030.
22    (b-10) For purposes of this Section, electric utilities
23subject to this Section that serve less than 3,000,000 retail
24customers but more than 500,000 retail customers in the State
25shall be deemed to have achieved a cumulative persisting annual
26savings of 6.6% from energy efficiency measures and programs

 

 

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1implemented during the period beginning January 1, 2012 and
2ending December 31, 2017, which is based on the deemed average
3weather normalized sales of electric power and energy during
4calendar years 2014, 2015, and 2016 of 36,900,000 MWhs. For the
5purposes of this subsection (b-10) and subsection (b-15), the
636,900,000 MWhs of deemed electric power and energy sales shall
7be reduced by the number of MWhs equal to the sum of the annual
8consumption of customers that are exempt from subsections (a)
9through (j) of this Section under subsection (l) of this
10Section, as averaged across the calendar years 2014, 2015, and
112016. After 2017, the deemed value of cumulative persisting
12annual savings from energy efficiency measures and programs
13implemented during the period beginning January 1, 2012 and
14ending December 31, 2017, shall be reduced each year, as
15follows, and the applicable value shall be applied to and count
16toward the utility's achievement of the cumulative persisting
17annual savings goals set forth in subsection (b-15):
18        (1) 5.8% deemed cumulative persisting annual savings
19    for the year ending December 31, 2018;
20        (2) 5.2% deemed cumulative persisting annual savings
21    for the year ending December 31, 2019;
22        (3) 4.5% deemed cumulative persisting annual savings
23    for the year ending December 31, 2020;
24        (4) 4.0% deemed cumulative persisting annual savings
25    for the year ending December 31, 2021;
26        (5) 3.5% deemed cumulative persisting annual savings

 

 

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1    for the year ending December 31, 2022;
2        (6) 3.1% deemed cumulative persisting annual savings
3    for the year ending December 31, 2023;
4        (7) 2.8% deemed cumulative persisting annual savings
5    for the year ending December 31, 2024;
6        (8) 2.5% deemed cumulative persisting annual savings
7    for the year ending December 31, 2025;
8        (9) 2.3% deemed cumulative persisting annual savings
9    for the year ending December 31, 2026;
10        (10) 2.1% deemed cumulative persisting annual savings
11    for the year ending December 31, 2027;
12        (11) 1.8% deemed cumulative persisting annual savings
13    for the year ending December 31, 2028;
14        (12) 1.7% deemed cumulative persisting annual savings
15    for the year ending December 31, 2029; and
16        (13) 1.5% deemed cumulative persisting annual savings
17    for the year ending December 31, 2030.
18    (b-15) Beginning in 2018, electric utilities subject to
19this Section that serve less than 3,000,000 retail customers
20but more than 500,000 retail customers in the State shall
21achieve the following cumulative persisting annual savings
22goals, as modified by subsection (b-20) and subsection (f) of
23this Section and as compared to the deemed baseline as reduced
24by the number of MWhs equal to the sum of the annual
25consumption of customers that are exempt from subsections (a)
26through (j) of this Section under subsection (l) of this

 

 

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1Section as averaged across the calendar years 2014, 2015, and
22016, through the implementation of energy efficiency measures
3during the applicable year and in prior years, but no earlier
4than January 1, 2012:
5        (1) 7.4% cumulative persisting annual savings for the
6    year ending December 31, 2018;
7        (2) 8.2% cumulative persisting annual savings for the
8    year ending December 31, 2019;
9        (3) 9.0% cumulative persisting annual savings for the
10    year ending December 31, 2020;
11        (4) 9.8% cumulative persisting annual savings for the
12    year ending December 31, 2021;
13        (5) 10.6% cumulative persisting annual savings for the
14    year ending December 31, 2022;
15        (6) 11.4% cumulative persisting annual savings for the
16    year ending December 31, 2023;
17        (7) 12.2% cumulative persisting annual savings for the
18    year ending December 31, 2024;
19        (8) 13% cumulative persisting annual savings for the
20    year ending December 31, 2025;
21        (9) 13.6% cumulative persisting annual savings for the
22    year ending December 31, 2026;
23        (10) 14.2% cumulative persisting annual savings for
24    the year ending December 31, 2027;
25        (11) 14.8% cumulative persisting annual savings for
26    the year ending December 31, 2028;

 

 

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1        (12) 15.4% cumulative persisting annual savings for
2    the year ending December 31, 2029; and
3        (13) 16% cumulative persisting annual savings for the
4    year ending December 31, 2030.
5    The difference between the cumulative persisting annual
6savings goal for the applicable calendar year and the
7cumulative persisting annual savings goal for the immediately
8preceding calendar year is 0.8% for the period of January 1,
92018 through December 31, 2025 and 0.6% for the period of
10January 1, 2026 through December 31, 2030.
11    (b-20) Each electric utility subject to this Section may
12include cost-effective voltage optimization measures in its
13plans submitted under subsections (f) and (g) of this Section,
14and the costs incurred by a utility to implement the measures
15under a Commission-approved plan shall be recovered under the
16provisions of Article IX or Section 16-108.5 of this Act. For
17purposes of this Section, the measure life of voltage
18optimization measures shall be 15 years. The measure life
19period is independent of the depreciation rate of the voltage
20optimization assets deployed.
21    Within 270 days after June 1, 2017 (the effective date of
22Public Act 99-906) this amendatory Act of the 99th General
23Assembly, an electric utility that serves less than 3,000,000
24retail customers but more than 500,000 retail customers in the
25State shall file a plan with the Commission that identifies the
26cost-effective voltage optimization investment the electric

 

 

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1utility plans to undertake through December 31, 2024. The
2Commission, after notice and hearing, shall approve or approve
3with modification the plan within 120 days after the plan's
4filing and, in the order approving or approving with
5modification the plan, the Commission shall adjust the
6applicable cumulative persisting annual savings goals set
7forth in subsection (b-15) to reflect any amount of
8cost-effective energy savings approved by the Commission that
9is greater than or less than the following cumulative
10persisting annual savings values attributable to voltage
11optimization for the applicable year:
12        (1) 0.0% of cumulative persisting annual savings for
13    the year ending December 31, 2018;
14        (2) 0.17% of cumulative persisting annual savings for
15    the year ending December 31, 2019;
16        (3) 0.17% of cumulative persisting annual savings for
17    the year ending December 31, 2020;
18        (4) 0.33% of cumulative persisting annual savings for
19    the year ending December 31, 2021;
20        (5) 0.5% of cumulative persisting annual savings for
21    the year ending December 31, 2022;
22        (6) 0.67% of cumulative persisting annual savings for
23    the year ending December 31, 2023;
24        (7) 0.83% of cumulative persisting annual savings for
25    the year ending December 31, 2024; and
26        (8) 1.0% of cumulative persisting annual savings for

