An Act To Reduce Energy Costs, Increase Energy Efficiency, Promote Electric System Reliability and Protect the Environment
Maine Legislature, Session 126, LD 1559
Committee: Energy, Utilities and Technology pursuant to Joint Order H
Amends: 35-A MRSA §122, 35-A MRSA §3210-C, 35-A MRSA §10103, 35-A MRSA §10104, 35-A MRSA §10109, 35-A MRSA §10110, 35-A MRSA §10111, 35-A MRSA §10120, 35-A MRSA §4508, 35-A MRSA §3131, 35-A MRSA §3132, 35-A MRSA §3132-A, 38 MRSA §579, 38 MRSA §580-A, 38 MRSA §580-B, 35-A MRSA §2523, 35-A MRSA §101, 35-A MRSA §3152, 35-A MRSA §3153-A

Legislative Document 
No. 1559 
H.P. 1128 
House of Representatives, June 5, 2013 
An Act To Reduce Energy Costs, Increase Energy Efficiency, 
Promote Electric System Reliability and Protect the Environment 
Under suspension of the rules Reported by Representative HOBBINS of Saco, 
Representative FREDETTE of Newport and Senator CLEVELAND of Androscoggin for the 
Joint Standing Committee on Energy, Utilities and Technology pursuant to Joint Order H.P. 
1125. 
MILLICENT M. MacFARLAND 
Clerk 
Be it enacted by the People of the State of Maine as follows: 
PART A 
Sec. A-1.  35-A MRSA §122, sub-§6-B, as enacted by PL 2011, c. 652, §13 and 
affected by §14, is amended to read: 
6-B.  Revenue from energy infrastructure corridors.  Notwithstanding subsection 
6-A, 90% 20% of the revenues generated from the use of statutory corridors designated 
under subsection 1-A, paragraphs A and B owned by the Department of Transportation 
within energy infrastructure corridors must be deposited into the Secondary Road 
Program Fund established in Title 23, section 1803-C and 10% 80% of the revenues must 
be deposited into the energy infrastructure benefits fund established in Title 5, section 
282, subsection 9. 
Sec. A-2.  35-A MRSA §3210-C, sub-§12, as enacted by PL 2011, c. 413, §3, is 
repealed. 
Sec. A-3.  35-A MRSA §10103, sub-§1, ¶B, as enacted by PL 2009, c. 372, Pt. 
B, §3, is repealed and the following enacted in its place: 
B.  Reduce energy costs and improve security of the state and local economies. The 
trust shall administer cost-effective energy and energy efficiency programs consistent 
with applicable requirements of this chapter and other law to help individuals and 
businesses meet their energy needs at the lowest cost and generally to improve the 
economic security of the State by: 
(1) Reducing the cost of energy to residents of the State; 
(2) Maximizing the use of cost-effective weatherization and energy efficiency 
measures, including measures that improve the energy efficiency of energy-using 
systems, such as heating and cooling systems and system upgrades to energy 
efficient systems that rely on affordable energy resources; 
(3) Reducing economic insecurity from the inefficient use of fossil fuels; 
(4) Increasing new jobs and business development to deliver affordable energy 
and energy efficiency products and services; 
(5) Enhancing heating improvements for households of all income levels through 
implementation of cost-effective efficiency programs, including weatherization 
programs and affordable heating systems, that will produce comfort, improve 
indoor air quality, reduce energy costs for those households and reduce the need 
for future fuel assistance; 
(6) Simplifying and enhancing consumer access to technical assistance and 
financial incentives relating to energy efficiency and the use of alternative energy 
resources by merging or coordinating dispersed programs under a single 
administrative unit possessing independent management and expertise; and 
(7) Using cost-effective energy and energy efficiency investments to reduce 
greenhouse gas emissions; 
Sec. A-4.  35-A MRSA §10103, sub-§1, ¶D, as enacted by PL 2009, c. 372, Pt. 
B, §3, is amended to read: 
D.  Actively promote investment in cost-effective energy and energy efficiency 
measures and systems that use alternative energy resources that reduce overall energy 
costs for consumers in the State. 
Sec. A-5.  35-A MRSA §10103, sub-§4, as amended by PL 2009, c. 655, Pt. B, 
§3, is further amended to read: 
4.  Program funding.  The board may apply for and receive grants from state, 
federal and private sources for deposit into appropriate program funds, including funds 
for both residential and business programs. The board may deposit in appropriate 
program funds the proceeds of any bonds issued for the purposes of programs 
administered by the trust.  The board may receive and shall deposit in appropriate 
program funds revenue resulting from any forward capacity market or other capacity 
payments from the regional transmission organization that may be attributable to by those 
projects funded by those funds.  The board shall deposit into appropriate program funds 
revenue transferred to the trust from the energy infrastructure benefits fund pursuant to 
Title 5, section 282, subsection 9 for use in accordance with subsection 4-A. The board 
may also deposit any grants or other funds received by or from any entity with which the 
trust has an agreement or contract pursuant to this chapter if the board determines that 
receipt of those funds is consistent with the purposes of this chapter. 
Sec. A-6.  35-A MRSA §10103, sub-§4-A, ¶A, as enacted by PL 2009, c. 655, 
Pt. B, §4, is repealed and the following enacted in its place: 
A.  To improve the State's economy by pursuing lower energy costs for people, 
communities and businesses in a manner that will enhance the environment of the 
State in accordance with the triennial plan. In the expenditure of funds pursuant to 
this paragraph, the trust may provide grants, loans, programs and incentives; and 
Sec. A-7.  35-A MRSA §10104, sub-§1, as enacted by PL 2009, c. 372, Pt. B, §3, 
is amended to read: 
1.  Generally.  In accordance with this section and other applicable law, the trust 
administers and disburses funds and coordinates programs to promote reduced energy 
costs, energy efficiency and increased use of alternative energy resources in the State. 
The trust is responsible for accounting for, evaluating and monitoring all activities of the 
trust and all programs funded in whole or in part by the trust. 
Sec. A-8.  35-A MRSA §10104, sub-§2, ¶B, as enacted by PL 2009, c. 372, Pt. 
B, §3, is amended to read: 
B.  The effectiveness of programs is maximized by building up and centralizing 
expertise, addressing conflicts of interest, mitigating the influence of politics, 
promoting flexible, timely program management and providing a champion for 
funding cost-effective energy and energy efficiency programs; 
Sec. A-9.  35-A MRSA §10104, sub-§3, as enacted by PL 2009, c. 372, Pt. B, §3, 
is amended to read: 
3.  Measures of performance.  The trust shall develop quantifiable measures of 
performance for all programs it administers and to which it will hold accountable all 
recipients of funding from the trust and recipients of funds used to deliver energy and 
energy efficiency and weatherization programs administered or funded by the trust.  Such 
measures may include, but are not limited to, reduced energy consumption, increased use 
of alternative energy resources, reduced heating costs, reduced capacity demand for 
natural gas, electricity and fossil fuels, reduced carbon dioxide emissions, program and 
overhead costs and cost-effectiveness, the number of new jobs created by the award of 
trust funds, the number of energy efficiency trainings or certification courses completed 
and the amount of sales generated. 
Sec. A-10.  35-A MRSA §10104, sub-§4, ¶A, as enacted by PL 2009, c. 372, Pt. 
B, §3, is amended to read: 
A.  The triennial plan must be developed by the trust, in consultation with entities and 
agencies engaged in delivering efficiency programs in the State, to authorize and 
govern or coordinate implementation of energy efficiency and weatherization 
programs in the State.  The triennial plan must identify all achievable cost-effective 
energy efficiency savings and related programs that could be implemented pursuant 
to sections 10110 and 10111, the costs and benefits of such programs and the basis 
and support for such identified costs and benefits. The trust shall conduct an 
evaluation of all cost-effective potential for electrical and natural gas energy 
efficiency savings in the State at least once every 5 years. 
(1)  Transmission and distribution utilities and natural gas utilities shall furnish 
data to the trust that the trust requests under this subsection to develop and 
implement the triennial plan or conduct the evaluation of all cost-effective 
potential for electrical and natural gas energy efficiency savings subject to such 
confidential treatment as a utility may request and the board determines 
appropriate pursuant to section 10106.  The costs of providing the data are 
deemed reasonable and prudent expenses of the utilities and are recoverable in 
rates. 
Sec. A-11.  35-A MRSA §10104, sub-§4, ¶C, as enacted by PL 2009, c. 372, Pt. 
B, §3, is amended to read: 
C.  The board shall review and approve the triennial plan by affirmative vote of 2/3 of 
the trustees upon a finding that the plan is consistent with the statutory authority for 
each source of funds that will be used to implement the plan, advances the state 
energy efficiency targets in paragraph F and reflects the best practices of program 
administration under subsection 2. The plan must include, but is not limited to, 
efficiency and conservation program budget allocations, objectives, targets, measures 
of performance, program designs, program implementation strategies, timelines and 
other relevant information. 
