Flett Exchange is a leading environmental exchange and brokerage firm. Our online trading platform brings transparency, price discovery, and liquidity to Solar Renewable Energy Certificates (SRECs). Our knowledgeable staff is also available to assist you in selling your SRECs for you. Over 3,500 active clients utilize Flett Exchange to negotiate the price, quantity, and details of SRECs in a secure and seamless online trading platform. Upon each SREC transaction Flett Exchange remits immediate payment to our sellers. Flett Exchange operates SREC markets in NJ, PA, DE, MD, OH, CT, MA, and DC and supported by trained solar professionals with specialized knowledge and proven experience.
 
Flett Exchange also brokers bilateral long-term SREC contracts between qualified counterparties. Flett Exchange buyers and sellers can secure price, quantity, and terms of SREC contracts 1-5 years in duration. Our stringent vetting process ensures that quality solar projects are presented to the market in a skillful manner. Buyers and sellers utilize Flett Exchange for long-term SREC contracts gain direct access to large pools of SRECs, while mitigating risk and locking-in profits. Please visit www.flettexchange.com to learn more about our services. 201-209-0234

The bill would have also lowered fine levels levied against power companies if they did not produce a certain amount of solar power each year. The potential savings to homeowners, municipalities and business’ would have been close to 1 billion dollars over the course of the legislation if it was passed.

The bill was introduced by the Democratic controlled legislature, sponsored by Senator Bob Smith.  The Republican Governors office submitted responses on Sunday for the legislature to consider. The Governors office supported an increase in the RPS to stabilize the market. The deal fell apart because of a disagreement of how to handle grid connected projects. The Christie administration suggested having all non-net metered projects seek Board of Public Utility BPU approval. These projects would not be approved if they would have a detrimental effect on the SREC market. The issue was too complicated to be resolved in the short amount of time left in the last day of the legislative session.

The bill will have to be introduced in the next legislative session.

The SREC market has dropped instantly to $200.

More on Flett Exchange:
 
Flett Exchange is a leading environmental exchange and brokerage firm. Our online trading platform brings transparency, price discovery, and liquidity to Solar Renewable Energy Certificates (SRECs). Our knowledgeable staff is also available to assist you in selling your SRECs for you. Over 3,500 active clients utilize Flett Exchange to negotiate the price, quantity, and details of SRECs in a secure and seamless online trading platform. Upon each SREC transaction Flett Exchange remits immediate payment to our sellers. Flett Exchange operates SREC markets in NJ, PA, DE, MD, OH, CT, MA, and DC and supported by trained solar professionals with specialized knowledge and proven experience.
 
Flett Exchange also brokers bilateral long-term SREC contracts between qualified counterparties. Flett Exchange buyers and sellers can secure price, quantity, and terms of SREC contracts 1-5 years in duration. Our stringent vetting process ensures that quality solar projects are presented to the market in a skillful manner. Buyers and sellers utilize Flett Exchange for long-term SREC contracts gain direct access to large pools of SRECs, while mitigating risk and locking-in profits. Please visit www.flettexchange.com to learn more about our services. 201-209-0234

EY2014 1,264 Gwhrs

EY2015 1,450 Gwhrs

EY2016 1,680 Gwhrs

EY2017 1,987 Gwhrs

EY2018 2,180 Gwhrs

EY2019 2,368 Gwhrs

EY2020 2,510 Gwhrs

EY2021 2,709.658 Gwhrs

EY2022 2,929.164 Gwhrs

EY2023 3,166.451 Gwhrs

EY2024 3,422.96 Gwhrs

EY2025 3,700.249 Gwhrs

EY2026 4,000 Gwhrs

EY 2027 4,200 Gwhrs

EY 2028 4,400 Gwhrs

EY 2029 4,600 Gwhrs

EY 2030 4,800 Gwhrs

EY20312 , and for every energy year thereafter, at least 2[5,316] 5,0002
 

Old Schedule:
 
1[EY 2013 596 Gwhrs

EY 2014 772 Gwhrs

EY 2015 965 Gwhrs

EY 2016 1,150 Gwhrs

EY 2017 1,357 Gwhrs

EY 2018 1,591 Gwhrs

EY 2019 1,858 Gwhrs

EY 2020 2,164 Gwhrs

EY 2021 2,518 Gwhrs

EY 2022 2,928 Gwhrs

EY 2023 3,433 Gwhrs

EY 2024 3,989 Gwhrs

EY 2025 4,610 Gwhrs

EY 2026 5,316 Gwhrs
 
New SACP (fine)
 
