This is an informal working document that was prepared under time constraints; it is not for publication and is subject

to change or correction.

LCO 8923

§§ 1 & 2 — C&LM BONDING AND PERFORMANCE INCENTIVES

• Authorizes up to $150 million annually from FYs 26-30 in new general obligation bonds for DEEP
to support the C&LM plan
• Allows PURA, upon DEEP’s request, to require the EDCs and gas companies to adjust a C&LM
conservation adjustment mechanism (CAM) based on general obligation bond allocations for
that purpose, so long as the bond funding is available in a way that ensures C&LM program
continuity and stability
• Allows gas companies to exceed the 4.6 cents per hundred cubic feet CAM to fund the net costs
of any agreement resulting from DEEP’s procurement of demand response resources (§ 48)
• Requires DEEP to transfer bond proceeds in recommended amounts when PURA implements
DEEP’s recommendation that companies collect a conservation adjustment mechanism that is
less than the amount authorized in statute (i.e., 6 mills)
• Bonds are subject to standard issuance procedures and have a maximum term of 20 years
• Requires the C&LM plan to include proposed performance management incentives for EDCs
and gas companies
o Allows the DEEP commissioner to approve, modify, or reject these incentives based on
impacts to the plan’s cost effectiveness and the likelihood of sufficiently motivating high
quality service
• EFFECTIVE DATE: October 1, 2025, except the bonding provision goes into effect July 1, 2025

§ 3 — BOND AUTHORIZATION FOR HARDSHIP CUSTOMER COSTS IN SBC

• Authorizes up to $300 million in general obligation bonds for OPM to pay for reducing the cost
of hardship protection measures and other hardship protections under the Systems Benefits
Charge
• Bonds are subject to standard issuance procedures and have a maximum term of 20 years
• EFFECTIVE DATE: July 1, 2025

§ 4 — BOND AUTHORIZATION FOR EV CHARGING PROGRAM

• Authorizes up to $80 million in general obligation bonds for OPM to fund the EV charging
Program (light-duty EV charging program or medium-duty to heavy-duty EV charging program
established in a PURA proceeding)
• Bonds are subject to standard issuance procedures and have a maximum term of 20 years
• EFFECTIVE DATE: July 1, 2025

§§ 5 & 6 — MEDICAL PROTECTION

• Shortens the winter shutoff moratorium by one month, ending it April rather than May (starts
in November)
• Applies shutoff protections to hardship customers who fail to pay their entire outstanding
balance, rather than those who lack the financial resource to pay their account

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This is an informal working document that was prepared under time constraints; it is not for publication and is subject
to change or correction.

• Renames “hardship case” as “financial hardship case” and removes provisions in current law
that designate seriously ill customers or those with seriously ill household members as hardship
customers
• Instead requires utilities to apply a medical protection designation to customer accounts for up
to six months every three calendar years
o To qualify, a physician, PA, or APRN must submit a certification (presumably to the
utility) that a customer or household member suffers from a medical condition that
requires the customer to maintain utility service
• The EDC or gas company must offer a reasonable amortization agreement under existing law’s
requirements for eligible financial hardship customers with accounts that maintain an eligible
arrearage
• If the customer is not a financial hardship customer or does not qualify for the amortization
agreements described above, the EDC or gas company must offer an amortization agreement of
up to 36 months or longer under PURA regulations
• Prohibits service termination (or denial or refusal to reinstate) during the six months a medical
protection designation is in effect
• Removes provisions broadly prohibiting utilities from terminating, denying, or refusing to
reinstate service for customers who lack financial resources to pay their account if doing so
would create a life-threatening situation for the customer or household member
• Removes a provision that generally prohibits utilities from terminating service for nonpayment
when a resident is seriously ill so long as the customer agrees to amortize the unpaid account
balance over a reasonable period of time and keep current on the account as charges accrue in
subsequent periods
• Instead requires utilities terminating service for financial hardship cases when doing so would
create a life-threatening situation, as certified to the utility by a physician, PA or APRN, to
provide (1) notice between 10 and 3 days before terminating service and (2) an opportunity to
enter into a payment arrangement to avoid service disconnection
o Certification must be provided to the utility no more than three years before the
disconnection
• For these customers (financial hardship customers with the above certification from a
physician, PA, or APRN) who have already been disconnected, requires utilities to reinstate
service if the customer enters into a payment arrangement and provide any required initial
payment, down payment, fee, and security deposit, as approved by PURA
• Adds the following statement to the utilities’ notice of termination for residential customers:
o “MEDICAL EMERGENCY: If you are a residential customer and believe that a life-
threatening situation exists in your home or would exist if your service were to be
disconnected, you may be protected from disconnection. Please contact us at (insert
telephone number of the utility) for more information.”
• Requires PURA to post notice by July 1, 2026, of its intent to adopt regulations on these
provisions
• Amends the notice telephone companies and telecommunications providers must send to
customers before submitting information to a credit rating agency about a customer’s

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This is an informal working document that was prepared under time constraints; it is not for publication and is subject
to change or correction.

nonpayment for service to state that the company supplies payment information to debt
collection agencies
• EFFECTIVE DATE: October 1, 2025

§ 7 — PURA STUDY OF RENEWABLE TARIFFS

• Adds to existing review in progress for next year to include:
o A framework to encourage the aggregation of distributed energy resources that can
respond and provide grid and retail market services
o Consideration of different compensation structures to encourage deployment in areas
of grid under-utilization
• Under existing law, PURA must submit this study to the Energy and Technology Committee by
January 15, 2026
• EFFECTIVE DATE: Upon passage