Sec. A-12.  35-A MRSA §10104, sub-§4, ¶D, as amended by PL 2009, c. 518, 
§8, is further amended to read: 
D.  Prior to submission of the triennial plan to the commission, the trust shall offer to 
provide a detailed briefing on the draft plan to the joint standing committee of the 
Legislature having jurisdiction over energy matters and, at the request of the 
committee, shall provide such a briefing and opportunity for input from the 
committee.  After providing such opportunity for input and making any changes as a 
result of any input received, the board shall deliver the plan to the commission for its 
review and approval.  The commission shall open a an adjudicatory proceeding and 
issue an order either approving the plan and issuing the appropriate orders to 
transmission and distribution utilities and gas utilities or rejecting the plan and stating 
the reasons for the rejection.  The commission shall reject elements of the plan that 
propose to use funds generated pursuant to sections 3210-C, 10110, 10111 or 10119 
if the plan fails to reasonably explain how these elements of the program would 
achieve the objectives and implementation requirements of the programs established 
under those sections or the measures of performance under subsection 3.  Funds 
generated under these statutory authorities may not be used pursuant to the triennial 
plan unless those elements of the plan proposing to use the funds have been approved 
by the commission.  The commission shall approve or reject any all elements of the 
triennial plan it determines to be cost-effective, reliable and achievable and shall 
incorporate into gas utility and transmission and distribution rates sufficient revenue 
to provide for the procurement of energy efficiency resources identified within the 
plan pursuant to section 10110, subsection 4-A and section 10111, subsection 2. The 
commission shall approve or reject the entire plan or elements of the plan within 60 
days of its delivery to the commission.  The board, within 15 30 days of final 
commission approval of its plan, shall submit the plan to the joint standing committee 
of the Legislature having jurisdiction over energy matters together with any 
explanatory or other supporting material as the committee may request and, at the 
request of the committee, shall provide a detailed briefing on the final plan.  After 
receipt of the plan, the joint standing committee of the Legislature having jurisdiction 
over energy matters may submit legislation relating to the plan. 
Sec. A-13.  35-A MRSA §10104, sub-§4, ¶F, as amended by PL 2009, c. 518, 
§8, is repealed and the following enacted in its place: 
F.  It is an objective of the triennial plan to design, coordinate and integrate sustained 
energy efficiency and weatherization programs that are available to all energy 
consumers in the State and to users of all fuel types. The plan must set forth the costs 
and benefits of energy efficiency programs that advance the following goals, and 
funding necessary to meet those goals: 
(1)  Reducing energy costs, including residential heating costs; 
(2) Weatherizing substantially all homes whose owners or occupants are willing 
to participate in and share the costs of cost-effective home weatherization to a 
minimum standard of weatherization, as defined by the trust, by 2030; 
(3) Reducing peak-load demand for electricity through trust programs by 300 
megawatts by 2020; 
(4) By 2020, achieving electricity and natural gas program savings of at least 
20% and heating fuel savings of at least 20%, as defined in and determined 
pursuant to the measures of performance approved by the commission under 
section 10120; 
(5) Creating stable private sector jobs providing alternative energy and energy 
efficiency products and services in the State by 2020; and 
(6) Reducing greenhouse gas emissions from the heating and cooling of buildings 
in the State by amounts consistent with the State's goals established in Title 38, 
section 576. 
The trust shall preserve when possible and appropriate the opportunity for carbon 
emission reductions to be monetized and sold into a voluntary carbon market. Any 
program of the trust that supports weatherization of buildings must be voluntary and 
may not constitute a mandate that would prevent the sale of emission reductions 
generated through weatherization measures into a voluntary carbon market. 
Except when specifically provided in the individual goals under this paragraph, the 
trust may consider expected savings from market effects not attributable to the trust 
as well as efforts by other organizations, including but not limited to federally funded 
low-income weatherization programs. 
As used in this paragraph, "heating fuel" means liquefied petroleum gas, kerosene or 
#2 heating oil, but does not include fuels when used for industrial or manufacturing 
processes. 
Sec. A-14.  35-A MRSA §10109, sub-§3, as enacted by PL 2009, c. 372, Pt. B, 
§3, is repealed. 
Sec. A-15.  35-A MRSA §10109, sub-§4, ¶A, as enacted by PL 2009, c. 372, Pt. 
B, §3, is amended to read: 
A.  During the years 2009, 2010 and 2011 fiscal years 2013-14, 2014-15 and 2015-
16, not less than 85% 50% of the trust fund funds received during those years must be 
allocated for measures, investments and arrangements that reduce electricity 
consumption or reduce greenhouse gas emissions and lower energy costs at 
commercial or industrial facilities, and not more than 15% 35% of the funds received 
by the trust fund during those years must be allocated for fossil fuel conservation 
measures, investments and arrangements used for investment in measures that lower 
residential heating energy demand and reduce greenhouse gas emissions.  The 
measures that lower residential heating demand must be fuel-neutral and may 
include, but are not limited to, energy efficiency improvements to residential 
buildings and upgrades to efficient heating systems that will reduce residential energy 
costs and greenhouse gas emissions, as determined by the board. The trust shall 
transfer to the commission 15% of funds received by the trust fund during fiscal years 
2013-14, 2014-15 and 2015-16, which the commission shall direct transmission and 
distribution utilities to disburse to ratepayers in a manner that provides maximum 
benefit to the Maine economy. Subject to the apportionment between fossil fuel and 
electricity conservation pursuant to this subsection, the trust shall fund conservation 
programs that give priority to measures with the highest benefit-to-cost ratio, as long 
as cost-effective collateral efficiency opportunities are not lost, and that: 
(1)  Reliably reduce greenhouse gas production and heating energy costs by fossil 
fuel combustion in the State at the lowest cost in funds from the trust fund per 
unit of emissions; or 
(2)  Reliably reduce the consumption of electricity in the State at the lowest cost 
in funds from the trust fund per kilowatt-hour saved. 
Sec. A-16.  35-A MRSA §10109, sub-§4, ¶D, as amended by PL 2009, c. 565, 
§6 and affected by §9, is further amended to read: 
D.  Nonelectric savings programs must be used to maximize fossil fuel energy 
efficiency and conservation and associated greenhouse gas reductions, subject to the 
apportionment between fossil fuel and electricity conservation set forth in paragraph 
A.  Community-based renewable energy projects, as defined in section 3602, 
subsection 1, may apply for funding from the trust as nonelectric savings programs to 
the extent they are eligible under paragraph A. 
Sec. A-17.  35-A MRSA §10109, sub-§4, ¶J, as enacted by PL 2009, c. 372, Pt. 
B, §3, is amended to read: 
J.  Trust fund receipts may must, upon request by the Department of Environmental 
Protection, fund research approved by the Department of Environmental Protection in 
an amount of up to $100,000 per year to develop new categories for carbon dioxide 
emissions offset projects, as defined in Title 38, section 580-A, subsection 6, that are 
located in the State. Expenditures on research pursuant to this paragraph are not 
considered administrative costs under paragraph F, subparagraph (1). 
Sec. A-18.  35-A MRSA §10110, sub-§2, ¶B, as enacted by PL 2009, c. 372, Pt. 
B, §3, is amended to read: 
B.  The trust, with regard to the assessment imposed under subsection 4 funds 
available to the trust under this section, shall: 
(1)  Target at least 20% 10% of funds for electricity conservation collected under 
subsection 4 or 4-A or $2,600,000, whichever is greater, to programs for low-
income residential consumers, as defined by the board by rule; 
(2)  Target at least 20% 10% of funds for electricity conservation collected under 
subsection 4 or 4-A or $2,600,000, whichever is greater, to programs for small 
business consumers, as defined by the board by rule; and 
(3)  To the greatest extent practicable, apportion remaining funds among 
customer groups and geographic areas in a manner that allows all other customers 
to have a reasonable opportunity to participate in one or more conservation 
programs. 
Sec. A-19.  35-A MRSA §10110, sub-§4, as enacted by PL 2009, c. 372, Pt. B, 
§3, is repealed. 
Sec. A-20.  35-A MRSA §10110, sub-§4-A is enacted to read: 
4-A.  Procurement of cost-effective energy efficiency resources.  The commission 
shall ensure that transmission and distribution utilities on behalf of their ratepayers 
procure all electric energy efficiency resources found by the commission to be cost-
effective, reliable and achievable pursuant to section 10104, subsection 4, except that the 
commission may not require the inclusion in rates under this subsection of a total amount 
that exceeds 4% of total retail electricity transmission and distribution sales in the State as 
determined by the commission by rule.  The cost of procurement of cost-effective electric 
energy efficiency resources is a just and reasonable element of rates.  The commission 
may issue any appropriate orders to transmission and distribution utilities necessary to 
achieve the goals of this subsection.  When determining the amount of cost-effective 
electric energy efficiency resources to be procured under this subsection, the commission 
shall: 
A.  Consider electric energy efficiency resources that are reasonably foreseeable to be 
acquired by the trust using all other sources of revenue, including, but not limited to, 
the Regional Greenhouse Gas Initiative Trust Fund under section 10109; 
B.  Ensure that calculations of avoided energy costs and the budget identified by the 
trust in its triennial plan as needed to capture all cost-effective electric energy 
efficiency resources are reasonable, based on sound evidence and make use of best 
practices across the region; and 
C.  Maximize total electricity savings for all ratepayers. 
The commission shall consider gross efficiency savings for the purpose of determining 
savings that are cost-effective, reliable and achievable and shall consider both net and 
gross efficiency savings for the purpose of determining the appropriateness of the amount 
identified by the trust in its triennial plan as needed to capture all cost-effective electric 
energy efficiency resources. 
Rules adopted under this subsection are routine technical rules under Title 5, chapter 375, 
subchapter 2-A. 
Sec. A-21.  35-A MRSA §10110, sub-§5, as amended by PL 2009, c. 518, §10, is 
repealed. 