EY 2013 $437

EY 2014 $422

EY 2015 $407

EY 2016 $393

EY 2017 $377

EY 2018 $362

EY 2019 $347

EY 2020 $334

EY 2021 $320

EY 2022 $307

EY 2023 $298

EY 2024 $289

EY 2025 $281

EY 2026 $272

EY 2027 $270

EY 2028 $265

EY 2029 $260

EY2030 $255

EY2031 $2502
 
Old SACP (fine):
 
EY 2013 $641

EY 2014 $625

EY 2015 $609

EY 2016 $594

EY 2017 $475*

EY 2018 $463*

EY 2019 $451*

EY 2020 $440*

EY 2021 $429*

EY 2022 $418*

EY 2023 $418*

EY 2024 $407*

EY 2025 $397*

EY 2026 $387*

EY 2027 $377*

*proposed
 

The Christie Administration will need to review the bill. There are also other aspects in the bill that will be considered and have the potential of preventing its passage. One last minute insertion by some solar industry insiders is a requirement that the ratepayer back a minimum of 30% of all new development in the State by forcing long term SREC contracts on ratepayers
 
Here is the bill:
 
ASSEMBLY TELECOMMUNICATIONS AND UTILITIES COMMITTEE

A M E N D M E N T S

to

[First Reprint]

SENATE, No. 2371

(Sponsored by Senator SMITH )

REPLACE TITLE TO READ:

An Act concerning 1[certain contracts for the purchase of]1 2[solar renewable energy 1[certificates] portfolio standards1] energy efficiency and renewable energy2 and amending P.L.1999, c.23.

INSERT NEW SECTION 1 TO READ:

21. Section 3 of P.L.1999, c.23 (C.48:3-51) is amended to read as follows:

3. As used in P.L.1999, c.23 (C.48:3-49 et al.):

“Assignee” means a person to which an electric public utility or another assignee assigns, sells or transfers, other than as security, all or a portion of its right to or interest in bondable transition property. Except as specifically provided in P.L.1999, c.23 (C.48:3-49 et al.), an assignee shall not be subject to the public utility requirements of Title 48 or any rules or regulations adopted pursuant thereto;

“Base load electric power generation facility” means an electric power generation facility intended to be operated at a greater than 50 percent capacity factor including, but not limited to, a combined cycle power facility and a combined heat and power facility;

“Base residual auction” means the auction conducted by PJM, as part of PJM’s reliability pricing model, three years prior to the start of the delivery year to secure electrical capacity as necessary to satisfy the capacity requirements for that delivery year;

“Basic gas supply service” means gas supply service that is provided to any customer that has not chosen an alternative gas supplier, whether or not the customer has received offers as to competitive supply options, including, but not limited to, any customer that cannot obtain such service for any reason, including non-payment for services. Basic gas supply service is not a competitive service and shall be fully regulated by the board;

“Basic generation service” or “BGS” means electric generation service that is provided, to any customer that has not chosen an alternative electric power supplier, whether or not the customer has received offers for competitive supply options, including, but not limited to, any customer that cannot obtain such service from an electric power supplier for any reason, including non-payment for services. Basic generation service is not a competitive service and shall be fully regulated by the board;

“Basic generation service provider” or “provider” means a provider of basic generation service;

“Basic generation service transition costs” means the amount by which the payments by an electric public utility for the procurement of power for basic generation service and related ancillary and administrative costs exceeds the net revenues from the basic generation service charge established by the board pursuant to section 9 of P.L.1999, c.23 (C.48:3-57) during the transition period, together with interest on the balance at the board-approved rate, that is reflected in a deferred balance account approved by the board in an order addressing the electric public utility’s unbundled rates, stranded costs, and restructuring filings pursuant to P.L.1999, c.23 (C.48:3-49 et al.). Basic generation service transition costs shall include, but are not limited to, costs of purchases from the spot market, bilateral contracts, contracts with non-utility generators, parting contracts with the purchaser of the electric public utility’s divested generation assets, short-term advance purchases, and financial instruments such as hedging, forward contracts, and options. Basic generation service transition costs shall also include the payments by an electric public utility pursuant to a competitive procurement process for basic generation service supply during the transition period, and costs of any such process used to procure the basic generation service supply;

“Board” means the New Jersey Board of Public Utilities or any successor agency;