§§ 8 & 9 — LOW-INCOME DISCOUNT RATE: COST CONTAINMENT & STUDY

• Sets cost-containment requirements for any low-income rates PURA implements in a rate case
or other proceeding started on or after October 1, 2025, or in pending rate case in which PURA
has not issued a final decision before November 1, 2025
• Requires these rates to include:
o Monthly usage caps (in kilowatt hours for EDC customers, centum cubic feet for gas
customers, gallons for water customers)
o A budgetary target triggering a PURA review if an EDC, gas company, or water
company’s total cost to fund the low-income rate exceeds a certain percentage of
annual billed total revenues
o A recertification process to confirm income eligibility for the program and appropriate
tier placement at least once every 12 months
• By November 15, 2029, requires PURA to submit a report to the Energy and Technology
Committee on the implementation of low-income rates from January 1, 2024, to December 31,
2028, including the effectiveness of the cost containment measures (e.g., reducing
uncollectibles and encouraging bill payments)
• EFFECTIVE DATE: July 1, 2025, except the study is effective upon passage

§ 10 — RENEWABLE ENERGY TARIFFS

• Makes Class I low-emissions projects (e.g., fuel cells) ineligible for NRES and SCEF
• Requires PURA to set a nonbypassable charge for RRES customers, starting January 1, 2026,
that is at least equal to the prior year’s FMCC
• Specifies that RRES projects must emit no pollutants
• Makes conforming changes to eliminate 10 MW cap for low-emissions NRES, starting for
procurements and tariff years starting January 1, 2025
• EFFECTIVE DATE: October 1, 2025

§§ 11-18 — SECURITIZATION OF “FINANCED UTILITY SERVICES”

• Creates a process to securitize financed utility services through rate reduction bonds

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This is an informal working document that was prepared under time constraints; it is not for publication and is subject
to change or correction.

• “financed utility services” are costs determined by PURA that:

o Have been prudently and efficiency incurred between January 1, 2018, through January
1, 2025 by an EDC to prepare for and restore power to customers following storms
o Have been or reasonably expected to be prudently and efficiently incurred after January
1, 2025, by an EDC for the accelerated initial procurement, installation, and operational
deployment of advanced metering infrastructure (AMI) to replace existing traditional
noninterval metering infrastructure used by its customers, including reasonable fees,
expenses, and transaction costs related to rate reduction bonds
o Include unrecovered balance of legacy infrastructure, including stranded costs, for
infrastructure replaced in connection with AMI deployment
o Include any reasonable fees, expenses, and transaction costs incurred in connection
with issuing, servicing, retiring, or refinancing rate reduction bonds to finance these
costs
• Allows PURA to determine whether issuing a rate reduction bond is in ratepayers’ best interest
o PURA may do so in its sole discretion, in response to a petition or on its own motion
• The finance authority is the state, acting through the State Treasurer, which can issue rate
reduction bonds or acquire transition property (CTA, see below) or authorize a special purpose
trust or other entity to do so
o Bill allows PURA to also authorize entities to issue rate reduction bonds under a
financing order
• Requires the financing entity to issue rate reduction bonds upon PURA’s issuing of a finance
order that specifies an appropriate amount
• Caps the aggregate value of rate reduction bonds at $2.2 billion
• Requires cost of rate reduction bonds to be recovered through the Competitive Transition
Assessment (CTA – existing component of ratepayer bills that is adjusted annually through the
RAM process)
• Requires PURA to adjust the CTA upon issuance of any rate reduction bonds to allow recovery
of bond costs through the CTA
• Requires excess bond costs to be returned to ratepayers with interest if bond proceeds used to
purchase transition property for rate reduction bonds issued for the deployment of AMI is
subsequently determined by PURA to exceed the amount prudently and efficiently incurred for
AMI deployment
o Excess must be returned in a manner PURA determines (e.g., by decreasing other
nonbypassable rates or through the revenue decoupling mechanism, but not through
the CTA)
• Requires net benefits of accumulated deferred income taxes for amount recovered through
rate reduction bonds for financed utility services to be credited to EDC customers by reducing
the amount of bonds that would otherwise be issued by the net present value of the related tax
cash flows, using a discount rate equal to the bonds’ expected interest rate
• Allows EDCs to apply to PURA for a financing order for financed utility services that PURA
determines through a separate proceeding to be appropriate for cost recovery under existing
laws on ratesetting
o PURA must respond to the application within 120 days after receiving it

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This is an informal working document that was prepared under time constraints; it is not for publication and is subject
to change or correction.

• Extends deadlines associated with various steps in the securitization process (eliminating
obsolete deadlines for previous authorizations)
• Expands the bond-related costs the CTA must cover to include any credit enhancement or
premium on the bonds
• CTA must be charged to customers until the rate reduction bonds are paid in full
o Bill specifies this include all principal, interest, premiums, costs and arrearages on the
bonds
• Requires transition property (the CTA) to vest immediately upon its creation (generally, when
the financing order is issued) in the applicable EDC
• Prohibits EDCs from including transition property in rate base calculations
• Requires PURA to hold a hearing as a contested case to determine the portion of financed
utility services that may be funded through securitization and thereby constitute transition
property
• PURA must establish and revise the CTA in amount sufficient to pay principal, interest, and any
credit enhancement or premium on the bonds as they become due, related financing expenses,
and to pay financed utility services that are not funded with bond proceeds
• Requires CTA to be charged to ratepayers until the bond costs are paid in full, including
principal, interest, premium, costs, and arrearages on the bonds
• The state pledges with transition property holders and rate reduction bond holders that it will
not amend, reduce, impair or alter the CTA, transition property, financing orders, and rights
under them until obligations are fully met, but alteration is permitted if adequate provision is
made to protect these parties
• Financing orders and rate reduction bonds are not state debt or a liability of the state or any of
its subdivisions
• Specifies that expiration of previous authority to securitize has no effect on other financing
orders PURA issues
• (§ 18) adds to the factors PURA must consider when determining a reasonable rate of return in
a rate amendment proceeding to include whether the company has benefited from financing
orders described above
• EFFECTIVE DATE: July 1, 2025, except the provision adding to factors PURA must consider in a
rate case is effective October 1, 2025