Sec. A-22.  35-A MRSA §10110, sub-§6, as enacted by PL 2009, c. 372, Pt. B, 
§3, is amended to read: 
6.  Transmission and subtransmission voltage level.  After July 1, 2007, electricity 
customers receiving service at transmission and subtransmission voltage levels are not 
eligible for new conservation programs undertaken under this section, and those 
customers are not required to pay in rates any amount associated with the assessment 
imposed on transmission and distribution utilities under subsection 4 or subsection 5 , or 
any amount associated with any procurement of energy efficiency resources by 
transmission and distribution utilities ordered under subsection 4-A.  To remove the 
amount of the assessment under subsection 4, the commission shall reduce the rates of 
such customers by 0.145 cent per kilowatt-hour.  For the purposes of this section, 
"transmission voltage levels" means 44 kilovolts or more, and "subtransmission voltage 
levels" means 34.5 kilovolts. 
Sec. A-23.  35-A MRSA §10110, sub-§8, as enacted by PL 2009, c. 372, Pt. B, 
§3, is amended to read: 
8.  Administration fund.  The trust shall establish a conservation may transfer up to 
9% of funds collected pursuant to this section to its administration fund to be used solely 
to defray administrative costs.  The commission, at the direction of the trust, may 
annually deposit funds collected pursuant to this section into the administration fund up 
to a maximum in any fiscal year of up to 9% of total funds received pursuant to 
subsections 4 and 5.  Any interest on funds in the administration fund must be credited to 
the administration fund and any funds unspent in any fiscal year must either remain in the 
administration fund to be used to defray administrative costs or be transferred to the 
program fund. 
Sec. A-24.  35-A MRSA §10110, sub-§10, as enacted by PL 2009, c. 372, Pt. B, 
§3, is amended to read: 
10.  Funds held in trust.  All funds collected from electricity consumers pursuant to 
this section are collected under the authority and for the purposes of this section and are 
deemed to be held in trust for the purposes of benefiting electricity consumers.  In the 
event funds are not expended or contracted for expenditure within 2 years of being 
collected from consumers, the commission shall return ensure that the value of those 
funds is returned to consumers by appropriate reductions in the assessment collected 
pursuant to subsection 4. 
Sec. A-25.  35-A MRSA §10111, sub-§2, as amended by PL 2011, c. 637, §7, is 
further amended to read: 
2.  Funding level.  The natural gas conservation fund, which is a nonlapsing fund, is 
established to carry out the purposes of this section.  The commission shall assess each 
gas utility that serves at least 5,000 residential customers an amount that is no less than 
3% of the gas utility's delivery revenues as defined by commission rule.  In, in 
accordance with the triennial plan, the commission may assess a higher an amount 
necessary to capture all cost-effective energy efficiency that is achievable and reliable.  
All amounts collected under this subsection must be transferred to the natural gas 
conservation fund.  Any interest on funds in the fund must be credited to the fund.  Funds 
not spent in any fiscal year remain in the fund to be used for the purposes of this section. 
The assessments charged to gas utilities under this section are just and reasonable costs 
for rate-making purposes and must be reflected in the rates of gas utilities. 
All funds collected pursuant to this section are collected under the authority and for the 
purposes of this section and are deemed to be held in trust for the purposes of benefiting 
natural gas consumers served by the gas utilities assessed under this subsection. In the 
event funds are not expended or contracted for expenditure within 2 years of being 
collected from consumers, the commission shall return ensure that the value of those 
funds is returned to consumers by appropriate reductions in the assessment collected 
pursuant to this subsection. 
Rules adopted by the commission under this subsection are routine technical rules as 
defined in Title 5, chapter 375, subchapter 2-A. 
Sec. A-26.  35-A MRSA §10120, sub-§3, as enacted by PL 2009, c. 372, Pt. B, 
§3, is amended to read: 
3.  Oversight and evaluation fund.  The commission may shall establish an 
oversight and evaluation fund to be used solely to defray the commission's projected costs 
of overseeing ongoing oversight of the trust trust's programs and results, including but not 
limited to reviewing the trust's calculation of program costs and benefits, measurement 
and verification procedures and program evaluations and reviewing and approving the 
triennial plan and contracting. The commission may use funds to contract with expert 
3rd-party resources to provide technical assistance or impartial evaluation of the 
performance of energy efficiency programs administered by the trust.  The commission 
may assess the trust an amount not to exceed 1% of the total funds administered by the 
trust, and the trust shall transfer that amount to the commission to be deposited into the 
oversight and evaluation fund.  Any interest on funds in the oversight and evaluation fund 
must be credited to the oversight and evaluation fund and any funds unspent in any fiscal 
year must either remain in the oversight and evaluation fund to be used for the purposes 
specified in this subsection or be transferred to the trust for deposit in appropriate 
program funds. 
Sec. A-27.  Maine Yankee settlement funds.  The Public Utilities Commission 
shall direct any transmission and distribution utility in this State that is the recipient of 
funds pursuant to a damage award received pursuant to litigation with the United States 
Department of Energy concerning decommissioning costs related to Maine Yankee 
Atomic Power Company, referred to in this section as "settlement funds," to disburse 
those settlement funds according to this section. 
1.  Fiscal years 2013-14 and 2014-15.  In fiscal years 2013-14 and 2014-15, the 
Public Utilities Commission shall require the payment of 55% of any settlement funds 
received by a transmission and distribution utility to the Efficiency Maine Trust to be 
used by the trust for electric efficiency and conservation programs pursuant to the Maine 
Revised Statutes, Title 35-A, section 10110 in accordance with the trust's triennial plan, 
except that if a utility's proportional share of the settlement funds paid to the trust by all 
transmission and distribution utilities exceeds that utility's proportional share of retail 
kilowatt hours delivered in this State by those transmission and distribution utilities, the 
commission shall allocate the excess to that transmission and distribution utility to reduce 
stranded costs. 
The commission shall require the remaining 45% of the settlement funds to be used to 
reduce the transmission and distribution utility's rates in a manner that provides 
maximum benefit to the economy of the State.  
2. In fiscal year 2015-16.  In fiscal year 2015-16, the Public Utilities Commission 
shall require the payment of a total of $2,000,000 of the settlement funds received by 
transmission and distribution utilities to the Efficiency Maine Trust to be used by the trust 
for electric efficiency and conservation programs pursuant to Title 35-A, section 10110 in 
accordance with the trust's triennial plan.  The proportional share of the $2,000,000 
provided from each transmission and distribution utility's settlement funds must be the 
same as that transmission and distribution utility's proportional share of the total retail 
kilowatt hours delivered in this State by all the transmission and distribution utilities 
receiving settlement funds. 
The commission shall require the remaining funds to be used to reduce the transmission 
and distribution utility's rates in a manner that provides maximum benefit to the economy 
of the State. 
3.  After fiscal year 2015-16. After fiscal year 2015-16, the Public Utilities 
Commission shall ensure that all settlement funds are allocated in a manner that provides 
maximum benefit to the economy of the State. 
Sec. A-28.  Efficiency Maine Trust contract for capacity resources.  The 
Public Utilities Commission shall direct investor-owned transmission and distribution 
utilities to enter into long-term contracts as described in the order issued by the 
commission on February 13, 2013 under Docket No. 2012-00408. 
Sec. A-29.  Other long-term contracts.  The Public Utilities Commission shall 
convene a stakeholder group to examine, and make policy recommendations to the 
Legislature regarding, financing and implementing energy efficiency and combined heat 
and power projects for transmission and subtransmission-level customers in an effective 
and fair manner. Except for the long-term contracts described in the order issued by the 
commission on February 13, 2013 under Docket No. 2012-00408, the commission may 
not approve long-term contracts under the Maine Revised Statutes, Title 35-A, section 
3210-C for energy efficiency and demand capacity resources affecting transmission and 
subtransmission customers prior to the commission's providing a report to the Legislature 
on the stakeholder group findings. 
Sec. A-30.  Effective date.  That section of this Part that repeals the Maine 
Revised Statutes, Title 35-A, section 10110, subsection 4 takes effect July 1, 2015.  That 
section of this Part that enacts Title 35-A, section 10110, subsection 4-A takes effect 
January 1, 2015. 
PART B 
Sec. B-1.  35-A MRSA c. 19 is enacted to read: 
CHAPTER 19 
THE MAINE ENERGY COST REDUCTION ACT 
§1901.  Short title 
This chapter may be known and cited as "the Maine Energy Cost Reduction Act." 
§1902.  Definitions 
As used in this chapter, unless the context otherwise indicates, the following terms 
have the following meanings. 
1.  Basis differential.  "Basis differential" means the difference between the so-called 
Henry Hub spot price for natural gas and the corresponding cash spot price for natural gas 
in New England. 
2.  Energy cost reduction contract. "Energy cost reduction contract" or "contract" 
means a contract executed in accordance with this chapter to procure capacity on a 
natural gas transmission pipeline, including, when applicable, compression capacity. 
3.  ISO-NE region.  "ISO-NE region" means the region in which the New England 
bulk power system operated by the independent system operator of the New England bulk 
power system or a successor organization is located. 
4.  Pipeline capacity holder.  "Pipeline capacity holder" means any person owning 
rights to natural gas pipeline capacity. 
5.  Trust fund.  "Trust fund" means the Energy Cost Reduction Trust Fund 
established under section 1907, subsection 1. 
§1903.  Legislative findings 
The Legislature finds that: 
1.  Electricity prices.  It is in the public interest to decrease prices of electricity and 
natural gas for consumers in this State; and 
2.  Natural gas expansion.  The expansion of natural gas transmission capacity into 
this State and other states in the ISO-NE region could result in lower natural gas prices 
and, by extension, lower electricity prices for consumers in this State. 