 

 

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1    the year ending December 31, 2025.
2    (b-25) In the event an electric utility jointly offers an
3energy efficiency measure or program with a gas utility under
4plans approved under this Section and Section 8-104 of this
5Act, the electric utility may continue offering the program,
6including the gas energy efficiency measures, in the event the
7gas utility discontinues funding the program. In that event,
8the energy savings value associated with such other fuels shall
9be converted to electric energy savings on an equivalent Btu
10basis for the premises. However, the electric utility shall
11prioritize programs for low-income residential customers to
12the extent practicable. An electric utility may recover the
13costs of offering the gas energy efficiency measures under this
14subsection (b-25).
15    For those energy efficiency measures or programs that save
16both electricity and other fuels but are not jointly offered
17with a gas utility under plans approved under this Section and
18Section 8-104 or not offered with an affiliated gas utility
19under paragraph (6) of subsection (f) of Section 8-104 of this
20Act, the electric utility may count savings of fuels other than
21electricity toward the achievement of its annual savings goal,
22and the energy savings value associated with such other fuels
23shall be converted to electric energy savings on an equivalent
24Btu basis at the premises.
25    In no event shall more than 10% of each year's applicable
26annual incremental goal as defined in paragraph (7) of

 

 

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1subsection (g) of this Section be met through savings of fuels
2other than electricity.
3    (c) Electric utilities shall be responsible for overseeing
4the design, development, and filing of energy efficiency plans
5with the Commission and may, as part of that implementation,
6outsource various aspects of program development and
7implementation. A minimum of 10%, for electric utilities that
8serve more than 3,000,000 retail customers in the State, and a
9minimum of 7%, for electric utilities that serve less than
103,000,000 retail customers but more than 500,000 retail
11customers in the State, of the utility's entire portfolio
12funding level for a given year shall be used to procure
13cost-effective energy efficiency measures from units of local
14government, municipal corporations, school districts, public
15housing, and community college districts, provided that a
16minimum percentage of available funds shall be used to procure
17energy efficiency from public housing, which percentage shall
18be equal to public housing's share of public building energy
19consumption.
20    The utilities shall also implement energy efficiency
21measures targeted at low-income households, which, for
22purposes of this Section, shall be defined as households at or
23below 80% of area median income, and expenditures to implement
24the measures shall be no less than $25,000,000 per year for
25electric utilities that serve more than 3,000,000 retail
26customers in the State and no less than $8,350,000 per year for

 

 

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1electric utilities that serve less than 3,000,000 retail
2customers but more than 500,000 retail customers in the State.
3    Each electric utility shall assess opportunities to
4implement cost-effective energy efficiency measures and
5programs through a public housing authority or authorities
6located in its service territory. If such opportunities are
7identified, the utility shall propose such measures and
8programs to address the opportunities. Expenditures to address
9such opportunities shall be credited toward the minimum
10procurement and expenditure requirements set forth in this
11subsection (c).
12    Implementation of energy efficiency measures and programs
13targeted at low-income households should be contracted, when it
14is practicable, to independent third parties that have
15demonstrated capabilities to serve such households, with a
16preference for not-for-profit entities and government agencies
17that have existing relationships with or experience serving
18low-income communities in the State.
19    Each electric utility shall develop and implement
20reporting procedures that address and assist in determining the
21amount of energy savings that can be applied to the low-income
22procurement and expenditure requirements set forth in this
23subsection (c).
24    The electric utilities shall also convene a low-income
25energy efficiency advisory committee to assist in the design
26and evaluation of the low-income energy efficiency programs.

 

 

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1The committee shall be comprised of the electric utilities
2subject to the requirements of this Section, the gas utilities
3subject to the requirements of Section 8-104 of this Act, the
4utilities' low-income energy efficiency implementation
5contractors, and representatives of community-based
6organizations.
7    (d) Notwithstanding any other provision of law to the
8contrary, a utility providing approved energy efficiency
9measures and, if applicable, demand-response measures in the
10State shall be permitted to recover all reasonable and
11prudently incurred costs of those measures from all retail
12customers, except as provided in subsection (l) of this
13Section, as follows, provided that nothing in this subsection
14(d) permits the double recovery of such costs from customers:
15        (1) The utility may recover its costs through an
16    automatic adjustment clause tariff filed with and approved
17    by the Commission. The tariff shall be established outside
18    the context of a general rate case. Each year the
19    Commission shall initiate a review to reconcile any amounts
20    collected with the actual costs and to determine the
21    required adjustment to the annual tariff factor to match
22    annual expenditures. To enable the financing of the
23    incremental capital expenditures, including regulatory
24    assets, for electric utilities that serve less than
25    3,000,000 retail customers but more than 500,000 retail
26    customers in the State, the utility's actual year-end

 

 

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1    capital structure that includes a common equity ratio,
2    excluding goodwill, of up to and including 50% of the total
3    capital structure shall be deemed reasonable and used to
4    set rates.
5        (2) A utility may recover its costs through an energy
6    efficiency formula rate approved by the Commission under a
7    filing under subsections (f) and (g) of this Section, which
8    shall specify the cost components that form the basis of
9    the rate charged to customers with sufficient specificity
10    to operate in a standardized manner and be updated annually
11    with transparent information that reflects the utility's
12    actual costs to be recovered during the applicable rate
13    year, which is the period beginning with the first billing
14    day of January and extending through the last billing day
15    of the following December. The energy efficiency formula
16    rate shall be implemented through a tariff filed with the
17    Commission under subsections (f) and (g) of this Section
18    that is consistent with the provisions of this paragraph
19    (2) and that shall be applicable to all delivery services
20    customers. The Commission shall conduct an investigation
21    of the tariff in a manner consistent with the provisions of
22    this paragraph (2), subsections (f) and (g) of this
23    Section, and the provisions of Article IX of this Act to
24    the extent they do not conflict with this paragraph (2).
25    The energy efficiency formula rate approved by the
26    Commission shall remain in effect at the discretion of the

 

 

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1    utility and shall do the following:
2            (A) Provide for the recovery of the utility's
3        actual costs incurred under this Section that are
4        prudently incurred and reasonable in amount consistent
5        with Commission practice and law. The sole fact that a
6        cost differs from that incurred in a prior calendar
7        year or that an investment is different from that made
8        in a prior calendar year shall not imply the imprudence
9        or unreasonableness of that cost or investment.
10            (B) Reflect the utility's actual year-end capital
11        structure for the applicable calendar year, excluding
12        goodwill, subject to a determination of prudence and
13        reasonableness consistent with Commission practice and
14        law. To enable the financing of the incremental capital
15        expenditures, including regulatory assets, for
16        electric utilities that serve less than 3,000,000
17        retail customers but more than 500,000 retail
18        customers in the State, a participating electric
19        utility's actual year-end capital structure that
20        includes a common equity ratio, excluding goodwill, of
21        up to and including 50% of the total capital structure
22        shall be deemed reasonable and used to set rates.
23            (C) Include a cost of equity, which shall be
24        calculated as the sum of the following:
25                (i) the average for the applicable calendar
26            year of the monthly average yields of 30-year U.S.