“Bondable stranded costs” means any stranded costs or basic generation service transition costs of an electric public utility approved by the board for recovery pursuant to the provisions of P.L.1999, c.23 (C.48:3-49 et al.), together with, as approved by the board: (1) the cost of retiring existing debt or equity capital of the electric public utility, including accrued interest, premium and other fees, costs and charges relating thereto, with the proceeds of the financing of bondable transition property; (2) if requested by an electric public utility in its application for a bondable stranded costs rate order, federal, State and local tax liabilities associated with stranded costs recovery or basic generation service transition cost recovery or the transfer or financing of such property or both, including taxes, whose recovery period is modified by the effect of a stranded costs recovery order, a bondable stranded costs rate order or both; and (3) the costs incurred to issue, service or refinance transition bonds, including interest, acquisition or redemption premium, and other financing costs, whether paid upon issuance or over the life of the transition bonds, including, but not limited to, credit enhancements, service charges, overcollateralization, interest rate cap, swap or collar, yield maintenance, maturity guarantee or other hedging agreements, equity investments, operating costs and other related fees, costs and charges, or to assign, sell or otherwise transfer bondable transition property;

“Bondable stranded costs rate order” means one or more irrevocable written orders issued by the board pursuant to P.L.1999, c.23 (C.48:3-49 et al.) which determines the amount of bondable stranded costs and the initial amount of transition bond charges authorized to be imposed to recover such bondable stranded costs, including the costs to be financed from the proceeds of the transition bonds, as well as on-going costs associated with servicing and credit enhancing the transition bonds, and provides the electric public utility specific authority to issue or cause to be issued, directly or indirectly, transition bonds through a financing entity and related matters as provided in P.L.1999, c.23, which order shall become effective immediately upon the written consent of the related electric public utility to such order as provided in P.L.1999, c.23;

“Bondable transition property” means the property consisting of the irrevocable right to charge, collect and receive, and be paid from collections of, transition bond charges in the amount necessary to provide for the full recovery of bondable stranded costs which are determined to be recoverable in a bondable stranded costs rate order, all rights of the related electric public utility under such bondable stranded costs rate order including, without limitation, all rights to obtain periodic adjustments of the related transition bond charges pursuant to subsection b. of section 15 of P.L.1999, c.23 (C.48:3-64), and all revenues, collections, payments, money and proceeds arising under, or with respect to, all of the foregoing;

“British thermal unit” or “Btu” means the amount of heat required to increase the temperature of one pound of water by one degree Fahrenheit;

“Broker” means a duly licensed electric power supplier that assumes the contractual and legal responsibility for the sale of electric generation service, transmission or other services to end-use retail customers, but does not take title to any of the power sold, or a duly licensed gas supplier that assumes the contractual and legal obligation to provide gas supply service to end-use retail customers, but does not take title to the gas;

“Buydown” means an arrangement or arrangements involving the buyer and seller in a given power purchase contract and, in some cases third parties, for consideration to be given by the buyer in order to effectuate a reduction in the pricing, or the restructuring of other terms to reduce the overall cost of the power contract, for the remaining succeeding period of the purchased power arrangement or arrangements;

“Buyout” means an arrangement or arrangements involving the buyer and seller in a given power purchase contract and, in some cases third parties, for consideration to be given by the buyer in order to effectuate a termination of such power purchase contract;

“Class I renewable energy” means electric energy produced from solar technologies, photovoltaic technologies, wind energy, fuel cells, geothermal technologies, wave or tidal action, small scale hydropower facilities with a capacity of three megawatts or less and put into service after the effective date of P.L. , c. (C. ) (pending before the Legislature as this bill), and methane gas from landfills or a biomass facility, provided that the biomass is cultivated and harvested in a sustainable manner;

“Class II renewable energy” means electric energy produced at a [resource recovery facility or] hydropower facility with a capacity of greater than three megawatts or a resource recovery facility, provided that such facility is located where retail competition is permitted and provided further that the Commissioner of Environmental Protection has determined that such facility meets the highest environmental standards and minimizes any impacts to the environment and local communities;

“Co-generation” means the sequential production of electricity and steam or other forms of useful energy used for industrial or commercial heating and cooling purposes;

“Combined cycle power facility” means a generation facility that combines two or more thermodynamic cycles, by producing electric power via the combustion of fuel and then routing the resulting waste heat by-product to a conventional boiler or to a heat recovery steam generator for use by a steam turbine to produce electric power, thereby increasing the overall efficiency of the generating facility;