§ 19 — PURA CHOOSING ENTITIES TO IMPLEMENT PROGRAMS

• Allows PURA to select any of the following entities to implement ratepayer-funded clean energy
or renewable energy programs established in PURA proceedings:
o Green Bank
o DEEP
o EDCs
o A third party PURA deems appropriate
o Any combination of entities listed above
• Existing law allows PURA to select these entities to implement NRES, RRES, SCEF, or the EV
charging program (CGS § 16-244dd)
• EFFECTIVE DATE: October 1, 2025

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This is an informal working document that was prepared under time constraints; it is not for publication and is subject
to change or correction.

§ 20 — DEEP STUDY ON PUBLIC BENEFITS CHARGE

• Requires DEEP, in coordination with PURA and OCC, to prepare a report on line items included
in the combined public benefits charge on electric bills
• Report must include an examination of the enabling authority for the imposition of each line
item, its purpose, and associated cost and benefits
• DEEP must submit the report to the Energy and Technology Committee by January 1, 2026
• EFFECTIVE DATE: Upon passage

§§ 21 & 22 — TIME-VARYING RATES

• Requires EDCs to apply to PURA by October 1, 2027, to implement time-varying rates for (1)
residential and (2) commercial and industrial customers
o “Time-varying rates” are electric utility rates for a class of customer designed to reflect
the EDC’s cost to provide electricity to the customer at different times and create a price
differential to incentivize targeted electric load growth and system efficiency, including
critical peak pricing (“critical peak” means a period when system costs are highest or
when the power grid is severely stressed and electric customers may pay higher prices
as a result of this stress)
o Requires time-varying rates proposals also propose to establish:
▪ the rates through an approved revenue recovery mechanism for transmission
and distribution rates
▪ a revenue reconciliation mechanism whereby revenue under- or over-collected
through time-varying rates is recovered or refunded through a billing
reconciliation adjustment
o Requires time-varying rates for transmission, distribution, and all other retail electric
rate components to:
▪ Provide for fixed rates across 24-hour cycles within each season
▪ Be based on projected seasonal demand
▪ Include on-peak rates
▪ Adequately incentivize the cost-effective shifting of load to off-peak periods by
applying an appropriate price differential between on-peak and off-peak time-of-
use rates
o Requires the design of the rates, including the price differential between on-peak and
off-peak time-varying rates, to be consistent with empirical research conducted by EDC
and other rate-design experts
o “on-peak” is a period likely to capture the regional ISO and distribution system peaks or
incentivize cost-effective load shifting to maximize grid efficiency, as PURA determines
o Requires any application for time-varying rates that includes a seasonal rate component
to also submit:
▪ Any proposal for differentiation of generation, transmission, and distribution
energy and demand rates (1) into summer and nonsummer periods and (2) into
winter and shoulder month periods, if cost differences between summer and

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This is an informal working document that was prepared under time constraints; it is not for publication and is subject
to change or correction.

nonsummer months are substantial, with consideration of projected customer

acceptance and use of these rates
▪ The appropriate phase-in period over which time electric customers may adjust
to seasonal rates without experiencing sudden, significant increases in electricity
prices
o Requires time-varying rates to be designed as default rates (the electric utility rate in
which a consumer is enrolled at the start of service if the customer does not specify a
preferred rate), with consideration for gradualism principles and customer acceptance
and establish exceptions as PURA deems appropriate for medically protected and
financial hardship customers
o Requires time-varying rate applications to:
▪ Propose a comprehensive customer education program
▪ Provide for a clearly defined opt-out process
▪ Give due consideration to interaction of time-varying rate design with existing
and foreseeable low-income rates and programs
• Requires PURA to initiate a docket to accept or modify EDC applications for time-varying rates
for residential and commercial EDC customers by October 1, 2027
• PURA may implement the rates after public notice and a hearing
o Requires PURA to evaluate whether a time varying rate is appropriate
▪ Rates are deemed appropriate if they are in the ratepayers’ best interests
▪ PURA must consider, among other things, if the benefits exceed costs, including
capital investments
o Prohibits PURA from approving time-varying rates unless
▪ They reasonably reflect the cost of service during their respective time-varying
periods
▪ The costs associated with implementation, impact on customers, and benefit to
the utility system justify implementing the time-varying rates
▪ The rates are expected to alter customer consumption patterns without undue
adverse effect on the customer
• EFFECTIVE DATE: July 1, 2025

§ 23 — CUSTOMER EDUCATION AND ENGAGEMENT PROGRAM

• Requires EDCs, in consultation with OCC and DEEP, to design a comprehensive customer
education and engagement program to inform customers of the benefits of time-varying rates
and encourage them to use these rates and any available technology that enables the
realization of customer cost savings on these time-varying rates
• Program designs must include:
o Approved methods for customer outreach, education, and engagement activities (e.g.,
strategies to maximize customer cost savings)
o Objective performance standards on program implementation
o Mandatory reporting requirements for EDCs on compliance with program requirements,
including submitting documentation and data as PURA requires

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to change or correction.