§1904.  Energy cost reduction contracts 
The commission in consultation with the Public Advocate and Governor's Energy 
Office may execute an energy cost reduction contract in accordance with this section.  In 
no event may the commission execute energy cost reduction contracts for the 
transmission of greater than a cumulative total of 200,000,000 cubic feet of natural gas 
per day or for a total amount that exceeds $75,000,000 annually.  
1.  Prior to executing an energy cost reduction contract.  Before executing an 
energy cost reduction contract, the commission shall: 
A.  Pursue, in appropriate regional and federal forums, market and rule changes that 
will reduce the basis differential for gas coming into New England and increase the 
efficiency with which gas brought into New England and Maine is transmitted, 
distributed and used. If the commission concludes that those market or rule changes 
will, within the same time frame, achieve substantially the same cost reduction 
effects for Maine electricity and gas customers as the execution of an energy cost 
reduction contact, the commission may not execute an energy cost reduction contract; 
B.  Explore all reasonable opportunities for private participation in securing 
additional gas pipeline capacity that would achieve the objectives in subsection 2. If 
the commission concludes that private transactions, within the same time frame, 
achieve substantially the same cost reduction effects for Maine electricity and gas 
customers as the execution of an energy cost reduction contact, the commission may 
not execute an energy cost reduction contract; and 
C.  In consultation with the Public Advocate and the Governor's Energy Office, hire a 
consultant with expertise in natural gas markets to make recommendations regarding 
the execution of an energy cost reduction contract. The commission shall consider 
those recommendations as part of an adjudicatory proceeding under subsection 2. 
2.  Commission determination of benefits.  After satisfying the requirements of 
subsection 1, the commission may execute or direct one or more transmission and 
distribution utilities, gas utilities or natural gas pipeline utilities to execute an energy cost 
reduction contract if the commission has determined, in an adjudicatory proceeding, that 
the agreement is commercially reasonable and in the public interest and that the contract 
is reasonably likely to: 
A.  Materially enhance natural gas transmission capacity into the State or into the 
ISO-NE region and that additional capacity will be economically beneficial to electric 
consumers, natural gas consumers or both in the State and that the overall costs of the 
contract are outweighed by its benefits to electric consumers, natural gas consumers 
or both in the State; and 
B.  Enhance electrical and natural gas reliability in the State. 
3.  Parties to an energy cost reduction contract.  The commission may execute, or 
direct to be executed, an energy cost reduction contract that contains the following 
provisions. 
A.  The commission may direct one or more transmission and distribution utilities, 
gas utilities or natural gas pipeline utilities to be a counterparty to an energy cost 
reduction contract. In determining whether and to what extent to direct a utility to be 
a counterparty to a contract under this subsection, the commission shall consider the 
anticipated reduction in the price of gas or electricity, as applicable, accruing to the 
customers of the utility as a result of the contract as determined by the commission in 
an adjudicatory proceeding. 
Any economic loss, including but not limited to any effects on the cost of capital 
resulting from an energy cost reduction contract for a transmission and distribution 
utility, a gas utility or a natural gas pipeline utility, is deemed to be prudent and the 
commission shall allow full recovery through the utility's rates.  
B.  If the commission concludes that an energy cost reduction contract can be 
achieved with the participation of other entities, the commission may contract jointly 
with other entities, including other state agencies and instrumentalities, governments 
in other states and nations, utilities and generators. 
C.  The commission may execute an energy cost reduction contract as a principal and 
counterparty. 
4.  Approval by the Governor.  The commission may not execute or direct the 
execution of an energy cost reduction contract unless the Governor has in writing 
approved the execution of the energy cost reduction contract. 
§1905.  Funding of an energy cost reduction contract 
An energy cost reduction contract may be funded in accordance with this section. 
1.  Assessments on ratepayers.  The commission may direct one or more 
transmission and distribution utilities, gas utilities or natural gas pipeline utilities to 
collect an assessment from ratepayers for the following purposes: 
A.  To finance the participation of a transmission and distribution utility, a gas utility 
or a natural gas pipeline utility in an energy cost reduction contract; and 
B.  To pay the costs of energy cost reduction contract evaluation and administration 
under section 1906, subsection 2. 
All assessments must be just and reasonable as determined by the commission and must 
be identified as an energy cost reduction contract charge on a ratepayer's utility bill. 
When determining just and reasonable assessments, the commission shall consider the 
anticipated reduction in the price of gas or electricity, as applicable, accruing to different 
categories of ratepayers as a result of the contract. 
2.  Assessments on utilities.  If the commission is the principal and counterparty on 
the contract, the commission may: 
A.  Assess one or more transmission and distribution utilities,  gas utilities and 
natural gas pipeline utilities in proportion to the anticipated reduction in the price of 
gas or electricity, as applicable, accruing as a result of the contract to the customers 
of the utility for any and all net costs to the commission of the commission's 
performance of the contract as determined by the commission in an adjudicatory 
proceeding.  The cost to the utility of the assessment may be recovered by the utility 
in rates in the same manner as any other prudently incurred cost. 
3.  Volumetric fee.  The commission may establish and direct the payment to the 
trust fund of a volumetric fee on the use of gas by a consumer of natural gas obtained 
from a source other than a gas utility or a natural gas pipeline utility of this State in 
proportion to the anticipated reduction in the price of gas accruing to that consumer as a 
result of the contract as determined by the commission in an adjudicatory proceeding. 
§1906.  Contract resale and administration 
The following provisions govern the resale and evaluation and administration of an 
energy cost reduction contract. 
1.  Resale of natural gas pipeline capacity.  The commission may negotiate and 
enter into contracts for the resale of all or a portion of the reserved natural gas 
transmission pipeline capacity acquired through an energy cost reduction contract. All of 
the revenue received as a result of the resale must be deposited into the trust fund. 
2.  Contract evaluation and administration.  The commission is responsible for 
assessing, analyzing, negotiating, implementing and monitoring compliance with energy 
cost reduction contracts. The commission may use funds for this purpose from the trust 
fund or may collect funds for this purpose through just and reasonable assessments placed 
on a transmission and distribution utility, a gas utility or a natural gas pipeline utility 
pursuant to section 1905, subsection 1, paragraph B. 
§1907.  Revenues from energy cost reduction contracts 
Revenues received from the resale of natural gas pipeline capacity acquired through 
an energy cost reduction contract must be used in accordance with this section. 
1.  Establishment of Energy Cost Reduction Trust Fund.  The Energy Cost 
Reduction Trust Fund is established as a nonlapsing fund administered by the 
commission for the purposes of this chapter. The commission is authorized to receive and 
shall deposit in the trust fund and expend in accordance with this section revenues 
received from an energy cost reduction contract and revenues received from the resale of 
natural gas pipeline capacity acquired through an energy cost reduction contract. 
The funds in the trust fund are held in trust for the purpose of reducing the energy costs of 
consumers in the State and may not be used for any other purpose, except as described in 
subsection 2. 
2.  Distribution of funds.  The commission shall distribute funds in the trust fund in 
the following order of priority: 
A.  As a first priority, to the costs of monitoring and administering a contract 
pursuant to section 1906, subsection 2; and 
B.  As a 2nd priority, to utilities and other entities to reduce energy costs for 
electricity and natural gas ratepayers and consumers subject to a volumetric fee under 
section 1905, subsection 3. The commission may distribute funds to benefit 
ratepayers of one or more transmission and distribution utilities, gas utilities or 
natural gas pipeline utilities or consumers subject to a volumetric fee under section 
1905, subsection 3 in a manner that the commission finds is equitable, just and 
reasonable. 
§1908.  Exemption from State Purchasing Agent rules 
Notwithstanding any other provision of law, agreements and contracts entered into 
pursuant to this chapter are not subject to the competitive bid requirements of the State 
Purchasing Agent. 
§1909.  Market power investigation 
The commission may on its own motion, with or without notice, summarily 
investigate the exercise of market power by a gas utility, natural gas pipeline utility or 
pipeline capacity holder. If, after the summary investigation, the commission determines 
it to be necessary, it may hold a public hearing in accordance with section 1304. 
Notwithstanding section 1304 and Title 5, section 9052, the commission shall notify the 
utility under investigation in writing of the matter under investigation and 7 days after the 
commission has given notice the commission may set the time and place for the public 
hearing. 
§1910.  Rulemaking 
The commission may adopt rules to implement this chapter. When adopting rules, the 
commission shall consider the financial implications of this chapter for transmission and 
distribution utilities, gas utilities and natural gas pipeline utilities. Rules adopted pursuant 
to this section are routine technical rules as defined in Title 5, chapter 375, subchapter 
2-A. 
§1911.  Reports 
The commission shall include in its annual report under section 120, subsection 3 a 
description of its efforts to pursue, in appropriate regional and federal forums, market and 
rule changes that will reduce the basis differential for natural gas coming into New 
England. 
§1912.  Limitation 
The commission may not execute an energy cost reduction contract under this chapter 
after December 31, 2018. The commission may continue to administer existing contracts 
and enter into agreements regarding the resale of natural gas pipeline capacity purchased 
through an energy cost reduction contract after December 31, 2018.  
Sec. B-2.  35-A MRSA §4508, sub-§1, as enacted by PL 1987, c. 141, Pt. A, §6, 
is amended to read: 
1.  Natural gas pipeline utilities subject to commission's authority.  A natural gas 
pipeline utility organized to construct or operate an interstate natural gas pipeline, which 
that holds a certificate of public convenience and necessity issued under the Federal 
Natural Gas Act authorizing it to construct or operate a natural gas pipeline and 
appurtenant facilities within the State, or an intrastate natural gas pipeline utility, which 
that has obtained authorization from the commission, is subject to the authority of the 
commission.  The commission shall adopt policies that reduce the probability of methane 
leakage from facilities as part of its regulation under this chapter. 