 

 

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1            Treasury bonds published by the Board of Governors
2            of the Federal Reserve System in its weekly H.15
3            Statistical Release or successor publication; and
4                (ii) 580 basis points.
5            At such time as the Board of Governors of the
6        Federal Reserve System ceases to include the monthly
7        average yields of 30-year U.S. Treasury bonds in its
8        weekly H.15 Statistical Release or successor
9        publication, the monthly average yields of the U.S.
10        Treasury bonds then having the longest duration
11        published by the Board of Governors in its weekly H.15
12        Statistical Release or successor publication shall
13        instead be used for purposes of this paragraph (2).
14            (D) Permit and set forth protocols, subject to a
15        determination of prudence and reasonableness
16        consistent with Commission practice and law, for the
17        following:
18                (i) recovery of incentive compensation expense
19            that is based on the achievement of operational
20            metrics, including metrics related to budget
21            controls, outage duration and frequency, safety,
22            customer service, efficiency and productivity, and
23            environmental compliance; however, this protocol
24            shall not apply if such expense related to costs
25            incurred under this Section is recovered under
26            Article IX or Section 16-108.5 of this Act;

 

 

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1            incentive compensation expense that is based on
2            net income or an affiliate's earnings per share
3            shall not be recoverable under the energy
4            efficiency formula rate;
5                (ii) recovery of pension and other
6            post-employment benefits expense, provided that
7            such costs are supported by an actuarial study;
8            however, this protocol shall not apply if such
9            expense related to costs incurred under this
10            Section is recovered under Article IX or Section
11            16-108.5 of this Act;
12                (iii) recovery of existing regulatory assets
13            over the periods previously authorized by the
14            Commission;
15                (iv) as described in subsection (e),
16            amortization of costs incurred under this Section;
17            and
18                (v) projected, weather normalized billing
19            determinants for the applicable rate year.
20            (E) Provide for an annual reconciliation, as
21        described in paragraph (3) of this subsection (d), less
22        any deferred taxes related to the reconciliation, with
23        interest at an annual rate of return equal to the
24        utility's weighted average cost of capital, including
25        a revenue conversion factor calculated to recover or
26        refund all additional income taxes that may be payable

 

 

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1        or receivable as a result of that return, of the energy
2        efficiency revenue requirement reflected in rates for
3        each calendar year, beginning with the calendar year in
4        which the utility files its energy efficiency formula
5        rate tariff under this paragraph (2), with what the
6        revenue requirement would have been had the actual cost
7        information for the applicable calendar year been
8        available at the filing date.
9        The utility shall file, together with its tariff, the
10    projected costs to be incurred by the utility during the
11    rate year under the utility's multi-year plan approved
12    under subsections (f) and (g) of this Section, including,
13    but not limited to, the projected capital investment costs
14    and projected regulatory asset balances with
15    correspondingly updated depreciation and amortization
16    reserves and expense, that shall populate the energy
17    efficiency formula rate and set the initial rates under the
18    formula.
19        The Commission shall review the proposed tariff in
20    conjunction with its review of a proposed multi-year plan,
21    as specified in paragraph (5) of subsection (g) of this
22    Section. The review shall be based on the same evidentiary
23    standards, including, but not limited to, those concerning
24    the prudence and reasonableness of the costs incurred by
25    the utility, the Commission applies in a hearing to review
26    a filing for a general increase in rates under Article IX

 

 

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1    of this Act. The initial rates shall take effect beginning
2    with the January monthly billing period following the
3    Commission's approval.
4        The tariff's rate design and cost allocation across
5    customer classes shall be consistent with the utility's
6    automatic adjustment clause tariff in effect on June 1,
7    2017 (the effective date of Public Act 99-906) this
8    amendatory Act of the 99th General Assembly; however, the
9    Commission may revise the tariff's rate design and cost
10    allocation in subsequent proceedings under paragraph (3)
11    of this subsection (d).
12        If the energy efficiency formula rate is terminated,
13    the then current rates shall remain in effect until such
14    time as the energy efficiency costs are incorporated into
15    new rates that are set under this subsection (d) or Article
16    IX of this Act, subject to retroactive rate adjustment,
17    with interest, to reconcile rates charged with actual
18    costs.
19        (3) The provisions of this paragraph (3) shall only
20    apply to an electric utility that has elected to file an
21    energy efficiency formula rate under paragraph (2) of this
22    subsection (d). Subsequent to the Commission's issuance of
23    an order approving the utility's energy efficiency formula
24    rate structure and protocols, and initial rates under
25    paragraph (2) of this subsection (d), the utility shall
26    file, on or before June 1 of each year, with the Chief

 

 

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1    Clerk of the Commission its updated cost inputs to the
2    energy efficiency formula rate for the applicable rate year
3    and the corresponding new charges, as well as the
4    information described in paragraph (9) of subsection (g) of
5    this Section. Each such filing shall conform to the
6    following requirements and include the following
7    information:
8            (A) The inputs to the energy efficiency formula
9        rate for the applicable rate year shall be based on the
10        projected costs to be incurred by the utility during
11        the rate year under the utility's multi-year plan
12        approved under subsections (f) and (g) of this Section,
13        including, but not limited to, projected capital
14        investment costs and projected regulatory asset
15        balances with correspondingly updated depreciation and
16        amortization reserves and expense. The filing shall
17        also include a reconciliation of the energy efficiency
18        revenue requirement that was in effect for the prior
19        rate year (as set by the cost inputs for the prior rate
20        year) with the actual revenue requirement for the prior
21        rate year (determined using a year-end rate base) that
22        uses amounts reflected in the applicable FERC Form 1
23        that reports the actual costs for the prior rate year.
24        Any over-collection or under-collection indicated by
25        such reconciliation shall be reflected as a credit
26        against, or recovered as an additional charge to,

 

 