• Requires EDCs to submit a detailed proposal, or update a previously submitted proposal, in any
rate case started on or after July 1, 2025
o Requires EDCs to administer the program upon PURA’s approval
• EFFECTIVE DATE: October 1, 2025

§ 24 — EMERGENCY SERVICE RESTORATION PLANNING COMMITTEES

• Requires each company, provider, or utility required under existing law to submit a service
restoration plan to also establish an emergency service restoration planning committee to
prepare the plan
• Expands “emergency” definition to include wildfires
• At least half the planning committee’s members must be line and restoration crew members
employed at the company, provider, or utility
o Requires line and crew members to select committee members through a process they
determine, unless they belong to a collective bargaining unit, in which case the
bargaining unit selects the members
o Requires the company to appoint the remaining members
o Requires the committee to have two co-chairpersons, one elected by the line and
restoration crew members of the committee and one elected by the other committee
members
o Requires planning committee members to take minutes, make them available to
employees upon request, and submit them to PURA and DESPP on request
o A majority of committee members is a quorum and committee decisions are made by
majority vote of members present at a meeting
• Expands the required contents of a service restoration plan to include measures to protect the
health and safety of (1) line and restoration crews during an emergency and when restoring
service, including providing appropriate personal protective equipment and (2) household and
community members during an emergency and during service restoration
• Requires the service restoration plan to have a training and skills plan for line and restoration
workers, jointly developed by the company and the collective bargaining unit, if line and
restoration crew members belong to one
• EFFECTIVE DATE: October 1, 2025

§§ 25-26— LINEWORKERS AND EMERGENCIES

• Prohibits EDCs from requiring line and restoration crew members to work in unsafe conditions
to avoid making payments or issuing credits required under existing law after prolonged
outages (e.g., $250 payment for spoiled food and medication)
• Prohibits EDCs from disciplining, terminating, withholding wages from, or otherwise retaliating
against line and restoration crew members for failing to restore service within the 96-hour
period
• EFFECTIVE DATE: October 1, 2025

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This is an informal working document that was prepared under time constraints; it is not for publication and is subject
to change or correction.

§§ 27 - 28 — GRID-ENHANCING TECHNOLOGIES (GETS)

• Requires EDCs and incumbent transmission owners, when seeking to construct or materially
modify transmission lines, substations, or switchyards, to develop at least two project
alternatives
o A material modification is one that costs at least $5 million and excludes construction
activities related to emergency conditions that cause power disruptions or any other
unplanned loss of an essential transmission asset function that requires immediate
rectification
o An “advanced conductor” is any conductor material, design, or technology that:
▪ Improves the electrical performance of electrical conductors compared to
traditional aluminum-conductor, steel-reinforced cable and
▪ Optimizes attributes such as carrying capacity, thermal performance, weight,
sag, durability, corrosion resistance, and efficiency, using materials such as high-
conductivity alloys and conductor designs using trapezoidal wires
o One alternative must use any advanced conductor, unless the primary proposed project
incorporates advanced conductor technology
o The other alternative must use grid enhancing technologies (GETs) or nontransmission
alternative technology, applicable to the proposed construction or modification
▪ GETs means hardware or software that increases capacity or efficiency of
distribution or transmission systems (e.g., dynamic line rating, advanced power
flow control, topology optimization, and energy storage)
▪ Nontransmission alternatives are grid investments or projects that use
nontraditional transmission and distribution solutions (e.g., distributed
generation, energy storage, energy efficiency demand response and grid
software and controls) to defer or replace the need for specific equipment
upgrades (e.g., lines or transformers) by reducing electric load at the substation
or circuit level
o Companies must submit their project alternatives with their Siting Council application or
petition for the proposed construction or material modification, along with a detailed
explanation comparing the cost-effectiveness and appropriateness of the project
alternative to the project preferred by the company if it does not prefer either project
alternative
o Requires the council to give preference to project alternatives that propose to use any
advanced conductor, GETs, or nontransmission alternative that (1) is not less cost
effective than the company’s preferred project and (2) has similar environmental and
community impacts as the council determines
o Allows EDCs to seek a waiver from DEEP commissioner from the requirement to submit
project alternatives in cases where (1) using advanced conductors, GETs, or
nontransmission alternative technologies is impossible or impractical (2) the proposed
project is subject to a regional planning process that adequately considers implementing
these technologies, as DEEP determines, or (3) the project has been evaluated by DEEP
and OCC (see below)

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to change or correction.