Sec. B-3.  Report.  The Public Utilities Commission shall report to the joint 
standing committee of the Legislature having jurisdiction over utilities and energy 
matters on the status of energy cost reduction contracts under the Maine Revised Statutes, 
Title 35-A, chapter 19 by December 31, 2015.  After receipt of the report, the joint 
standing committee may submit legislation relating to the report. 
PART C 
Sec. C-1.  35-A MRSA §3131, sub-§4-B is enacted to read: 
4-B.  Nontransmission alternative.  "Nontransmission alternative" means any of the 
following methods used either individually or combined to reduce the need for the 
construction of a transmission line under section 3132 or transmission project under 
section 3132-A: energy efficiency and conservation, load management, demand response 
or distributed generation. 
Sec. C-2.  35-A MRSA §3132, sub-§2-C, ¶¶B and C, as enacted by PL 2009, 
c. 309, §2, are amended to read: 
B.  Justification for adoption of the route selected, including comparison with 
alternative routes that are environmentally, technically and economically practical; 
and 
C.  Results of an investigation by an independent 3rd party, which may be the 
commission or a contractor selected by the commission, of nontransmission 
alternatives to construction of the proposed transmission line including energy 
conservation, distributed generation or load management.  The investigation must set 
forth the total projected costs of the transmission line as well as the total projected 
costs of the alternatives over the effective life of the proposed transmission line; and 
Sec. C-3.  35-A MRSA §3132, sub-§2-C, ¶D is enacted to read: 
D.  A description of the need for the proposed transmission line. 
Sec. C-4.  35-A MRSA §3132, sub-§5, as enacted by PL 1987, c. 141, Pt. A, §6, 
is amended to read: 
5.  Commission approval of a proposed line.  The commission may approve or 
disapprove all or portions of a proposed transmission line and shall make such orders 
regarding its character, size, installation and maintenance as are necessary, having regard 
for any increased costs caused by the orders.  The commission shall give preference to the 
nontransmission alternatives that have been identified as able to address the identified 
need for the proposed transmission line at lower total cost to ratepayers in this State.  
When the costs to ratepayers in this State of the identified nontransmission alternatives 
are reasonably equal, the commission shall give preference to the alternatives that 
produce the lowest amount of local air emissions, including greenhouse gas emissions. 
Sec. C-5.  35-A MRSA §3132, sub-§6, as repealed and replaced by PL 2011, c. 
281, §1, is amended to read: 
6.  Commission order; certificate of public convenience and necessity.  In its 
order, the commission shall make specific findings with regard to the public need for the 
proposed transmission line.  The commission shall make specific findings with regard to 
the likelihood that nontransmission alternatives can sufficiently address the identified 
public need over the effective life of the transmission line at lower total cost.  Except as 
provided in subsection 6-A for a high-impact electric transmission line and in accordance 
with subsection 6-B regarding nontransmission alternatives, if the commission finds that 
a public need exists, after considering whether the need can be economically and reliably 
met using nontransmission alternatives, it shall issue a certificate of public convenience 
and necessity for the transmission line.  In determining public need, the commission shall, 
at a minimum, take into account economics, reliability, public health and safety, scenic, 
historic and recreational values, state renewable energy generation goals, the proximity of 
the proposed transmission line to inhabited dwellings and alternatives to construction of 
the transmission line, including energy conservation, distributed generation or load 
management. If the commission orders or allows the erection of the transmission line, the 
order is subject to all other provisions of law and the right of any other agency to approve 
the transmission line.  The commission shall, as necessary and in accordance with 
subsections 7 and 8, consider the findings of the Department of Environmental Protection 
under Title 38, chapter 3, subchapter 1, article 6, with respect to the proposed 
transmission line and any modifications ordered by the Department of Environmental 
Protection to lessen the impact of the proposed transmission line on the environment. A 
person may submit a petition for and obtain approval of a proposed transmission line 
under this section before applying for approval under municipal ordinances adopted 
pursuant to Title 30-A, Part 2, Subpart 6-A; and Title 38, section 438-A and, except as 
provided in subsection 4, before identifying a specific route or route options for the 
proposed transmission line.  Except as provided in subsection 4, the commission may not 
consider the petition insufficient for failure to provide identification of a route or route 
options for the proposed transmission line.  The issuance of a certificate of public 
convenience and necessity establishes that, as of the date of issuance of the certificate, the 
decision by the person to erect or construct was prudent.  At the time of its issuance of a 
certificate of public convenience and necessity, the commission shall send to each 
municipality through which a proposed corridor or corridors for a transmission line 
extends a separate notice that the issuance of the certificate does not override, supersede 
or otherwise affect municipal authority to regulate the siting of the proposed transmission 
line. The commission may deny a certificate of public convenience and necessity for a 
transmission line upon a finding that the transmission line is reasonably likely to 
adversely affect any transmission and distribution utility or its customers. 
Sec. C-6.  35-A MRSA §3132, sub-§6-B is enacted to read: 
6-B.  Reasonable consideration of nontransmission alternatives.  If the 
commission determines that nontransmission alternatives can sufficiently address the 
transmission need under subsection 6 at lower total cost, but at a higher cost to ratepayers 
in this State than the proposed transmission line, the commission shall make reasonable 
efforts to achieve within 180 days an agreement among the states within the ISO-NE 
region to allocate the cost of the nontransmission alternatives among the ratepayers of the 
region using the allocation method used for transmission lines or a different allocation 
method that results in lower costs than the proposed transmission line to the ratepayers of 
this State. 
For the purposes of this section, "ISO-NE region" has the same meaning as in section 
1902, subsection 3. 
The subsection is repealed December 31, 2015. 
Sec. C-7.  35-A MRSA §3132, sub-§15 is enacted to read: 
15.  Advancement of nontransmission alternatives policies. The commission shall 
advocate in all relevant venues for the pursuit of least-cost solutions to bulk power system 
needs on a total cost basis and for all available resources, including nontransmission 
alternatives, to be treated comparably in transmission analysis, planning and access to 
funding. 
Sec. C-8.  35-A MRSA §3132-A is enacted to read: 
§3132-A.  Construction of transmission projects prohibited without approval of the 
commission 
A person may not construct any transmission project without approval from the 
commission.  For the purposes of this section, "transmission project" means any proposed 
transmission line and its associated infrastructure capable of operating at less than 69 
kilovolts and projected to cost in excess of $20,000,000. 
1.  Submission requirement.  A person that proposes to undertake in the State a 
transmission project must provide the commission with the following information: 
A.  Results of an investigation by an independent 3rd party, which may be the 
commission or a contractor selected by the commission, of nontransmission 
alternatives to construction of the proposed transmission project. The investigation 
must set forth the total projected costs of the transmission project as well as the total 
projected costs of the nontransmission alternatives over the effective life of the 
proposed transmission project; and 
B.  A description of the need for the proposed transmission project. 
2.  Approval; consideration of nontransmission alternatives.  In order for a 
transmission project to be approved, the commission must consider whether the identified 
need over the effective life of the proposed transmission project can be economically and 
reliably met using nontransmission alternatives at a lower total cost. During its review the 
commission shall give preference to nontransmission alternatives that are identified as 
able to address the identified need for the proposed transmission project at lower total 
cost to ratepayers. Of the identified nontransmission alternatives, the commission shall 
give preference to the lowest-cost nontransmission alternatives. When the costs to 
ratepayers of the identified nontransmission alternatives are reasonably equal, the 
commission shall give preference to the alternatives that produce the lowest amount of 
local air emissions, including greenhouse gas emissions. 
3.  Exception.   A transmission project that is constructed, owned and operated by a 
generator of electricity solely for the purpose of electrically and physically 
interconnecting the generator to the transmission system of a transmission and 
distribution utility is not subject to this section. 
PART D 
Sec. D-1.  38 MRSA §579, first ¶, as amended by PL 2007, c. 608, §3, is further 
amended to read: 
The department may participate in the regional greenhouse gas initiative as described 
in the climate action plan required in section 577. The commissioner or the 
commissioner's designee and the members of the Public Utilities Commission are 
authorized to act as representatives for the State in the regional organization as defined in 
section 580-A, subsection 20, may contract with organizations and entities when such 
arrangements are necessary to efficiently carry out the purposes of this section and may 
coordinate the State's efforts with other states and jurisdictions participating in that 
initiative, with respect to: 
Sec. D-2.  38 MRSA §580-A, sub-§6, as enacted by PL 2007, c. 317, §17, is 
amended to read: 
6.  Carbon dioxide emissions offset project.  "Carbon dioxide emissions offset 
project" means a project that reduces or avoids loading of carbon dioxide and other 
greenhouse gases in the atmosphere and is demonstrated to qualify as real, additional, 
verifiable, enforceable and permanent as those terms are defined in rules adopted by the 
department.  "Carbon dioxide emissions offset project" includes, but is not limited to, 
landfill and agricultural methane capture and destruction, reduction in emissions of sulfur 
hexafluoride, sequestration of carbon due to afforestation forestry practices and reduction 
or avoidance of carbon dioxide emissions from natural gas, oil or propane end-use 
combustion due to end-use energy efficiency and other categories established by the 
department by rule. 
Sec. D-3.  38 MRSA §580-A, sub-§17-A is enacted to read: 
17-A.  Model rule.  "Model rule" means the model rule, as amended, referenced in 
the memorandum of understanding. 