“Combined heat and power facility” or “co-generation facility” means a generation facility which produces electric energy[,] and steam[,] or other forms of useful energy such as heat, which are used for industrial or commercial heating or cooling purposes. A combined heat and power facility or co-generation facility shall not be considered a public utility;

“Competitive service” means any service offered by an electric public utility or a gas public utility that the board determines to be competitive pursuant to section 8 or section 10 of P.L.1999, c.23 (C.48:3-56 or C.48:3-58) or that is not regulated by the board;

“Commercial and industrial energy pricing class customer” or “CIEP class customer” means that group of non-residential customers with high peak demand, as determined by periodic board order, which either is eligible or which would be eligible, as determined by periodic board order, to receive funds from the Retail Margin Fund established pursuant to section 9 of P.L.1999, c.23 (C.48:3-57) and for which basic generation service is hourly-priced;

“Comprehensive resource analysis” means an analysis including, but not limited to, an assessment of existing market barriers to the implementation of energy efficiency and renewable technologies that are not or cannot be delivered to customers through a competitive marketplace;

“Connected to the distribution system” means, for a solar power generation facility, (1) connected to a net metering customer’s side of a meter, regardless of the voltage at which that customer connects to the electric grid, or (2) directly connected to the electric grid at 69 kilovolts or less, regardless of how an electric public utility classifies that portion of its electric grid, except that notwithstanding that it meets the criterion set forth in paragraph (1) or in paragraph (2) hereof, a solar electric power generation facility that is greater than 10 megawatts in capacity and either not net metered or not an on-site generation facility shall not be considered “connected to the distribution system” unless it shall have been designated as such by the board pursuant to subsection r. of section 38 of P.L.1999, c.23 (C.48:3-87). Any facility, other than that of a net metering customer on the customer’s side of the meter, connected above 69 kilovolts shall not be considered connected to the distribution system;

“Customer” means any person that is an end user and is connected to any part of the transmission and distribution system within an electric public utility’s service territory or a gas public utility’s service territory within this State;

“Customer account service” means metering, billing, or such other administrative activity associated with maintaining a customer account;

“Delivery year” or “DY” means the 12-month period from June 1st through May 31st, numbered according to the calendar year in which it ends;

“Demand side management” means the management of customer demand for energy service through the implementation of cost-effective energy efficiency technologies, including, but not limited to, installed conservation, load management and energy efficiency measures on and in the residential, commercial, industrial, institutional and governmental premises and facilities in this State;

“EE certificate” means a certificate issued by the board or its designee, representing one megawatt hour (MWh) of eligible energy efficiency and energy conservation and has value based upon, and driven by, the energy market;

“Electric generation service” means the provision of retail electric energy and capacity which is generated off-site from the location at which the consumption of such electric energy and capacity is metered for retail billing purposes, including agreements and arrangements related thereto;

“Electric power generator” means an entity that proposes to construct, own, lease or operate, or currently owns, leases or operates, an electric power production facility that will sell or does sell at least 90 percent of its output, either directly or through a marketer, to a customer or customers located at sites that are not on or contiguous to the site on which the facility will be located or is located. The designation of an entity as an electric power generator for the purposes of P.L.1999, c.23 (C.48:3-49 et al.) shall not, in and of itself, affect the entity’s status as an exempt wholesale generator under the Public Utility Holding Company Act of 1935, 15 U.S.C. s.79 et seq.;

“Electric power supplier” means a person or entity that is duly licensed pursuant to the provisions of P.L.1999, c.23 (C.48:3-49 et al.) to offer and to assume the contractual and legal responsibility to provide electric generation service to retail customers, and includes load serving entities, marketers and brokers that offer or provide electric generation service to retail customers. The term excludes an electric public utility that provides electric generation service only as a basic generation service pursuant to section 9 of P.L.1999, c.23 (C.48:3-57);

“Electric public utility” means a public utility, as that term is defined in R.S.48:2-13, that transmits and distributes electricity to end users within this State;

“Electric related service” means a service that is directly related to the consumption of electricity by an end user, including, but not limited to, the installation of demand side management measures at the end user’s premises, the maintenance, repair or replacement of appliances, lighting, motors or other energy-consuming devices at the end user’s premises, and the provision of energy consumption measurement and billing services;

“Electronic signature” means an electronic sound, symbol or process, attached to, or logically associated with, a contract or other record, and executed or adopted by a person with the intent to sign the record;