▪ Requires companies to submit a waiver application to the DEEP commissioner in

way she prescribes and that specifies the conditions that make using these
technologies impossible or impracticable
▪ Requires the DEEP commissioner to accept or deny a waiver application by 60
days after receiving it
▪ Authorizes DEEP to approve a waiver after consulting with OCC
▪ If DEEP does not act on a waiver application within 60 days, it is deemed
approved
o Allows an EDC to request a revocable general waiver from DEEP of requirements to
submit project alternatives and the bill’s evaluation process (see below) for project
subject to a regional transmission planning or review process that considers advanced
conductors, GETs, or nontransmission alternatives if the DEEP commissioner deems the
process adequate
• Requires EDCs and incumbent transmission owners to include additional information in their
annual reports to the Siting Council on forecasted loads and resources, including:
o A schedule of any planned construction or material modification of transmission
facilities, substations, and switchyards, for the next 10 years, including:
▪ A description of the need for the project and its scope, as appropriate for the
project’s current development stage
▪ Cost estimates
▪ Whether advanced conductor, GETs, or nontransmission alternatives may be
considered
▪ Any other information requested by DEEP or the Siting Council
o Data on any construction or material modification of transmission facilities, substations,
and switchyards, placed in service in the previous year, including
▪ Both final costs and estimated costs of the project at each relevant design stage
▪ The original estimated in-service date of the facility
▪ Any other information reasonably requested by the DEEP commissioner or OCC
related to projects disclosed in the report
▪ For the first report filed after the bill becomes effective, EDCs must provide this
data for any facility placed into service by the company or transmission owner on
or after January 1, 2022
▪ Requires companies to notify the DEEP commissioner and OCC if the information
is unavailable and attempt to reach a resolution
• Requires the DEEP commissioner, in consultation with OCC, to determine whether a facility
listed in the report for construction or modification requires further evaluation and notify an
EDC within 180 days after their annual report on forecasted loads and resources is filed
o Requires DEEP to consider:
▪ Whether the facility is subject to a transmission planning or review process that
is similar to the typical ISO-New England process
▪ The underlying facility’s age or condition
▪ The proposed project’s scope and cost

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to change or correction.

▪ Whether the proposed project responds to needs identified through proactive

transmission planning by ISO-New England
▪ Whether and how advanced conductors, GETs, and nontransmission alternatives
are proposed to be used, can reduce environmental or aesthetic impacts and
feasibly solve the underlying need identified by the EDC
o Requires DEEP and OCC , before determining that a project requires further evaluation,
to give the EDC an opportunity to provide evidence that the project requires no further
evaluation
o Requires DEEP and OCC to evaluate the proposed projects based on:
▪ The reasonableness of need identified by the EDC justifying the proposed facility
▪ The reasonableness of the project’s proposed scope, including the timing of
proposed investments
▪ Whether the EDC’s proposed solution is the most cost-effective solution to the
identified need or whether alternatives solutions (e.g., GETs, nontransmission
alternatives, or advanced conductors) could more cost effectively address the
identified need
▪ The costs of the proposed project and any alternatives identified as part of the
evaluation
▪ Whether cost-effective opportunities exist for the proposed project to be
changed to account for future demand growth or other variables that could
mitigate the need for the EDC to conduct construction activities on the same
facility before the end of its useful life
▪ Any other factors DEEP or OCC reasonably determine are needed to evaluate a
specific project
o Requires DEEP and OCC to meet with each EDC at least twice per year to discuss and
receive input on any facilities currently under evaluation
o Requires DEEP or OCC to jointly prepare a report detailing the factors for evaluation
listed above
o Requires DEEP or OCC to complete any draft report on the evaluation and share it with
the EDCs no later than 90 days before an EDC files an application or petition with the
Siting Council, so long as the EDC informs DEEP and OCC of the anticipated filing at least
12 months in advance of filing it
o Requires the (1) DEEP commissioner to file a final report on the project evaluations in
the relevant Siting Council proceeding for the proposed project and (2) Siting Council to
give appropriate consideration to DEEP’s findings in making its determination on the
proposed project
o Requires DEEP to initiate a procurement process to implement a nontransmission
alternative if the project evaluation described above identifies a feasible one
▪ Requires PURA to review and approve any agreement to implement the
alternative if PURA determines the alternative ensures reliability, is cost
effective, and is technically feasible
▪ Allows the DEEP commissioner and OCC to hire consultants to assist with this
evaluation and recover costs through the FMCC

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This is an informal working document that was prepared under time constraints; it is not for publication and is subject
to change or correction.

• Requires EDCs and incumbent transmission owners to provide data, communications, and
information requested by the DEEP commissioner or OCC in connection with any project
evaluation, subject to DEEP’s enforcement powers under existing law (CGS § 22a-6, e.g., the
power to administer oaths, take testimony, and subpoena witnesses and evidences to enforce
laws and department regulations and orders)
o Requires EDC responses to requests to be shared with DEEP and OCC
• Requires each EDC to report by January 1, 2027, and every 5 years after, to PURA on its
compliance with the bill’s provisions
o Requires PURA to provide a copy of the report to the Energy and Technology Committee
• Makes any commercial or proprietary financial information for a company provided under
these requirements confidential and protected by DEEP and OCC
• Requires EDCs to submit a report to PURA, in any base rate or capital improvement proceeding,
that analyzes the cost effectiveness of and the projected timetables for employing GETs,
advanced conductors, energy storage, or other non-wires alternatives relevant to the EDC’s
operations or capital investments
o Allows the report to include certain information (e.g., proposed performance incentive
mechanisms)
o Allows PURA to approve the deployment of these technologies with or without
performance incentive mechanisms if PURA deems them cost effective
• EFFECTIVE DATE: October 1, 2025

§ 29 —CONSULTANTS
• Broadens the authority of DEEP, PURA, and OCC to retain consultants by allowing each to
independently retain them (rather than only allowing DEEP to retain them in consultation with
PURA and OCC, and only allowing PURA to retain them in consultation with OCC for FCC
proceedings)
• EFFECTIVE DATE: October 1, 2025

§ 30 — ISO-NEW ENGLAND MEMBERSHIP REQUIREMENT

• Requires transmission owners to be part of ISO-New England
• EFFECTIVE DATE: Upon passage