Sec. D-4.  38 MRSA §580-B, sub-§3, as enacted by PL 2007, c. 317, §17, is 
amended to read: 
3.  Base annual budget.  The Until January 1, 2014, the base annual carbon dioxide 
emissions budget is established at 5,948,902 tons of carbon dioxide.  Beginning with the 
year 2015, the annual carbon dioxide emissions budget must decline by 148,722 tons per 
year until 2018 so that the annual carbon dioxide emissions budget for 2018 is 10% 
below the base annual carbon dioxide emissions budget. For the year 2014, the base 
annual carbon dioxide emissions budget is established at 3,277,250 tons of carbon 
dioxide. Beginning with the year 2015, the annual carbon dioxide emissions budget must 
decline by 2.5% each year through the year 2020. 
Sec. D-5.  38 MRSA §580-B, sub-§3-A is enacted to read: 
3-A.  Interim adjustments for banked allowances.  The 2014 base annual carbon 
dioxide emissions budget of 3,277,250 tons of carbon dioxide and base annual budgets 
for 2015 to 2020 must be reduced by an amount equivalent to the quantity of banked 
allowances in excess of the quantity of allowances required for compliance at the end of 
2013.  The State's interim adjustments for banked allowances must be made in proportion 
to the State's share of the total annual carbon dioxide emissions budget for all states 
participating in the regional greenhouse gas initiative. 
Sec. D-6.  38 MRSA §580-B, sub-§4, as enacted by PL 2007, c. 317, §17, is 
amended to read: 
4.  Rules implementing program.  The department shall adopt rules to implement 
the program.  The rules must contain Rules must be consistent with the model rule. The 
rules must include, but are not limited to: 
A.  Provisions for the establishment of a system for the annual assignment, sale and 
distribution of carbon dioxide emissions allowances consistent with the carbon 
dioxide emissions budget; 
B.  Provisions for the establishment of carbon dioxide budget unit compliance 
obligation  accounts; 
C.  Provisions for the establishment of carbon dioxide offset project allowance 
categories and requirements; 
D.  Provisions for the implementation of a licensing process for carbon dioxide 
budget units; 
E.  Provisions for the establishment of a carbon dioxide emissions and carbon dioxide 
allowance tracking program; and 
F.  Provisions to manage the carbon dioxide allowance auction developed in 
coordination with other states and jurisdictions in the regional greenhouse gas 
initiative and in a manner that is consistent with provisions adopted by those states 
and jurisdictions and, to the extent feasible, that: 
(1)  Ensure close monitoring of allowance transactions in a manner that guards 
against collusion and market manipulation; 
(2)  Ensure ongoing authentic price discovery and minimize price volatility; 
(3)  Facilitate open participation for bidding to all individuals or entities that meet 
the financial requirements jointly adopted by the participating states; 
(4)  Minimize administration and transaction costs and provide for an open and 
transparent user-friendly system; 
(5)  Provide that ongoing monitoring of market activity is undertaken by entities 
that have complete financial independence from any market participant; 
(6)  For purposes of civil and criminal enforcement authority under section 349, 
establish a contract term at the time an allowance is purchased at the regional 
auction for violations of market rules jointly adopted by the participating states 
and jurisdictions or through another method of ensuring state jurisdiction; and 
(7)  Guarantee that the Attorney General, the Public Utilities Commission and the 
commissioner have access to all auction information and information concerning 
allowance trading activity, including reports provided to the regional organization 
by a market monitor. 
Rules adopted pursuant to this subsection are routine technical rules as defined in Title 5, 
chapter 375, subchapter 2-A. 
Sec. D-7.  38 MRSA §580-B, sub-§10, as repealed and replaced by PL 2009, c. 
652, Pt. A, §61, is amended to read: 
10.  Annual report.  The department, the Public Utilities Commission and the 
trustees of the Efficiency Maine Trust established pursuant to Title 35-A, section 10103 
shall submit a joint report to the joint standing committees of the Legislature having 
jurisdiction over natural resources matters and utilities and energy matters by March 15, 
2009 and each year thereafter 15th annually.  The report must assess and address: 
A.  The reductions of greenhouse gas emissions from carbon dioxide budget units, 
conservation programs funded by the Regional Greenhouse Gas Initiative Trust Fund 
pursuant to Title 35-A, section 10109 and carbon dioxide emissions offset projects; 
B.  The improvements in overall carbon dioxide emissions and energy efficiency 
from sources that emit greenhouse gases including electrical generation and fossil 
fuel fired units; 
C.  The maximization of savings through systemic energy improvements statewide; 
D.  Research and support of new carbon dioxide offset allowance categories for 
development in the State; 
E.  Management and cost-effectiveness of the State's energy conservation and carbon 
reduction programs and efforts funded by the Regional Greenhouse Gas Initiative 
Trust Fund, established pursuant to Title 35-A, section 10109;  
F.  The extent to which funds from the Regional Greenhouse Gas Initiative Trust 
Fund, established pursuant to Title 35-A, section 10109, serve customers from all 
classes of the State's transmission and distribution utilities; and 
G.  The revenues and expenditures of the Regional Greenhouse Gas Initiative Trust 
Fund, established pursuant to Title 35-A, section 10109. 
The department, the Public Utilities Commission and the trustees of the Efficiency Maine 
Trust may include in the report any proposed changes to the program established under 
this chapter. 
The joint standing committee of the Legislature having jurisdiction over natural resources 
matters may submit legislation relating to areas within the committee's jurisdiction in 
connection with the program.  The joint standing committee of the Legislature having 
jurisdiction over utilities and energy matters may submit legislation relating to areas 
within the committee's jurisdiction in connection with the program. 
Sec. D-8.  Fuel switching offset category. The Department of Environmental 
Protection and the Public Utilities Commission shall work together to develop and 
promote for recognition by the other states participating in the regional greenhouse gas 
initiative a modification of the existing end-use energy efficiency offset category in the 
Regional Greenhouse Gas Initiative Act of 2007 to provide incentives for industrial and 
residential consumers to switch from the use of oil and coal as fuel to fuels with lower 
greenhouse gas emissions. In developing the modification to the existing offset category, 
the department shall work toward including the following factors: 
1.  Eligibility of fuel switching to alternative fuels such as natural gas, biomass or 
other renewable fuels; 
2.  Calculation of the offset amounts on the basis of the net reduction in carbon 
dioxide equivalents from the prior fuel used;  
3.  Offsets for greenhouse gas emission reductions that are real, additional, verifiable, 
enforceable and permanent; and 
4.  Allowing for the transfer of offset credits to a 3rd party to provide financial 
consideration to enable the fuel switching to occur. 
The department and the commission shall include a progress report on the 
development of this offset category as part of the annual report under the Maine Revised 
Statutes, Title 38, section 580-B, subsection 10. 
PART E 
Sec. E-1.  35-A MRSA §2523 is enacted to read: 
§2523.  Street lights; use of poles 
This section governs street lights that are attached to utility poles in the public way. 
1.  Ownership and maintenance options.  On or after October 1, 2014, a 
transmission and distribution utility shall provide the following options to municipalities 
for street and area lighting provided by light fixtures attached to poles owned by the 
transmission and distribution utility or on shared-use poles in the electrical space under 
the contractual management of the transmission and distribution utility located in the 
public way: 
A.  The transmission and distribution utility provides all of the components of the 
street lighting system, including installation on the utility poles and maintenance, and 
provides electricity delivery to the street lighting system from a power vendor 
selected by the municipality. The transmission and distribution utility shall apply a 
monthly charge for these services as approved by the commission that reflects the 
total cost to provide street lighting equipment for each light and a separate charge for 
power delivery consistent with subsection 3; 
B.  The transmission and distribution utility installs all of the components of the street 
lighting hardware as selected, purchased and owned by the municipality on utility 
poles owned by the transmission and distribution utility or in the electrical space 
under contractual management of the transmission and distribution utility on shared-
use poles and connects the light to the power source on the pole. The transmission 
and distribution utility may apply a one-time charge per light fixture for installation 
as established by the commission. 
Any repairs made by the transmission and distribution utility to the mounting 
hardware or the power supply wire connection following installation must be billed at 
a rate established by the commission.  Maintenance of all components of the light 
fixture is the responsibility of the municipality or its contractor.  Any person 
performing maintenance work on behalf of the municipality pursuant to this provision 
must be qualified pursuant to applicable federal or state standards or any standards 
established by the commission for such work and must have liability insurance in an 
amount and with terms determined by the commission.  Light locations, the street 
lighting hardware installed and delivery charges are governed by subsections 2 and 3; 
and 
C.  The transmission and distribution utility connects to the power lines a light fixture 
either owned by or owned and installed by the municipality or its contractor on a pole 
owned by the transmission and distribution utility or on a shared-use pole in the 
electrical space under the contractual management of the transmission and 
distribution utility.  Light locations, the street lighting hardware installed and delivery 
charges are governed by subsections 2 and 3.  Maintenance of the light fixture and 
mounting hardware is the responsibility of the municipality or its contractor.  Any 
person installing or working on municipally owned street lighting equipment 
pursuant to this paragraph on behalf of the municipality must be qualified pursuant to 
applicable federal and state standards or any standards established by the commission 
for such work and must have liability insurance in an amount and with terms 
determined by the commission.  The transmission and distribution utility may apply a 
one-time power connection charge per light fixture as established by the commission. 
2.  Lighting location and installation.  For municipally owned street lighting 
hardware located on poles owned by the transmission and distribution utility or in the 
electrical space under the contractual management of the transmission and distribution 
utility on shared-use poles in the public way, the location on the pole and the street 
lighting hardware installed, as well as any associated charges, are governed by the 
following provisions. 