“Eligible energy efficiency and energy conservation programs” means programs which apply measurement and verification standards adopted by the board to the board’s issuance of an EE certificate, and which utilize demand side management consisting of the management of customer consumption of electricity or of the demand for or generation of electricity through the implementation of (1) energy efficiency technologies, management practices, or other strategies in residential, commercial, industrial, institutional, or government customers that reduce electricity consumption by those customers, (2) load management or demand response technologies, management practices or other strategies in residential, commercial, industrial, institutional and government customers that shift electric load from periods of higher demand to periods of lower demand, or (3) industrial by-product technologies that use a by-product from an industrial process, including the reuse of energy from exhaust gases or other manufacturing by-products in the direct production of electricity at the facility of a customer;

“Eligible generator” means a developer of a base load or mid-merit electric power generation facility including, but not limited to, an on-site generation facility that qualifies as a capacity resource under PJM criteria and that commences construction after the effective date of P.L.2011, c.9 (C.48:3-98.2 et al.);

“Energy agent” means a person that is duly registered pursuant to the provisions of P.L.1999, c.23 (C.48:3-49 et al.), that arranges the sale of retail electricity or electric related services or retail gas supply or gas related services between government aggregators or private aggregators and electric power suppliers or gas suppliers, but does not take title to the electric or gas sold;

“Energy consumer” means a business or residential consumer of electric generation service or gas supply service located within the territorial jurisdiction of a government aggregator;

“Energy efficiency portfolio standard” means a requirement to procure a specified amount of energy efficiency or demand side management resources as a means of managing and reducing energy usage and demand by customers;

“Energy year” or “EY” means the 12-month period from June 1st through May 31st, numbered according to the calendar year in which it ends;

“Federal Energy Regulatory Commission” or “FERC” means the federal agency established pursuant to 42 U.S.C. s.7171 et seq. to regulate the interstate transmission of electricity, natural gas, and oil;

“Financing entity” means an electric public utility, a special purpose entity, or any other assignee of bondable transition property, which issues transition bonds. Except as specifically provided in P.L.1999, c.23 (C.48:3-49 et al.), a financing entity which is not itself an electric public utility shall not be subject to the public utility requirements of Title 48 or any rules or regulations adopted pursuant thereto;

“Gas public utility” means a public utility, as that term is defined in R.S.48:2-13, that distributes gas to end users within this State;

“Gas related service” means a service that is directly related to the consumption of gas by an end user, including, but not limited to, the installation of demand side management measures at the end user’s premises, the maintenance, repair or replacement of appliances or other energy-consuming devices at the end user’s premises, and the provision of energy consumption measurement and billing services;

“Gas supplier” means a person that is duly licensed pursuant to the provisions of P.L.1999, c.23 (C.48:3-49 et al.) to offer and assume the contractual and legal obligation to provide gas supply service to retail customers, and includes, but is not limited to, marketers and brokers. A non-public utility affiliate of a public utility holding company may be a gas supplier, but a gas public utility or any subsidiary of a gas utility is not a gas supplier. In the event that a gas public utility is not part of a holding company legal structure, a related competitive business segment of that gas public utility may be a gas supplier, provided that related competitive business segment is structurally separated from the gas public utility, and provided that the interactions between the gas public utility and the related competitive business segment are subject to the affiliate relations standards adopted by the board pursuant to subsection k. of section 10 of P.L.1999, c.23 (C.48:3-58);

“Gas supply service” means the provision to customers of the retail commodity of gas, but does not include any regulated distribution service;

“Government aggregator” means any government entity subject to the requirements of the “Local Public Contracts Law,” P.L.1971, c.198 (C.40A:11-1 et seq.), the “Public School Contracts Law,” N.J.S.18A:18A-1 et seq., or the “County College Contracts Law,” P.L.1982, c.189 (C.18A:64A-25.1 et seq.), that enters into a written contract with a licensed electric power supplier or a licensed gas supplier for: (1) the provision of electric generation service, electric related service, gas supply service, or gas related service for its own use or the use of other government aggregators; or (2) if a municipal or county government, the provision of electric generation service or gas supply service on behalf of business or residential customers within its territorial jurisdiction;

“Government energy aggregation program” means a program and procedure pursuant to which a government aggregator enters into a written contract for the provision of electric generation service or gas supply service on behalf of business or residential customers within its territorial jurisdiction;

“Governmental entity” means any federal, state, municipal, local or other governmental department, commission, board, agency, court, authority or instrumentality having competent jurisdiction;

“Greenhouse gas emissions portfolio standard” means a requirement that addresses or limits the amount of carbon dioxide emissions indirectly resulting from the use of electricity as applied to any electric power suppliers and basic generation service providers of electricity;