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1        respectively, with interest calculated at a rate equal
2        to the utility's weighted average cost of capital
3        approved by the Commission for the prior rate year, the
4        charges for the applicable rate year. Such
5        over-collection or under-collection shall be adjusted
6        to remove any deferred taxes related to the
7        reconciliation, for purposes of calculating interest
8        at an annual rate of return equal to the utility's
9        weighted average cost of capital approved by the
10        Commission for the prior rate year, including a revenue
11        conversion factor calculated to recover or refund all
12        additional income taxes that may be payable or
13        receivable as a result of that return. Each
14        reconciliation shall be certified by the participating
15        utility in the same manner that FERC Form 1 is
16        certified. The filing shall also include the charge or
17        credit, if any, resulting from the calculation
18        required by subparagraph (E) of paragraph (2) of this
19        subsection (d).
20            Notwithstanding any other provision of law to the
21        contrary, the intent of the reconciliation is to
22        ultimately reconcile both the revenue requirement
23        reflected in rates for each calendar year, beginning
24        with the calendar year in which the utility files its
25        energy efficiency formula rate tariff under paragraph
26        (2) of this subsection (d), with what the revenue

 

 

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1        requirement determined using a year-end rate base for
2        the applicable calendar year would have been had the
3        actual cost information for the applicable calendar
4        year been available at the filing date.
5            For purposes of this Section, "FERC Form 1" means
6        the Annual Report of Major Electric Utilities,
7        Licensees and Others that electric utilities are
8        required to file with the Federal Energy Regulatory
9        Commission under the Federal Power Act, Sections 3,
10        4(a), 304 and 209, modified as necessary to be
11        consistent with 83 Ill. Admin. Code Part 415 as of May
12        1, 2011. Nothing in this Section is intended to allow
13        costs that are not otherwise recoverable to be
14        recoverable by virtue of inclusion in FERC Form 1.
15            (B) The new charges shall take effect beginning on
16        the first billing day of the following January billing
17        period and remain in effect through the last billing
18        day of the next December billing period regardless of
19        whether the Commission enters upon a hearing under this
20        paragraph (3).
21            (C) The filing shall include relevant and
22        necessary data and documentation for the applicable
23        rate year. Normalization adjustments shall not be
24        required.
25        Within 45 days after the utility files its annual
26    update of cost inputs to the energy efficiency formula

 

 

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1    rate, the Commission shall with reasonable notice,
2    initiate a proceeding concerning whether the projected
3    costs to be incurred by the utility and recovered during
4    the applicable rate year, and that are reflected in the
5    inputs to the energy efficiency formula rate, are
6    consistent with the utility's approved multi-year plan
7    under subsections (f) and (g) of this Section and whether
8    the costs incurred by the utility during the prior rate
9    year were prudent and reasonable. The Commission shall also
10    have the authority to investigate the information and data
11    described in paragraph (9) of subsection (g) of this
12    Section, including the proposed adjustment to the
13    utility's return on equity component of its weighted
14    average cost of capital. During the course of the
15    proceeding, each objection shall be stated with
16    particularity and evidence provided in support thereof,
17    after which the utility shall have the opportunity to rebut
18    the evidence. Discovery shall be allowed consistent with
19    the Commission's Rules of Practice, which Rules of Practice
20    shall be enforced by the Commission or the assigned
21    administrative law judge. The Commission shall apply the
22    same evidentiary standards, including, but not limited to,
23    those concerning the prudence and reasonableness of the
24    costs incurred by the utility, during the proceeding as it
25    would apply in a proceeding to review a filing for a
26    general increase in rates under Article IX of this Act. The

 

 

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1    Commission shall not, however, have the authority in a
2    proceeding under this paragraph (3) to consider or order
3    any changes to the structure or protocols of the energy
4    efficiency formula rate approved under paragraph (2) of
5    this subsection (d). In a proceeding under this paragraph
6    (3), the Commission shall enter its order no later than the
7    earlier of 195 days after the utility's filing of its
8    annual update of cost inputs to the energy efficiency
9    formula rate or December 15. The utility's proposed return
10    on equity calculation, as described in paragraphs (7)
11    through (9) of subsection (g) of this Section, shall be
12    deemed the final, approved calculation on December 15 of
13    the year in which it is filed unless the Commission enters
14    an order on or before December 15, after notice and
15    hearing, that modifies such calculation consistent with
16    this Section. The Commission's determinations of the
17    prudence and reasonableness of the costs incurred, and
18    determination of such return on equity calculation, for the
19    applicable calendar year shall be final upon entry of the
20    Commission's order and shall not be subject to reopening,
21    reexamination, or collateral attack in any other
22    Commission proceeding, case, docket, order, rule, or
23    regulation; however, nothing in this paragraph (3) shall
24    prohibit a party from petitioning the Commission to rehear
25    or appeal to the courts the order under the provisions of
26    this Act.

 

 

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1    (e) Beginning on June 1, 2017 (the effective date of Public
2Act 99-906) this amendatory Act of the 99th General Assembly, a
3utility subject to the requirements of this Section may elect
4to defer, as a regulatory asset, up to the full amount of its
5expenditures incurred under this Section for each annual
6period, including, but not limited to, any expenditures
7incurred above the funding level set by subsection (f) of this
8Section for a given year. The total expenditures deferred as a
9regulatory asset in a given year shall be amortized and
10recovered over a period that is equal to the weighted average
11of the energy efficiency measure lives implemented for that
12year that are reflected in the regulatory asset. The
13unamortized balance shall be recognized as of December 31 for a
14given year. The utility shall also earn a return on the total
15of the unamortized balances of all of the energy efficiency
16regulatory assets, less any deferred taxes related to those
17unamortized balances, at an annual rate equal to the utility's
18weighted average cost of capital that includes, based on a
19year-end capital structure, the utility's actual cost of debt
20for the applicable calendar year and a cost of equity, which
21shall be calculated as the sum of the (i) the average for the
22applicable calendar year of the monthly average yields of
2330-year U.S. Treasury bonds published by the Board of Governors
24of the Federal Reserve System in its weekly H.15 Statistical
25Release or successor publication; and (ii) 580 basis points,
26including a revenue conversion factor calculated to recover or

 

 

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1refund all additional income taxes that may be payable or
2receivable as a result of that return. Capital investment costs
3shall be depreciated and recovered over their useful lives
4consistent with generally accepted accounting principles. The
5weighted average cost of capital shall be applied to the
6capital investment cost balance, less any accumulated
7depreciation and accumulated deferred income taxes, as of
8December 31 for a given year.
9    When an electric utility creates a regulatory asset under
10the provisions of this Section, the costs are recovered over a
11period during which customers also receive a benefit which is
12in the public interest. Accordingly, it is the intent of the
13General Assembly that an electric utility that elects to create
14a regulatory asset under the provisions of this Section shall
15recover all of the associated costs as set forth in this
16Section. After the Commission has approved the prudence and
17reasonableness of the costs that comprise the regulatory asset,
18the electric utility shall be permitted to recover all such
19costs, and the value and recoverability through rates of the
20associated regulatory asset shall not be limited, altered,
21impaired, or reduced.
22    (f) Beginning in 2017, each electric utility shall file an
23energy efficiency plan with the Commission to meet the energy
24efficiency standards for the next applicable multi-year period
25beginning January 1 of the year following the filing, according
26to the schedule set forth in paragraphs (1) through (3) of this