A.  The commission shall establish criteria, based on standard utility industry 
practice, for determining possible locations on the utility pole for the street lighting 
hardware, determining any changes that may be needed, including, but not limited to, 
relocating equipment already on the pole, installing a taller pole or bracing an 
existing pole, as well as determining any one-time fees the transmission and 
distribution utility may charge the municipality for making the determinations and 
undertaking the work necessitated by the determinations.  The criteria must also 
specify the conditions under which a request from a municipality to locate a light 
fixture on a pole may reasonably be denied by the transmission and distribution 
utility. 
B.  The commission shall establish basic criteria, consistent with standard utility 
industry practice, for municipally owned street lighting hardware installed on utility 
poles that address any reasonable safety and compatibility issues with other 
equipment on or uses of the pole.  The criteria must provide a basis for determining 
when no additional assessment work, and related fees pursuant to paragraph A, would 
be warranted for a replacement light fixture because the new light fixture places 
comparable or lower demands on the utility pole and related utility equipment than 
the light fixture being replaced. 
3.  Delivery rates and associated charges.  The commission shall establish through 
appropriate proceedings the charges for the transmission and distribution utility to deliver 
electricity to the municipal street lighting systems as provided in subsection 1.  For 
municipal street lighting system options described in subsection 1, paragraphs B and C, 
the commission shall determine what, if any, ongoing fees beyond the power-only 
delivery charge may be assessed, including a pole attachment fee.  In making this 
determination, the commission shall weigh, among other factors, the municipal interest to 
serve the general public and the location of the poles in municipal rights-of-way. 
4.  Transfer of ownership.  A transmission and distribution utility shall allow a 
municipality to transfer utility-owned street and area lighting for which the municipality 
is billed to either form of municipal ownership in subsection 1, paragraphs B and C in a 
time frame and under terms established by the commission.  The commission shall also 
determine a fair and equitable cost for all aspects of the transfer and establish guidelines 
to best enable the contiguous ownership of lighting fixtures. 
PART F 
Sec. F-1.  35-A MRSA §101, as amended by PL 2011, c. 623, Pt. D, §2, is further 
amended to read: 
§101.  Statement of purpose 
The purpose of this Title is to ensure that there is a regulatory system for public 
utilities in the State and for other entities subject to this Title that is consistent with the 
public interest and with other requirements of law and to provide for reasonable licensing 
requirements for competitive electricity providers.  The basic purpose of this regulatory 
system as it applies to public utilities subject to service regulation under this Title is to 
ensure safe, reasonable and adequate service, to assist in minimizing the cost of energy 
available to the State’s consumers and to ensure that the rates of public utilities subject to 
rate regulation are just and reasonable to customers and public utilities. 
Sec. F-2.  35-A MRSA §3152, sub-§1, ¶A, as amended by PL 1999, c. 398, Pt. 
A, §57 and affected by §§104 and 105, is further amended to read: 
A.  Require the commission to relate transmission and distribution rates more closely 
to the costs of providing transmission and distribution service; and 
Sec. F-3.  35-A MRSA §3152, sub-§1, ¶C, as amended by PL 1999, c. 398, Pt. 
A, §57 and affected by §§104 and 105, is further amended to read: 
C.  Require the commission to consider the ability of low-income residential 
customers to pay in full for electric services as transmission and distribution rates are 
redesigned consistent with these policies.; and 
Sec. F-4.  35-A MRSA §3152, sub-§1, ¶D is enacted to read: 
D.  Require the commission to set rates to the extent practicable to achieve economic 
efficiency. 
Sec. F-5.  35-A MRSA §3153-A, sub-§4 is enacted to read: 
4.  Economic efficiency.  In designing rates for transmission and distribution utilities, 
the commission shall set rates to the extent practicable to achieve economic efficiency. 
PART G 
Sec. G-1.  PL 2011, c. 637, §11, sub-§2, ¶¶A, D and E are amended to read: 
A. May provide efficient electric heat pumps or electric thermal storage units to up to 
residential or small business customers within its service territory.  The number 
of efficient electric heat pumps provided to customers may exceed 500 if proposed by 
the utility and approved by the Public Utilities Commission; 
D. May offer rebates incentives to participating customers to be applied to the total 
installation cost of the efficient electric heat pumps or electric thermal storage units; 
and 
E. May With respect to electric thermal storage units, may enroll customers in the 
pilot program only until December 31, 2013 and with respect to efficient electric heat 
pumps, may enroll customers in the pilot program until December 31, 2014, except 
that the deadline may be extended  if proposed by the utility and approved by the 
Public Utilities Commission. 
Sec. G-2.  PL 2011, c. 637, §11, sub-§2 is amended by adding at the end a new 
blocked paragraph to read: 
Nothing in this subsection is intended to limit the authority of the commission to establish 
special rates for customers purchasing electricity through the pilot program. Those rates 
may include the recovery of costs associated with incentives or loans authorized under 
the pilot program.  Any recovery of those costs must be through customers participating 
in the program and may not be passed through to customers not participating in the pilot 
program. 
PART H 
Sec. H-1.  PL 2009, c. 615, Pt. A, §6, 3rd ¶ from the end is amended to read: 
The commission may not approve any long-term contract under this section that 
would result in an increase in electric rates in any customer class that is greater than the 
amount of the assessment charged under Title 35-A, section 10110, subsection 4 at the 
time that the contract is entered $1.45 per megawatt hour. 
Sec. H-2.  PL 2009, c. 615, Pt. A, §6 is amended by adding at the end a new 
paragraph to read: 
If a supplier under a deep-water offshore wind energy pilot project elects not to go 
forward or does not proceed to construction under the terms of a contract or other terms 
approved by the commission by order for any reason, including that the supplier does not 
receive necessary federal funding or financing, the commission may consider additional 
proposals for a deep-water offshore energy pilot project that can be funded within 
funding limitations under this section.  To consider additional proposals, the commission 
shall conduct a 2nd round of solicitation of competitive proposals.  The commission may 
approve additional projects that are contingent on previously approved projects not 
proceeding to construction within the approved time frames or deadlines.  The University 
of Maine's deep-water offshore wind energy pilot project must be considered a deep-
water offshore wind energy pilot project under this section.   The commission shall make 
all reasonable efforts to complete its review and make decisions on additional proposals 
under this section by December 31, 2013. 
PART I 
Sec. I-1.  Appropriations and allocations.  The following appropriations and 
allocations are made. 
PUBLIC UTILITIES COMMISSION 
Public Utilities - Administrative Division 0184 
Initiative: Allocates the projected revenue from the transfers from the Regional 
Greenhouse Gas Initiative Trust Fund of the Efficiency Maine Trust to be distributed to 
utility ratepayers at the direction of the Public Utilities Commission to provide the 
maximum benefit to the Maine economy. 
SUMMARY 
This bill is reported by the Joint Standing Committee on Energy, Utilities and 
Technology pursuant to Joint Order 2013, H.P. 1125. 
The committee has developed this legislation to reduce energy costs, promote electric 
efficiency and electric grid reliability, protect the environment and improve security of 
the state and local economies, helping individuals and businesses meet their energy needs 
at the lowest cost. 
The purposes of this bill are to: 
1.  Reduce the cost of energy to residents of the State; 
2.  Maximize the use of cost-effective weatherization and energy efficiency measures, 
including improvements to energy-using systems, such as heating and cooling systems, 
and upgrades to energy efficient systems that rely on affordable energy resources; 
3.  Reduce economic insecurity from the inefficient use of expensive fossil fuels; 
4.  Increase new jobs and support businesses that deliver affordable energy and 
energy efficiency products and services; 
OTHER SPECIAL REVENUE FUNDS 
2013-14
2014-15
All Other 
$1,500,000
$1,500,000
OTHER SPECIAL REVENUE FUNDS TOTAL 
$1,500,000
$1,500,000
5.  Enhance heating benefits for households of all income levels through 
implementation of cost-effective efficiency programs, including weatherization programs 
and affordable heating systems that will reduce energy costs and reduce the need for 
future fuel assistance; 
6.  Simplify and enhance consumer access to technical assistance and financial 
incentives relating to energy efficiency and the use of alternative energy resources by 
merging or coordinating dispersed programs under a single administrative unit possessing 
independent management and expertise; 
7.  Use cost-effective energy and energy efficiency investments to reduce greenhouse 
gas emissions; 
8.  Facilitate the reduction in consumer reliance on oil for heating, manufacturing and 
transportation purposes; 
9.  Facilitate the transition of consumers to reliance on less expensive and less 
polluting energy sources; 
10.  Ensure adequate electricity and natural gas supply in New England, substantially 
eliminate the so-called "basis differential" for natural gas and protect the reliability of the 
regional electric grid; and 
11.  Reduce the price of electricity and of natural gas for consumers in this State. 
PART A 
This Part changes the structure of the assessment imposed by the Public Utilities 
Commission for electric efficiency and conservation programs. The bill repeals the base 
rate of .145¢ per kilowatt hour effective July 1, 2015, and instead requires the 
commission to ensure that transmission and distribution utilities have sufficient revenue 
from rates to provide for the procurement for the benefit of ratepayers of all energy 
efficiency resources found by the commission to be cost-effective, reliable and achievable 
and allows the commission to impose any order on transmission and distribution utilities 
necessary to achieve the energy efficiency savings. 