“Incremental auction” means an auction conducted by PJM, as part of PJM’s reliability pricing model, prior to the start of the delivery year to secure electric capacity as necessary to satisfy the capacity requirements for that delivery year, that is not otherwise provided for in the base residual auction;

“Leakage” means an increase in greenhouse gas emissions related to generation sources located outside of the State that are not subject to a state, interstate or regional greenhouse gas emissions cap or standard that applies to generation sources located within the State;

“Locational deliverability area” or “LDA” means one or more of the zones within the PJM region which are used to evaluate area transmission constraints and reliability issues including electric public utility company zones, sub-zones, and combinations of zones;

“Long-term capacity agreement pilot program” or “LCAPP” means a pilot program established by the board that includes participation by eligible generators, to seek offers for financially-settled standard offer capacity agreements with eligible generators pursuant to the provisions of P.L.2011, c.9 (C.48:3-98.2 et al.);

“Market transition charge” means a charge imposed pursuant to section 13 of P.L.1999, c.23 (C.48:3-61) by an electric public utility, at a level determined by the board, on the electric public utility customers for a limited duration transition period to recover stranded costs created as a result of the introduction of electric power supply competition pursuant to the provisions of P.L.1999, c.23 (C.48:3-49 et al.);

“Marketer” means a duly licensed electric power supplier that takes title to electric energy and capacity, transmission and other services from electric power generators and other wholesale suppliers and then assumes the contractual and legal obligation to provide electric generation service, and may include transmission and other services, to an end-use retail customer or customers, or a duly licensed gas supplier that takes title to gas and then assumes the contractual and legal obligation to provide gas supply service to an end-use customer or customers;

“Mid-merit electric power generation facility” means a generation facility that operates at a capacity factor between baseload generation facilities and peaker generation facilities;

“Net proceeds” means proceeds less transaction and other related costs as determined by the board;

“Net revenues” means revenues less related expenses, including applicable taxes, as determined by the board;

“Offshore wind energy” means electric energy produced by a qualified offshore wind project;

“Offshore wind renewable energy certificate” or “OREC” means a certificate, issued by the board or its designee, representing the environmental attributes of one megawatt hour of electric generation from a qualified offshore wind project;

“Off-site end use thermal energy services customer” means an end use customer that purchases thermal energy services from an on-site generation facility, combined heat and power facility, or co-generation facility, and that is located on property that is separated from the property on which the on-site generation facility, combined heat and power facility, or co-generation facility is located by more than one easement, public thoroughfare, or transportation or utility-owned right-of-way;

“On-site generation facility” means a generation facility, including but not limited to, a generation facility that produces Class I or Class II renewable energy, and equipment and services appurtenant to electric sales by such facility to the end use customer located on the property or on property contiguous to the property on which the end user is located. An on-site generation facility shall not be considered a public utility. The property of the end use customer and the property on which the on-site generation facility is located shall be considered contiguous if they are geographically located next to each other, but may be otherwise separated by an easement, public thoroughfare, transportation or utility-owned right-of-way, or if the end use customer is purchasing thermal energy services produced by the on-site generation facility, for use for heating or cooling, or both, regardless of whether the customer is located on property that is separated from the property on which the on-site generation facility is located by more than one easement, public thoroughfare, or transportation or utility-owned right-of-way;

“Person” means an individual, partnership, corporation, association, trust, limited liability company, governmental entity or other legal entity;

“PJM Interconnection, L.L.C.” or “PJM” means the privately-held, limited liability corporation that is a FERC-approved Regional Transmission Organization, or its successor, that manages the regional, high-voltage electricity grid serving all or parts of 13 states including New Jersey and the District of Columbia, operates the regional competitive wholesale electric market, manages the regional transmission planning process, and establishes systems and rules to ensure that the regional and in-State energy markets operate fairly and efficiently;

“Private aggregator” means a non-government aggregator that is a duly-organized business or non-profit organization authorized to do business in this State that enters into a contract with a duly licensed electric power supplier for the purchase of electric energy and capacity, or with a duly licensed gas supplier for the purchase of gas supply service, on behalf of multiple end-use customers by combining the loads of those customers;