 

 

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1subsection (f). If a utility does not file such a plan on or
2before the applicable filing deadline for the plan, it shall
3face a penalty of $100,000 per day until the plan is filed.
4        (1) No later than 30 days after June 1, 2017 (the
5    effective date of Public Act 99-906) this amendatory Act of
6    the 99th General Assembly or May 1, 2017, whichever is
7    later, each electric utility shall file a 4-year energy
8    efficiency plan commencing on January 1, 2018 that is
9    designed to achieve the cumulative persisting annual
10    savings goals specified in paragraphs (1) through (4) of
11    subsection (b-5) of this Section or in paragraphs (1)
12    through (4) of subsection (b-15) of this Section, as
13    applicable, through implementation of energy efficiency
14    measures; however, the goals may be reduced if the
15    utility's expenditures are limited pursuant to subsection
16    (m) of this Section or, for a utility that serves less than
17    3,000,000 retail customers, if each of the following
18    conditions are met: (A) the plan's analysis and forecasts
19    of the utility's ability to acquire energy savings
20    demonstrate that achievement of such goals is not cost
21    effective; and (B) the amount of energy savings achieved by
22    the utility as determined by the independent evaluator for
23    the most recent year for which savings have been evaluated
24    preceding the plan filing was less than the average annual
25    amount of savings required to achieve the goals for the
26    applicable 4-year plan period. Except as provided in

 

 

HB2956- 29 -LRB101 09743 JRG 54844 b

1    subsection (m) of this Section, annual increases in
2    cumulative persisting annual savings goals during the
3    applicable 4-year plan period shall not be reduced to
4    amounts that are less than the maximum amount of cumulative
5    persisting annual savings that is forecast to be
6    cost-effectively achievable during the 4-year plan period.
7    The Commission shall review any proposed goal reduction as
8    part of its review and approval of the utility's proposed
9    plan.
10        (2) No later than March 1, 2021, each electric utility
11    shall file a 4-year energy efficiency plan commencing on
12    January 1, 2022 that is designed to achieve the cumulative
13    persisting annual savings goals specified in paragraphs
14    (5) through (8) of subsection (b-5) of this Section or in
15    paragraphs (5) through (8) of subsection (b-15) of this
16    Section, as applicable, through implementation of energy
17    efficiency measures; however, the goals may be reduced if
18    the utility's expenditures are limited pursuant to
19    subsection (m) of this Section or, each of the following
20    conditions are met: (A) the plan's analysis and forecasts
21    of the utility's ability to acquire energy savings
22    demonstrate that achievement of such goals is not cost
23    effective; and (B) the amount of energy savings achieved by
24    the utility as determined by the independent evaluator for
25    the most recent year for which savings have been evaluated
26    preceding the plan filing was less than the average annual

 

 

HB2956- 30 -LRB101 09743 JRG 54844 b

1    amount of savings required to achieve the goals for the
2    applicable 4-year plan period. Except as provided in
3    subsection (m) of this Section, annual increases in
4    cumulative persisting annual savings goals during the
5    applicable 4-year plan period shall not be reduced to
6    amounts that are less than the maximum amount of cumulative
7    persisting annual savings that is forecast to be
8    cost-effectively achievable during the 4-year plan period.
9    The Commission shall review any proposed goal reduction as
10    part of its review and approval of the utility's proposed
11    plan.
12        (3) No later than March 1, 2025, each electric utility
13    shall file a 5-year energy efficiency plan commencing on
14    January 1, 2026 that is designed to achieve the cumulative
15    persisting annual savings goals specified in paragraphs
16    (9) through (13) of subsection (b-5) of this Section or in
17    paragraphs (9) through (13) of subsection (b-15) of this
18    Section, as applicable, through implementation of energy
19    efficiency measures; however, the goals may be reduced if
20    the utility's expenditures are limited pursuant to
21    subsection (m) of this Section or, each of the following
22    conditions are met: (A) the plan's analysis and forecasts
23    of the utility's ability to acquire energy savings
24    demonstrate that achievement of such goals is not cost
25    effective; and (B) the amount of energy savings achieved by
26    the utility as determined by the independent evaluator for

 

 

HB2956- 31 -LRB101 09743 JRG 54844 b

1    the most recent year for which savings have been evaluated
2    preceding the plan filing was less than the average annual
3    amount of savings required to achieve the goals for the
4    applicable 5-year plan period. Except as provided in
5    subsection (m) of this Section, annual increases in
6    cumulative persisting annual savings goals during the
7    applicable 5-year plan period shall not be reduced to
8    amounts that are less than the maximum amount of cumulative
9    persisting annual savings that is forecast to be
10    cost-effectively achievable during the 5-year plan period.
11    The Commission shall review any proposed goal reduction as
12    part of its review and approval of the utility's proposed
13    plan.
14    Each utility's plan shall set forth the utility's proposals
15to meet the energy efficiency standards identified in
16subsection (b-5) or (b-15), as applicable and as such standards
17may have been modified under this subsection (f), taking into
18account the unique circumstances of the utility's service
19territory. For those plans commencing on January 1, 2018, the
20Commission shall seek public comment on the utility's plan and
21shall issue an order approving or disapproving each plan no
22later than August 31, 2017, or 105 days after June 1, 2017 (the
23effective date of Public Act 99-906) this amendatory Act of the
2499th General Assembly, whichever is later. For those plans
25commencing after December 31, 2021, the Commission shall seek
26public comment on the utility's plan and shall issue an order

 

 

HB2956- 32 -LRB101 09743 JRG 54844 b

1approving or disapproving each plan within 6 months after its
2submission. If the Commission disapproves a plan, the
3Commission shall, within 30 days, describe in detail the
4reasons for the disapproval and describe a path by which the
5utility may file a revised draft of the plan to address the
6Commission's concerns satisfactorily. If the utility does not
7refile with the Commission within 60 days, the utility shall be
8subject to penalties at a rate of $100,000 per day until the
9plan is filed. This process shall continue, and penalties shall
10accrue, until the utility has successfully filed a portfolio of
11energy efficiency and demand-response measures. Penalties
12shall be deposited into the Energy Efficiency Trust Fund.
13    (g) In submitting proposed plans and funding levels under
14subsection (f) of this Section to meet the savings goals
15identified in subsection (b-5) or (b-15) of this Section, as
16applicable, the utility shall:
17        (1) Demonstrate that its proposed energy efficiency
18    measures will achieve the applicable requirements that are
19    identified in subsection (b-5) or (b-15) of this Section,
20    as modified by subsection (f) of this Section.
21        (2) Present specific proposals to implement new
22    building and appliance standards that have been placed into
23    effect.
24        (3) Demonstrate that its overall portfolio of
25    measures, not including low-income programs described in
26    subsection (c) of this Section, is cost-effective using the