§ 31 — ISO-NEW ENGLAND VOTES

• Requires EDCs to annually (by February) submit to PURA a report on each recorded vote it (or
its corporate affiliate of the EDC in this state) cast in ISO-NE meetings during the prior year
• The report must include (1) all recorded votes the EDC cast, even if not otherwise disclosed, (2)
all recorded votes the corporate affiliate cast, and (3) a description of how each vote cast was in
the public’s interest
• EFFECTIVE DATE: Upon passage

§ 32 — POWER PURCHASE AGREEMENTS (MILLSTONE) AND STANDARD SERVICE

• Creates an exception for the 3- to 10-year limit on the length of contract terms under the zero-
carbon procurement

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to change or correction.

o allows for contract terms (i.e., shorter or longer) selected by at least one other state
entering into such an agreement if the term is in ratepayers’ best interest
• Allows EDCs to use energy or related products purchased under the previous zero-carbon
procurement (e.g., Millstone) or any other PURA-approved agreement (presumably
procurement agreements) to provide standard service
o EDCs must set the time duration for using these products in consultation with PURA’s
procurement manager
• Requires EDCs to consult with PURA’s procurement manager and OCC and determine that it is
in the best interest of standard service customers
• Requires EDCs that elect to use these products for standard service to:
o seek PURA’s approval to do so
o consult with PURA and OCC to establish product quantity, duration, and the price for
any products recovered through generation service charges
• Allows PURA to establish reporting standards related to determining whether using these
products for standard service is in standard service customers’ best interests
• If PURA approves the energy or products for standard service, costs are recovered through
generation service charges and Class I RECs not used to serve standard service customers are
disposed of under procedures PURA establishes for sale or retirement (see § 41)
• Requires remaining costs and benefits associated with agreements under the zero carbon
procurement or any other PURA-approved agreement to be recovered through a
nonbypassable fully reconciling rate component (as they are now)
• EFFECTIVE DATE: October 1, 2025

§ 33 — STANDARD SERVICE PROCUREMENT PLAN

• Requires, rather than allows, PURA’s procurement manager to consult with DEEP and OCC
when developing the procurement plan
• Requires the procurement plan to include a provision for EDCs to use self-service, where the
EDC can purchase energy, capacity, or other market products needed to serve its standard
service load
• Expands the types of costs PURA and EDCs can recover to include those associated with
implementation of the procurement plan
o Current law allows for costs associated with developing the plan
o PURA recovers costs through an assessment on the companies it regulations
o EDCs recover costs through a reconciling bypassable component of electric rates as
PURA determines
• Requires PURA’s procurement manager to submit a procurement plan amendment by October
15, 2025, to PURA for approval, with the following modifications:
o Provision for at least four competitive solicitation per year at a time the procurement
manager determines is in the ratepayers’ best interests
o Allowance of contracts with durations up to three years
o Allowance of fixed price energy supply contracts in addition to full requirements
contracts

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This is an informal working document that was prepared under time constraints; it is not for publication and is subject
to change or correction.

o Direction to the EDCs to develop the capacity and expertise to purchase all or any
portion of the energy, capacity, or other market products needed to serve the
companies standard service load from applicable markets or other sources
• Decreases the frequency of the procurement manager’s report on procurement plan
implementation from quarterly to annually
• Allows PURA to initiate an uncontested proceeding to amend the procurement plan from time
to time
• Makes minor and technical changes (e.g., removing references to “interim” amendments and
the “annual” procurement plan, generally conforming to practice)
• EFFECTIVE DATE: October 1, 2025

§ 34 — PROCUREMENT STUDY
• Requires PURA to study standard service and last resort service, including processes, polices,
procedures, and timelines, in non-vertically integrated jurisdictions outside the ISO-New
England region
• Requires the study to:
o Include a comparative analysis of benefits and challenges of the procurement policies
for default energy supply service for the jurisdictions
o Identify any practices that could be adopted by EDCs to lower rates for standard service
customers (e.g., strategies to reduce risk premium)
o Evaluate the timing and frequency of procurements and supply rate adjustment
o Include any other analysis PURA deems relevant
• Requires the PURA chairperson to report its findings to the Energy and Technology Committee
by January 15, 2027
• EFFECTIVE DATE: Upon passage

§ 35 — THERMAL ENERGY NETWORKS

• Requires DEEP to establish a thermal energy network grant and loan program, within available
appropriations, to support the development of thermal energy network products
o “Thermal energy network” is all real estate, fixtures, and personal property owned,
operated, and used or in connection with a utility-scale distribution infrastructure
project that pumps thermal energy (heating or heating and cooling derived from
geothermal energy or fuel sources that do not emit greenhouse gases) as piped
noncombustible fluids used to transfer heat into and out of buildings for heating and
cooling processes (e.g., for comfort, domestic hot water, and refrigeration)
o Requires DEEP commissioner to develop and issue an RFP from eligible recipients (e.g.,
local or regional governmental entities, municipal corporations, regional COGs, public
authorities, EDCs, tribes, municipal electric utilities, energy improvement districts,
nonprofit, academic, and private entities)
o Grants and loans may provide:
▪ Help with community planning (e.g., thermal energy network project feasibility,
such as a benefit-cost analysis)
▪ Help with costs for design, engineering services, and infrastructure

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This is an informal working document that was prepared under time constraints; it is not for publication and is subject
to change or correction.