“Public utility holding company” means: (1) any company that, directly or indirectly, owns, controls, or holds with power to vote, ten percent or more of the outstanding voting securities of an electric public utility or a gas public utility or of a company which is a public utility holding company by virtue of this definition, unless the Securities and Exchange Commission, or its successor, by order declares such company not to be a public utility holding company under the Public Utility Holding Company Act of 1935, 15 U.S.C. s.79 et seq., or its successor; or (2) any person that the Securities and Exchange Commission, or its successor, determines, after notice and opportunity for hearing, directly or indirectly, to exercise, either alone or pursuant to an arrangement or understanding with one or more other persons, such a controlling influence over the management or policies of an electric public utility or a gas public utility or public utility holding company as to make it necessary or appropriate in the public interest or for the protection of investors or consumers that such person be subject to the obligations, duties, and liabilities imposed in the Public Utility Holding Company Act of 1935 or its successor;

“Qualified offshore wind project” means a wind turbine electricity generation facility in the Atlantic Ocean and connected to the electric transmission system in this State, and includes the associated transmission-related interconnection facilities and equipment, and approved by the board pursuant to section 3 of P.L.2010, c.57 (C.48:3-87.1);

“Registration program” means an administrative process developed by the board that requires that all solar electric power generation facilities with a planned capacity of one megawatt or greater that are filing with the board for approval to generate SRECs, to file documents detailing the size, location, and other project information as required by the board;

“Regulatory asset” means an asset recorded on the books of an electric public utility or gas public utility pursuant to the Statement of Financial Accounting Standards, No. 71, entitled “Accounting for the Effects of Certain Types of Regulation,” or any successor standard and as deemed recoverable by the board;

“Related competitive business segment of an electric public utility or gas public utility” means any business venture of an electric public utility or gas public utility including, but not limited to, functionally separate business units, joint ventures, and partnerships, that offers to provide or provides competitive services;

“Related competitive business segment of a public utility holding company” means any business venture of a public utility holding company, including, but not limited to, functionally separate business units, joint ventures, and partnerships and subsidiaries, that offers to provide or provides competitive services, but does not include any related competitive business segments of an electric public utility or gas public utility;

“Reliability pricing model” or “RPM” means PJM’s capacity-market model, and its successors, that secures capacity on behalf of electric load serving entities to satisfy load obligations not satisfied through the output of electric generation facilities owned by those entities, or otherwise secured by those entities through bilateral contracts;

“Renewable energy certificate” or “REC” means a certificate representing the environmental benefits or attributes of one megawatt-hour of generation from a generating facility that produces Class I or Class II renewable energy, but shall not include a solar renewable energy certificate or an offshore wind renewable energy certificate;

“Resource clearing price” or “RCP” means the clearing price established for the applicable locational deliverability area by the base residual auction or incremental auction, as determined by the optimization algorithm for each auction, conducted by PJM as part of PJM’s reliability pricing model;

“Resource recovery facility” means a solid waste facility constructed and operated for the incineration of solid waste for energy production and the recovery of metals and other materials for reuse which the Department of Environmental Protection has determined are in compliance with current environmental standards, including, but not limited to, all applicable requirements of the federal “Clean Air Act” (42 U.S.C. s.7401 et seq.);

“Restructuring related costs” means reasonably incurred costs directly related to the restructuring of the electric power industry, including the closure, sale, functional separation and divestiture of generation and other competitive utility assets by a public utility, or the provision of competitive services as such costs are determined by the board, and which are not stranded costs as defined in P.L.1999, c.23 (C.48:3-49 et al.) but may include, but not be limited to, investments in management information systems, and which shall include expenses related to employees affected by restructuring which result in efficiencies and which result in benefits to ratepayers, such as training or retraining at the level equivalent to one year’s training at a vocational or technical school or county community college, the provision of severance pay of two weeks of base pay for each year of full-time employment, and a maximum of 24 months’ continued health care coverage. Except as to expenses related to employees affected by restructuring, “restructuring related costs” shall not include going forward costs;

“Retail choice” means the ability of retail customers to shop for electric generation or gas supply service from electric power or gas suppliers, or opt to receive basic generation service or basic gas service, and the ability of an electric power or gas supplier to offer electric generation service or gas supply service to retail customers, consistent with the provisions of P.L.1999, c.23 (C.48:3-49 et al.);

“Retail margin” means an amount, reflecting differences in prices that electric power suppliers and electric public utilities may charge in providing electric generation service and basic generation service, respectively, to retail customers, excluding residential customers, which the board may authorize to be charged to categories of basic generation service customers of electric public utilities in this State, other than residential customers, under the board’s continuing regulation of basic generation service pursuant to sections 3 and 9 of P.L.1999, c.23 (C.48:3-51 and 48:3-57), for the purpose of promoting a competitive retail market for the supply of electricity;