This Part decreases the percentage of revenue generated from the use of energy 
efficiency corridors owned by the Department of Transportation that is deposited into the 
Secondary Road Program Fund from 90% to 20% and increases the percentage of 
revenue deposited in the energy infrastructure benefits fund from 10% to 80%. 
This Part directs that funds received by transmission and distribution utilities 
pursuant to Maine Yankee litigation be paid 55% to the Efficiency Maine Trust and 45% 
to ratepayers pursuant to an order of the commission allocating the funds for the 
maximum benefit to the Maine economy. 
This Part allocates 35% of Regional Greenhouse Gas Initiative proceeds to residential 
fuel switching, as approved by the Efficiency Maine Trust, 50% to electric savings and 
thermal savings for commercial and industrial facilities and 15% to the Public Utilities 
Commission to be disbursed to transmission and distribution utilities for the maximum 
benefit to the State’s economy. 
This Part approves a pending long-term contract for energy efficiency resources as 
recommended by the Public Utilities Commission.  
PART B 
This Part gives the Public Utilities Commission the authority until December 31, 
2018 to execute an energy cost reduction contract to procure natural gas pipeline capacity 
for the purpose of increasing the flow of natural gas into New England by 2,000,000,000 
cubic feet per day. 
This Part establishes the standards for the Public Utilities Commission to execute an 
energy cost reduction contract. This Part requires consultation with the Office of the 
Public Advocate and the Governor’s Energy Office when the Public Utilities Commission 
hires a consultant to assist in developing the terms of an energy cost reduction contract. 
An energy cost reduction contract may not be executed without approval from the 
Governor. The cost of the contract may not exceed $75,000,000 annually.  The Public 
Utilities Commission may direct a transmission and distribution utility, a natural gas 
utility and a natural gas pipeline utility to assess ratepayers for the cost of an energy cost 
reduction contract and the cost of the administration of an energy cost reduction contract. 
This Part authorizes the Public Utilities Commission to establish and collect a 
volumetric fee for use of natural gas by Maine consumers for natural gas not provided to 
the consumers by a natural gas utility or natural gas pipeline utility. 
This Part establishes the Energy Cost Reduction Trust Fund, to be administered by 
the Public Utilities Commission, to receive the revenue from the resale of natural gas 
pipeline capacity and to direct those fund toward initiatives to reduce energy costs for 
ratepayers. 
This Part exempts energy cost reduction contracts and the resale of natural gas 
pipeline capacity from the competitive bid requirements of the State Purchasing Agent. 
This Part gives the Public Utilities Commission authority to investigate the exercise 
of market power by a gas utility, natural gas pipeline utility and any person who owns 
rights to natural gas pipeline capacity. 
This Part authorizes the Public Utilities Commission to adopt rules to implement the 
provisions of the Part. 
PART C 
This Part prohibits the Public Utilities Commission from issuing a certificate of 
public convenience and necessity for the construction of a transmission line unless a 
description of the need for the proposed transmission line is provided, an analysis of 
nontransmission alternatives is conducted by an independent 3rd party selected by the 
Public Utilities Commission and the projected cost of the proposed transmission line is 
compared to the projected cost of feasible nontransmission alternatives based on total 
projected costs. Preference must be given to lower-cost alternatives with fewer 
greenhouse gas emissions. The Public Utilities Commission must make specific findings 
as to whether nontransmission alternatives can address the identified transmission need at 
a lower total cost than the proposed transmission line. This Part requires that, until 
December 31, 2015, when the commission determines that nontransmission alternatives 
can address the need at a lower total cost but represent a larger increased cost to 
ratepayers of the State than the proposed transmission line, the commission must make 
reasonable efforts to achieve an agreement among the states within the New England 
independent system operator region to allocate the cost of the nontransmission 
alternatives among the ratepayers of the region using the allocation method used for 
transmission lines or another allocation method that results in lower increased cost to 
ratepayers of the State. 
This Part also requires that lower-voltage projects that are capable of operating at less 
than 69 kilovolts and projected to cost in excess of $20,000,000 must be reviewed and 
approved by the Public Utilities Commission before construction of the transmission 
project and establishes the standards for approval. 
PART D 
This Part amends the Regional Greenhouse Gas Initiative Act of 2007 to provide 
consistency with regional targets, directs the Department of Environmental Protection 
and the Public Utilities Commission to work together to modify a current regional 
greenhouse gas initiative offset category to allow for fuel switching and further directs 
the Department of Environmental Protection and the Public Utilities Commission to 
promote this modification with other regional greenhouse gas initiative states. 
PART E 
This Part requires electricity transmission and distribution utilities to provide new 
options for municipal street lighting programs and provides for how a municipality may 
be charged for the utility infrastructure services provided, how the location of street and 
area lighting will be provided, at what rates or by what methods the electricity delivery 
charges may be assessed and how a municipality may transition from one option to 
another during the course of any year. 
PART F 
This Part directs the Public Utilities Commission to consider economic efficiency 
when designing rates. 
PART G 
This Part authorizes the Public Utilities Commission to extend the number of 
customers who may participate in the pilot program for efficient electric heat pumps and 
extend the length of the pilot period, allows more flexibility in the manner in which 
incentives are provided to customers and clarifies that nothing in the legislation related to 
the pilot program is intended to limit any currently existing authority of the Public 
Utilities Commission to establish special rates with respect to customers participating in 
the pilot program, as long as the costs of the pilot program are recovered only from 
customers participating in the program. 
PART H 
This Part authorizes the Public Utilities Commission to issue a 2nd solicitation for 
deep-water offshore wind projects under the provisions of Public Law 2009, chapter 615 
if the original recipient of the contract does not move forward in development for any 
reason. 
FISCAL NOTE REQUIRED 
(See attached) 
Approved: 06/04/13
LD 1559
LR 2160(01)
FY 2013-14
FY 2014-15
Projections 
FY 2015-16
Projections 
FY 2016-17
Appropriations/Allocations
Other Special Revenue Funds
$1,500,000
$1,500,000
$1,500,000
$0
Revenue
Other Special Revenue Funds
$1,500,000
$1,500,000
$1,500,000
$0
Fiscal Detail and Notes
Fiscal Note
Part A also changes the assessment for electric conservation and efficiency programs from 0.145¢ per kilowatt hour to 
an amount built into utility rates that does not exceed 4% of total retail electricity transmission and distribution sales 
in the State to fund these programs effective July 1, 2015.  The potential increase in the amount of the future 
assessments cannot be estimated at this time.  After the transition of the assessment, if the Public Utilities Commission 
orders the assessment to accrue directly to the Efficiency Maine Trust, the Other Special Revenue Funds allocations 
required to make the transfer of revenue collected by the Pubic Utilities Commission to the Efficiency Maine Trust 
will be significantly reduced.  Part I includes the adjustments to Other Special Revenue Funds allocations.
Part A reduces the Department of Transportation's share of revenue from energy infrastructure corridors from 90% to 
20% of the total and increases the Efficiency Maine Trust's share from 10% to 80%.  No funding for the Department 
of Transportation's Secondary Road Program Fund is currently budgeted or allocated related to this revenue, so no 
revenue or allocation adjustments are required.
Part A also reallocates the revenue received in the Regional Greenhouse Gas Initiative Trust Fund to the Public 
Utilities Commission in fiscal years 2013-14, 2014-15 and 2015-16.  The Efficiency Maine Trust is directed to spend 
35% of these revenues for residential heating solutions.  It also requires that 15% of these revenues be transferred to 
the Public Utilities Commission.   Based on projected total receipts of approximately $10 million annually during this 
period, the commission will require additional allocations of $1,500,000 each year to authorize the expenditures of 
these funds, which must be disbursed by transmission and distribution utilities to ratepayers in a manner that provides 
maximum benefit to the Maine economy.
Fiscal Note Required: Yes
An Act To Reduce Energy Costs, Increase Energy Efficiency, Promote Electric System Reliability and 
Protect the Environment
Fiscal Note for Original Bill
Rep. Hobbins, Rep. Fredette, Sen. Cleveland
Committee: Energy, Utilities and Technology
LR2160(01) - Fiscal Note - Page 1 of 2
The Office of the Public Advocate and the Governor's Energy Office can absorb the future additional costs associated 
with consultation in the process of the Public Utilities Commission execution of an energy cost reduction contract in 
Part B.  These costs can be absorbed within the office's existing budgeted resources.
The Department of Environment Protection will incur additional costs to develop a regional greenhouse gas initiative 
offset category for fuel switching.  The department has sufficient existing funding to implement this requirement 
without additional resources.
The Public Utilities Commission will incur some additional administrative costs associated with the new requirements 
and reporting in several review and approval processes in this bill.  The commission can absorb these additional costs 
within existing budgeted resources.
Part A also directs transmission and distribution utilities that receive settlement funds from litigation related to the 
decommissioning costs of the Maine Yankee Atomic Power Company to pay 55% of those funds to the Efficiency 
Maine Trust in fiscal years 2013-14 and 2014-15, estimated to be approximately $9,350,000 in fiscal year 2013-14 
and $7,150,000 in fiscal year 2014-15, to be used for electric efficiency and conservation programs.  In fiscal year 
2015-16 a fixed amount of $2,000,000 of these settlement funds must be paid to the trust for these same programs.  
Part B establishes an Energy Cost Reduction Trust Fund at the Public Utilities Commission.  The amount of revenue 
that may accrue to this Other Special Revenue Funds account can not be estimated at this time.   Amounts in this trust 
fund can be used for the costs of administering an energy cost reduction contract or for utilities to reduce energy costs 
of electricity and natural gas ratepayers. 
LR2160(01) - Fiscal Note - Page 2 of 2