▪ Nonfederal cost share for grant or loan applications

o Allows DEEP commissioner to establish any financing mechanisms to provide or leverage
additional funding to support these projects
o Requires grant or loan recipients to report to PURA, OCC, DEEP, and the Energy and
Technology Committee annually for three years after getting a grant or loan on the
status or their projects
o EFFECTIVE October 1, 2025

§ 36 & 38 — NEW NUCLEAR CONSTRUCTION

• Creates a second exception from the nuclear moratorium for advanced nuclear reactors
o Requires advanced nuclear reactors to get consent, either by a referendum or a vote of
the legislative body, from (1) the municipality where the proposed facility is sited and
(2) any other municipality in the proposed facility’s emergency planning zone, as the
federal Nuclear Regulatory Commission (NRC) determines
o For both the existing exception (construction at Millstone) and advanced nuclear
reactors, the bill requires the entity proposing a new facility to get all permits, licenses,
and permissions or approvals for the facility’s construction, operation, and
decommissioning funding required under any applicable federal laws, NRC regulations,
and any other federal or state law, rule, or regulation on the facility’s permitting,
licensing, construction, operation, or decommissioning
• Expands DEEP’s duties related to atomic development activity by requiring the commissioner or
designee to be a point of contact for public and private stakeholders to help them comply with
federal, state, and local requirements related to atomic development (e.g., siting considerations
and permitting)
• EFFECTIVE DATE: October 1, 2025

§ 37 — COMPETITIVE ADVANCED NUCLEAR REACTOR AND OFFSHORE WIND ENERGY SITE READINESS
FUNDING PROGRAM
• Requires DEEP to establish the program and provide grants or loans to eligible recipients to
support the following activities for advanced nuclear reactors and offshore wind facilities:
o Environmental and technical studies for early site permitting
o Local and regional infrastructure assessments to support facility development
o Community engagement and planning initiatives related to hosting facilities
o Other necessary expenses DEEP identifies to advance facilities
• “Eligible recipients” are:
o Any of the following entities with a demonstrated interest in hosting advanced nuclear
reactors or facilities associated with the development and interconnection of offshore
wind facilities
▪ Regional governmental entities
▪ Municipalities
▪ Regional COGs
▪ Public authorities
▪ State or federally recognized tribe

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This is an informal working document that was prepared under time constraints; it is not for publication and is subject
to change or correction.

▪ Municipal electric utility or cooperative

o A private entity partnering with any of the above entities
o A higher education institution in the state
• Allows DEEP use these funding sources to support the program and hire a technical consultant
to implement the program:
o Bond funds authorized in support of the program and
o Federal funds allocated to the state
▪ Allows DEEP to revise its program criteria to be consistent with federal funding
criteria
• Authorizes $5 million in general obligation bonds for DEEP to fund grants or loans through the
program
• EFFECTIVE DATE: July 1, 2025

§ 39 — LANDFILL METHANE AND BIOMASS REMOVED FROM CLASS I

• Removes electricity derived from landfill methane gas and biomass facilities from the definition
of Class I renewable energy source
• EFFECTIVE DATE: October 1, 2025

§§ 40 - 46 — CLASS I RENEWABLE PORTFOLIO STANDARD (RPS)

• Decreases Class I RPS requirements
Year Current Law Bill
2026 32 25
2027 34 27
2028 36 29
2029 38 31
2030 40 33

• Requires PURA, in consultation with DEEP and OCC, to establish procedures for RECs purchased
under renewable energy tariffs and PPAs resulting from various DEEP solicitations, which may
include procedures for (1) selling them or (2) retiring them on behalf of all ratepayers to reduce
EDC and supplier RPS requirements, rather than allowing them to be sold
• Applies to RECs purchased under the following programs:
o Clean energy tariffs (§ 10)
o Class I/large scale hydro (§ 41)
o Run-of-the-river hydropower, landfill methane gas, biomass, fuel cell, offshore wind or
anaerobic digestion, or energy storage systems (§ 42)
o Class I procured in event of Class I material shortage (§ 43)
o Offshore wind (§ 44)
o Anaerobic digestion (§ 45)
• EFFECTIVE DATE: October 1, 2025

§ 46 — INTEGRATED RESOURCE PLAN (IRP) AND RENEWABLE PROCUREMENTS

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This is an informal working document that was prepared under time constraints; it is not for publication and is subject
to change or correction.

• Requires DEEP, in the next IRP approved after January 1, 2025, to:
o establish targets for how much energy DEEP may seek in solicitations under existing
authorizations for various energy sources (e.g., offshore wind, Class I sources, zero-
carbon procurement)
o include a proposed schedule for these solicitations for new zero carbon Class I
renewable energy resources needed to achieve an additional 7% of the load served by
EDCs in the aggregate by 2030 (in addition to RPS requirements)
• Requires DEEP’s targets to consider various factors (e.g., electricity system needs identified by
the IRP, greenhouse gas reduction goals, the Comprehensive Energy Strategy, positive impacts
on the state’s economic development, opportunities to coordinate with other states,
forecasted trends in technology costs, and ratepayer impacts)
• EFFECTIVE DATE: October 1, 2025