 

 

HB2956- 33 -LRB101 09743 JRG 54844 b

1    total resource cost test or complies with paragraphs (1)
2    through (3) of subsection (f) of this Section and
3    represents a diverse cross-section of opportunities for
4    customers of all rate classes, other than those customers
5    described in subsection (l) of this Section, to participate
6    in the programs. Individual measures need not be cost
7    effective.
8        (4) Present a third-party energy efficiency
9    implementation program subject to the following
10    requirements:
11            (A) beginning with the year commencing January 1,
12        2019, electric utilities that serve more than
13        3,000,000 retail customers in the State shall fund
14        third-party energy efficiency programs in an amount
15        that is no less than $25,000,000 per year, and electric
16        utilities that serve less than 3,000,000 retail
17        customers but more than 500,000 retail customers in the
18        State shall fund third-party energy efficiency
19        programs in an amount that is no less than $8,350,000
20        per year;
21            (B) during 2018, the utility shall conduct a
22        solicitation process for purposes of requesting
23        proposals from third-party vendors for those
24        third-party energy efficiency programs to be offered
25        during one or more of the years commencing January 1,
26        2019, January 1, 2020, and January 1, 2021; for those

 

 

HB2956- 34 -LRB101 09743 JRG 54844 b

1        multi-year plans commencing on January 1, 2022 and
2        January 1, 2026, the utility shall conduct a
3        solicitation process during 2021 and 2025,
4        respectively, for purposes of requesting proposals
5        from third-party vendors for those third-party energy
6        efficiency programs to be offered during one or more
7        years of the respective multi-year plan period; for
8        each solicitation process, the utility shall identify
9        the sector, technology, or geographical area for which
10        it is seeking requests for proposals;
11            (C) the utility shall propose the bidder
12        qualifications, performance measurement process, and
13        contract structure, which must include a performance
14        payment mechanism and general terms and conditions;
15        the proposed qualifications, process, and structure
16        shall be subject to Commission approval; and
17            (D) the utility shall retain an independent third
18        party to score the proposals received through the
19        solicitation process described in this paragraph (4),
20        rank them according to their cost per lifetime
21        kilowatt-hours saved, and assemble the portfolio of
22        third-party programs.
23        The electric utility shall recover all costs
24    associated with Commission-approved, third-party
25    administered programs regardless of the success of those
26    programs.

 

 

HB2956- 35 -LRB101 09743 JRG 54844 b

1        (4.5) Implement cost-effective demand-response
2    measures to reduce peak demand by 0.1% over the prior year
3    for eligible retail customers, as defined in Section
4    16-111.5 of this Act, and for customers that elect hourly
5    service from the utility pursuant to Section 16-107 of this
6    Act, provided those customers have not been declared
7    competitive. This requirement continues until December 31,
8    2026.
9        (5) Include a proposed or revised cost-recovery tariff
10    mechanism, as provided for under subsection (d) of this
11    Section, to fund the proposed energy efficiency and
12    demand-response measures and to ensure the recovery of the
13    prudently and reasonably incurred costs of
14    Commission-approved programs.
15        (6) Provide for an annual independent evaluation of the
16    performance of the cost-effectiveness of the utility's
17    portfolio of measures, as well as a full review of the
18    multi-year plan results of the broader net program impacts
19    and, to the extent practical, for adjustment of the
20    measures on a going-forward basis as a result of the
21    evaluations. The resources dedicated to evaluation shall
22    not exceed 3% of portfolio resources in any given year.
23        (7) For electric utilities that serve more than
24    3,000,000 retail customers in the State:
25            (A) Through December 31, 2025, provide for an
26        adjustment to the return on equity component of the

 

 

HB2956- 36 -LRB101 09743 JRG 54844 b

1        utility's weighted average cost of capital calculated
2        under subsection (d) of this Section:
3                (i) If the independent evaluator determines
4            that the utility achieved a cumulative persisting
5            annual savings that is less than the applicable
6            annual incremental goal, then the return on equity
7            component shall be reduced by a maximum of 200
8            basis points in the event that the utility achieved
9            no more than 75% of such goal. If the utility
10            achieved more than 75% of the applicable annual
11            incremental goal but less than 100% of such goal,
12            then the return on equity component shall be
13            reduced by 8 basis points for each percent by which
14            the utility failed to achieve the goal.
15                (ii) If the independent evaluator determines
16            that the utility achieved a cumulative persisting
17            annual savings that is more than the applicable
18            annual incremental goal, then the return on equity
19            component shall be increased by a maximum of 200
20            basis points in the event that the utility achieved
21            at least 125% of such goal. If the utility achieved
22            more than 100% of the applicable annual
23            incremental goal but less than 125% of such goal,
24            then the return on equity component shall be
25            increased by 8 basis points for each percent by
26            which the utility achieved above the goal. If the

 

 

HB2956- 37 -LRB101 09743 JRG 54844 b

1            applicable annual incremental goal was reduced
2            under paragraphs (1) or (2) of subsection (f) of
3            this Section, then the following adjustments shall
4            be made to the calculations described in this item
5            (ii):
6                    (aa) the calculation for determining
7                achievement that is at least 125% of the
8                applicable annual incremental goal shall use
9                the unreduced applicable annual incremental
10                goal to set the value; and
11                    (bb) the calculation for determining
12                achievement that is less than 125% but more
13                than 100% of the applicable annual incremental
14                goal shall use the reduced applicable annual
15                incremental goal to set the value for 100%
16                achievement of the goal and shall use the
17                unreduced goal to set the value for 125%
18                achievement. The 8 basis point value shall also
19                be modified, as necessary, so that the 200
20                basis points are evenly apportioned among each
21                percentage point value between 100% and 125%
22                achievement.
23            (B) For the period January 1, 2026 through December
24        31, 2030, provide for an adjustment to the return on
25        equity component of the utility's weighted average
26        cost of capital calculated under subsection (d) of this

 

 