§ 47 — GAS DEMAND RESPONSE SOLICITATION

• Expands a solicitation authorization in current law for passive demand response measures (1) to
include active demand response measures and (2) by allowing DEEP to solicit and direct gas
companies into 20-year contracts for active or passive demand proposals
• Correspondingly removes a requirement that demand response projects reduce electric
demand by at least 1 MW
• Requires gas companies, in addition to EDCs, to consult with the Energy Efficiency Board to
assess the feasibility of demand response proposals
• Requires the DEEP commissioner to consider the same factors as under current law, including
whether benefits to ratepayers outweigh costs, fuel diversity, and greenhouse gas reductions,
among other things
• Caps aggregate amount of these proposals at 10% of the state’s gas utility load (existing law
caps proposals at 10% of the EDCs’ load, applying in the aggregate to demand response
solicitations and other solicitations (e.g., Class I, energy storage)
• Allows DEEP to direct EDCs into long-term contracts for active demand response measures that
result in electric savings and electricity time-of-use shifts
• Allows DEEP to direct the gas companies to enter into long-term contracts for active or passive
demand response measures that yield gas savings or time-of-use shifts from proposals
submitted under the bill, so long as the contract’s benefits outweigh its costs to gas customers
• Requires gas companies to submit agreements to PURA for approval and recover net costs
through the C&LM CAM (see §§ 1 & 2)
• If an EDC and gas company both apply to recover net costs for the same agreement, PURA must
determine which costs are attributable to each company
• For all solicitations under the bill and under existing authorizations in this section, requires RECs
to be disposed of under procedures PURA establishes (see § 41)
• EFFECTIVE DATE: October 1, 2025

§§ 48 & 52 — PURA and DEEP

• Makes PURA a part of DEEP for administrative purposes only

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This is an informal working document that was prepared under time constraints; it is not for publication and is subject
to change or correction.

• For commissioners appointed on or after January 1, 2025, specifies their terms begin when they
are appointed and qualified and their terms continue for four years following the July after the
date the governor appointed them; they may continue holding office until a successor is
appointed
• Modifies the three-commissioner panel laws to specify proceedings (rather than all matters)
may be heard by a panel and requires that:
o the PURA chairperson select a panel presiding officer (or serve as such), who must
schedule hearings and issue notices and rulings (including motions) on procedural,
evidentiary, and intermediate matters
o the presiding officer may take these actions if a majority of the panel supports doing so
after communication and conferencing; these actions constitute an action of the panel
unless a majority of the panel modifies them
o the final decision must be approved by a majority vote of the panel and votes of each
member must be recorded in the meeting minutes, documented in writing, and made
public within 48 hours
o Removes a provision requiring panel decisions that are not unanimous to be approved a
majority vote of all utility commissioners
• Requires that all utility commissioners be assigned to any panels (1) imposing civil penalties for
violations of PURA regulations and orders (under CGS § 16-41), (2) for a general rate hearing
(under CGS § 16-19a), and (3) for rate amendments (under CGS § 16-19)
• Except for rate amendments, the PURA chairperson may assign a hearing officer to develop the
administrative record, issue rulings (including motions) on procedural, evidentiary, and
intermediate matters and, if applicable, file a proposed final decision in accordance with the
UAPA
• For recusals or disqualifications, commissioners are considered administrative adjudicators
• Adds requirement that the PURA chairperson, when doing staff and agency planning, ensure
that utility commissioners who write concurring or dissenting opinions have staff to assist them
with it
• Expands the existing “revolving door” and “cooling off period” limitations on PURA
commissioners and employees by:
o prohibiting former commissioners and DEEP employees assigned to work with PURA (as
well as current ones) from accepting outside employment that could conflict with their
work with PURA by impairing their independence or induce sharing confidential
information
o lengthening, from one year to three years, the period after a commissioner leaves PURA
that he or she is barred from accepting employment with a public service company,
telecommunications provider, or their lobbyists–and also adds they cannot be employed
by related entities or a firm or corporation that provides legal representation to them
either
o subjecting PURA employees to the same post-employment restrictions, but only for one
year, exempting employees that PURA terminated
o Prohibits all former commissioners, rather than just those who are attorneys, from
appearing or participating in matters before PURA

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This is an informal working document that was prepared under time constraints; it is not for publication and is subject
to change or correction.

• An existing Uniform Administrative Procedures Act provision (CGS § 4-175) allows plaintiffs in
certain Superior Court civil actions (filed under CGS § 52-59) to seek a declaratory judgment
from the court regarding the validity of certain agency regulations or final actions (specifically
those that may impair the legal rights of the plaintiff). The bill specifies this provision applies to
actions filed after January 1, 2025, to which PURA is a party.
• Makes other minor conforming changes (e.g., removing a requirement that certain PURA
regulations align with DEEP policies)
• EFFECTIVE DATE: October 1, 2025

§ 49-51 — OCC CONSULTANTS & TRANSACTION INFORMATION

• Specifies that OCC can retain engineers as consultants (current law allows other consultants
knowledgeable in utility regulation (e.g., economists, capital cost experts, and rate design
experts)
• Requires PURA to include in the transmission rate adjustment funds to cover DEEP’s and OCC’s
costs to participate in Siting Council proceedings and evaluations and analysis
• Current law allows PURA to order holding companies and their subsidiaries to produce
documents related to the company’s or subsidiaries’ transactions with a public service company
and have those transaction audited. Under this law, the holding company’s or subsidiary’s
proprietary commercial and proprietary financial information is confidential and protected by
PURA
o Requires this information to be provided to OCC
o Requires OCC to keep this information confidential and protect it, subject to FOIA laws
o Prohibits OCC employees from willfully and knowingly disclosing confidential
information to any other person for pecuniary gain or using the information for
pecuniary gain
• EFFECTIVE DATE: October 1, 2025

53 — RATE CASE DEADLINE EXTENSIONS

• Allows PURA to extend its deadlines to act on utility rate case decisions by up to 90 days if more
than one utility with at least 75,000 customers files a rate amendment application in a 60-day
period
• EFFECTIVE DATE: Upon passage

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