HB2956- 38 -LRB101 09743 JRG 54844 b

1        Section:
2                (i) If the independent evaluator determines
3            that the utility achieved a cumulative persisting
4            annual savings that is less than the applicable
5            annual incremental goal, then the return on equity
6            component shall be reduced by a maximum of 200
7            basis points in the event that the utility achieved
8            no more than 66% of such goal. If the utility
9            achieved more than 66% of the applicable annual
10            incremental goal but less than 100% of such goal,
11            then the return on equity component shall be
12            reduced by 6 basis points for each percent by which
13            the utility failed to achieve the goal.
14                (ii) If the independent evaluator determines
15            that the utility achieved a cumulative persisting
16            annual savings that is more than the applicable
17            annual incremental goal, then the return on equity
18            component shall be increased by a maximum of 200
19            basis points in the event that the utility achieved
20            at least 134% of such goal. If the utility achieved
21            more than 100% of the applicable annual
22            incremental goal but less than 134% of such goal,
23            then the return on equity component shall be
24            increased by 6 basis points for each percent by
25            which the utility achieved above the goal. If the
26            applicable annual incremental goal was reduced

 

 

HB2956- 39 -LRB101 09743 JRG 54844 b

1            under paragraph (3) of subsection (f) of this
2            Section, then the following adjustments shall be
3            made to the calculations described in this item
4            (ii):
5                    (aa) the calculation for determining
6                achievement that is at least 134% of the
7                applicable annual incremental goal shall use
8                the unreduced applicable annual incremental
9                goal to set the value; and
10                    (bb) the calculation for determining
11                achievement that is less than 134% but more
12                than 100% of the applicable annual incremental
13                goal shall use the reduced applicable annual
14                incremental goal to set the value for 100%
15                achievement of the goal and shall use the
16                unreduced goal to set the value for 134%
17                achievement. The 6 basis point value shall also
18                be modified, as necessary, so that the 200
19                basis points are evenly apportioned among each
20                percentage point value between 100% and 134%
21                achievement.
22        (7.5) For purposes of this Section, the term
23    "applicable annual incremental goal" means the difference
24    between the cumulative persisting annual savings goal for
25    the calendar year that is the subject of the independent
26    evaluator's determination and the cumulative persisting

 

 

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1    annual savings goal for the immediately preceding calendar
2    year, as such goals are defined in subsections (b-5) and
3    (b-15) of this Section and as these goals may have been
4    modified as provided for under subsection (b-20) and
5    paragraphs (1) through (3) of subsection (f) of this
6    Section. Under subsections (b), (b-5), (b-10), and (b-15)
7    of this Section, a utility must first replace energy
8    savings from measures that have reached the end of their
9    measure lives and would otherwise have to be replaced to
10    meet the applicable savings goals identified in subsection
11    (b-5) or (b-15) of this Section before any progress towards
12    achievement of its applicable annual incremental goal may
13    be counted. Notwithstanding anything else set forth in this
14    Section, the difference between the actual annual
15    incremental savings achieved in any given year, including
16    the replacement of energy savings from measures that have
17    expired, and the applicable annual incremental goal shall
18    not affect adjustments to the return on equity for
19    subsequent calendar years under this subsection (g).
20        (8) For electric utilities that serve less than
21    3,000,000 retail customers but more than 500,000 retail
22    customers in the State:
23            (A) Through December 31, 2025, the applicable
24        annual incremental goal shall be compared to the annual
25        incremental savings as determined by the independent
26        evaluator.

 

 

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1                (i) The return on equity component shall be
2            reduced by 8 basis points for each percent by which
3            the utility did not achieve 84.4% of the applicable
4            annual incremental goal.
5                (ii) The return on equity component shall be
6            increased by 8 basis points for each percent by
7            which the utility exceeded 100% of the applicable
8            annual incremental goal.
9                (iii) The return on equity component shall not
10            be increased or decreased if the annual
11            incremental savings as determined by the
12            independent evaluator is greater than 84.4% of the
13            applicable annual incremental goal and less than
14            100% of the applicable annual incremental goal.
15                (iv) The return on equity component shall not
16            be increased or decreased by an amount greater than
17            200 basis points pursuant to this subparagraph
18            (A).
19            (B) For the period of January 1, 2026 through
20        December 31, 2030, the applicable annual incremental
21        goal shall be compared to the annual incremental
22        savings as determined by the independent evaluator.
23                (i) The return on equity component shall be
24            reduced by 6 basis points for each percent by which
25            the utility did not achieve 100% of the applicable
26            annual incremental goal.

 

 

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1                (ii) The return on equity component shall be
2            increased by 6 basis points for each percent by
3            which the utility exceeded 100% of the applicable
4            annual incremental goal.
5                (iii) The return on equity component shall not
6            be increased or decreased by an amount greater than
7            200 basis points pursuant to this subparagraph
8            (B).
9            (C) If the applicable annual incremental goal was
10        reduced under paragraphs (1), (2) or (3) of subsection
11        (f) of this Section, then the following adjustments
12        shall be made to the calculations described in
13        subparagraphs (A) and (B) of this paragraph (8):
14                (i) The calculation for determining
15            achievement that is at least 125% or 134%, as
16            applicable, of the applicable annual incremental
17            goal shall use the unreduced applicable annual
18            incremental goal to set the value.
19                (ii) For the period through December 31, 2025,
20            the calculation for determining achievement that
21            is less than 125% but more than 100% of the
22            applicable annual incremental goal shall use the
23            reduced applicable annual incremental goal to set
24            the value for 100% achievement of the goal and
25            shall use the unreduced goal to set the value for
26            125% achievement. The 8 basis point value shall

 

 

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1            also be modified, as necessary, so that the 200
2            basis points are evenly apportioned among each
3            percentage point value between 100% and 125%
4            achievement.
5                (iii) For the period of January 1, 2026 through
6            December 31, 2030, the calculation for determining
7            achievement that is less than 134% but more than
8            100% of the applicable annual incremental goal
9            shall use the reduced applicable annual
10            incremental goal to set the value for 100%
11            achievement of the goal and shall use the unreduced
12            goal to set the value for 125% achievement. The 6
13            basis point value shall also be modified, as
14            necessary, so that the 200 basis points are evenly
15            apportioned among each percentage point value
16            between 100% and 134% achievement.
17        (9) The utility shall submit the energy savings data to
18    the independent evaluator no later than 30 days after the
19    close of the plan year. The independent evaluator shall
20    determine the cumulative persisting annual savings for a
21    given plan year no later than 120 days after the close of
22    the plan year. The utility shall submit an informational
23    filing to the Commission no later than 160 days after the
24    close of the plan year that attaches the independent
25    evaluator's final report identifying the cumulative
26    persisting annual savings for the year and calculates,

 

 

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1    under paragraph (7) or (8) of this subsection (g), as
2    applicable, any resulting change to the utility's return on
3    equity component of the weighted average cost of capital
4    applicable to the next plan year beginning with the January
5    monthly billing period and extending through the December
6    monthly billing period. However, if the utility recovers
7    the costs incurred under this Section under paragraphs (2)
8    and (3) of subsection (d) of this Section, then the utility
9    shall not be required to submit such informational filing,
10    and shall instead submit the information that would
11    otherwise be included in the informational filing as part
12    of its filing under paragraph (3) of such subsection (d)
13    that is due on or before June 1 of each year.
14        For those utilities that must submit the informational
15    filing, the Commission may, on its own motion or by
16    petition, initiate an investigation of such filing,
17    provided, however, that the utility's proposed return on
18    equity calculation shall be deemed the final, approved
19    calculation on December 15 of the year in which it is filed
20    unless the Commission enters an order on or before December
21    15, after notice and hearing, that modifies such
22    calculation consistent with this Section.
23        The adjustments to the return on equity component
24    described in paragraphs (7) and (8) of this subsection (g)
25    shall be applied as described in such paragraphs through a
26    separate tariff mechanism, which shall be filed by the

 

 

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1    utility under subsections (f) and (g) of this Section.
2    (h) No more than 6% of energy efficiency and
3demand-response program revenue may be allocated for research,
4development, or pilot deployment of new equipment or measures.
5    (i) When practicable, electric utilities shall incorporate
6advanced metering infrastructure data into the planning,
7implementation, and evaluation of energy efficiency measures
8and programs, subject to the data privacy and confidentiality
9protections of applicable law.
10    (j) The independent evaluator shall follow the guidelines
11and use the savings set forth in Commission-approved energy
12efficiency policy manuals and technical reference manuals, as
13each may be updated from time to time. Until such time as
14measure life values for energy efficiency measures implemented
15for low-income households under subsection (c) of this Section
16are incorporated into such Commission-approved manuals, the
17low-income measures shall have the same measure life values
18that are established for same measures implemented in
19households that are not low-income households.
20    (k) Notwithstanding any provision of law to the contrary,
21an electric utility subject to the requirements of this Section
22may file a tariff cancelling an automatic adjustment clause
23tariff in effect under this Section or Section 8-103, which
24shall take effect no later than one business day after the date
25such tariff is filed. Thereafter, the utility shall be
26authorized to defer and recover its expenditures incurred under

 

 

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1this Section through a new tariff authorized under subsection
2(d) of this Section or in the utility's next rate case under
3Article IX or Section 16-108.5 of this Act, with interest at an
4annual rate equal to the utility's weighted average cost of
5capital as approved by the Commission in such case. If the
6utility elects to file a new tariff under subsection (d) of
7this Section, the utility may file the tariff within 10 days
8after June 1, 2017 (the effective date of Public Act 99-906)
9this amendatory Act of the 99th General Assembly, and the cost
10inputs to such tariff shall be based on the projected costs to
11be incurred by the utility during the calendar year in which
12the new tariff is filed and that were not recovered under the
13tariff that was cancelled as provided for in this subsection.
14Such costs shall include those incurred or to be incurred by
15the utility under its multi-year plan approved under
16subsections (f) and (g) of this Section, including, but not
17limited to, projected capital investment costs and projected
18regulatory asset balances with correspondingly updated
19depreciation and amortization reserves and expense. The
20Commission shall, after notice and hearing, approve, or approve
21with modification, such tariff and cost inputs no later than 75
22days after the utility filed the tariff, provided that such
23approval, or approval with modification, shall be consistent
24with the provisions of this Section to the extent they do not
25conflict with this subsection (k). The tariff approved by the
26Commission shall take effect no later than 5 days after the

 

 

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1Commission enters its order approving the tariff.
2    No later than 60 days after the effective date of the
3tariff cancelling the utility's automatic adjustment clause
4tariff, the utility shall file a reconciliation that reconciles
5the moneys collected under its automatic adjustment clause
6tariff with the costs incurred during the period beginning June
71, 2016 and ending on the date that the electric utility's
8automatic adjustment clause tariff was cancelled. In the event
9the reconciliation reflects an under-collection, the utility
10shall recover the costs as specified in this subsection (k). If
11the reconciliation reflects an over-collection, the utility
12shall apply the amount of such over-collection as a one-time
13credit to retail customers' bills.
14    (l) (Blank). For the calendar years covered by a multi-year
15plan commencing after December 31, 2017, subsections (a)
16through (j) of this Section do not apply to any retail
17customers of an electric utility that serves more than
183,000,000 retail customers in the State and whose total highest
1930 minute demand was more than 10,000 kilowatts, or any retail
20customers of an electric utility that serves less than
213,000,000 retail customers but more than 500,000 retail
22customers in the State and whose total highest 15 minute demand
23was more than 10,000 kilowatts. For purposes of this subsection
24(l), "retail customer" has the meaning set forth in Section
2516-102 of this Act. A determination of whether this subsection
26is applicable to a customer shall be made for each multi-year

 

 

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1plan beginning after December 31, 2017. The criteria for
2determining whether this subsection (l) is applicable to a
3retail customer shall be based on the 12 consecutive billing
4periods prior to the start of the first year of each such
5multi-year plan.
6    (m) Notwithstanding the requirements of this Section, as
7part of a proceeding to approve a multi-year plan under
8subsections (f) and (g) of this Section, the Commission shall
9reduce the amount of energy efficiency measures implemented for
10any single year, and whose costs are recovered under subsection
11(d) of this Section, by an amount necessary to limit the
12estimated average net increase due to the cost of the measures
13to no more than
14        (1) 3.5% for the each of the 4 years beginning January
15    1, 2018,
16        (2) 3.75% for each of the 4 years beginning January 1,
17    2022, and
18        (3) 4% for each of the 5 years beginning January 1,
19    2026,
20of the average amount paid per kilowatthour by residential
21eligible retail customers during calendar year 2015. To
22determine the total amount that may be spent by an electric
23utility in any single year, the applicable percentage of the
24average amount paid per kilowatthour shall be multiplied by the
25total amount of energy delivered by such electric utility in
26the calendar year 2015, adjusted to reflect the proportion of

 

 

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1the utility's load attributable to customers who are exempt
2from subsections (a) through (j) of this Section under
3subsection (l) of this Section. For purposes of this subsection
4(m), the amount paid per kilowatthour includes, without
5limitation, estimated amounts paid for supply, transmission,
6distribution, surcharges, and add-on taxes. For purposes of
7this Section, "eligible retail customers" shall have the
8meaning set forth in Section 16-111.5 of this Act. Once the
9Commission has approved a plan under subsections (f) and (g) of
10this Section, no subsequent rate impact determinations shall be
11made.
12(Source: P.A. 99-906, eff. 6-1-17; 100-840, eff. 8-13-18;
13revised 10-19-18.)
 
14    Section 99. Effective date. This Act takes effect upon
15becoming law.