“Shopping credit” means an amount deducted from the bill of an electric public utility customer to reflect the fact that such customer has switched to an electric power supplier and no longer takes basic generation service from the electric public utility;

“Small scale hydropower facility” means a facility located within this State and connected to the distribution system, and that meets the requirements of, and has been certified by, a nationally recognized low-impact hydropower organization that has established low-impact hydropower certification criteria applicable to: (1) river flows; (2) water quality; (3) fish passage and protection; (4) watershed protection; (5) threatened and endangered species protection; (6) cultural resource protection; (7) recreation; and (8) facilities recommended for removal;

“Social program” means a program implemented with board approval to provide assistance to a group of disadvantaged customers, to provide protection to consumers, or to accomplish a particular societal goal, and includes, but is not limited to, the winter moratorium program, utility practices concerning “bad debt” customers, low income assistance, deferred payment plans, weatherization programs, and late payment and deposit policies, but does not include any demand side management program or any environmental requirements or controls;

“Societal benefits charge” means a charge imposed by an electric public utility, at a level determined by the board, pursuant to, and in accordance with, section 12 of P.L.1999, c.23 (C.48:3-60);

“Solar alternative compliance payment” or “SACP” means a payment of a certain dollar amount per megawatt hour (MWh) which an electric power supplier or provider may submit to the board in order to comply with the solar electric generation requirements under section 38 of P.L.1999, c.23 (C.48:3-87);

“Solar renewable energy certificate” or “SREC” means a certificate issued by the board or its designee, representing one megawatt hour (MWh) of solar energy that is generated by a facility connected to the distribution system in this State and has value based upon, and driven by, the energy market;

“Standard offer capacity agreement” or “SOCA” means a financially-settled transaction agreement, approved by board order, that provides for eligible generators to receive payments from the electric public utilities for a defined amount of electric capacity for a term to be determined by the board but not to exceed 15 years, and for such payments to be a fully non-bypassable charge, with such an order, once issued, being irrevocable;

“Standard offer capacity price” or “SOCP” means the capacity price that is fixed for the term of the SOCA and which is the price to be received by eligible generators under a board-approved SOCA;

“Stranded cost” means the amount by which the net cost of an electric public utility’s electric generating assets or electric power purchase commitments, as determined by the board consistent with the provisions of P.L.1999, c.23 (C.48:3-49 et al.), exceeds the market value of those assets or contractual commitments in a competitive supply marketplace and the costs of buydowns or buyouts of power purchase contracts;

“Stranded costs recovery order” means each order issued by the board in accordance with subsection c. of section 13 of P.L.1999, c.23 (C.48:3-61) which sets forth the amount of stranded costs, if any, the board has determined an electric public utility is eligible to recover and collect in accordance with the standards set forth in section 13 of P.L.1999, c.23 (C.48:3-61) and the recovery mechanisms therefor;

“Thermal efficiency” means the useful electric energy output of a facility, plus the useful thermal energy output of the facility, expressed as a percentage of the total energy input to the facility;

“Transition bond charge” means a charge, expressed as an amount per kilowatt hour, that is authorized by and imposed on electric public utility ratepayers pursuant to a bondable stranded costs rate order, as modified at any time pursuant to the provisions of P.L.1999, c.23 (C.48:3-49 et al.);

“Transition bonds” means bonds, notes, certificates of participation or beneficial interest or other evidences of indebtedness or ownership issued pursuant to an indenture, contract or other agreement of an electric public utility or a financing entity, the proceeds of which are used, directly or indirectly, to recover, finance or refinance bondable stranded costs and which are, directly or indirectly, secured by or payable from bondable transition property. References in P.L.1999, c.23 (C.48:3-49 et al.) to principal, interest, and acquisition or redemption premium with respect to transition bonds which are issued in the form of certificates of participation or beneficial interest or other evidences of ownership shall refer to the comparable payments on such securities;

“Transition period” means the period from August 1, 1999 through July 31, 2003;

“Transmission and distribution system” means, with respect to an electric public utility, any facility or equipment that is used for the transmission, distribution or delivery of electricity to the customers of the electric public utility including, but not limited to, the land, structures, meters, lines, switches and all other appurtenances thereof and thereto, owned or controlled by the electric public utility within this State; and

“Universal service” means any service approved by the board with the purpose of assisting low-income residential customers in obtaining or retaining electric generation or delivery service.2

(cf: P.L.2011, c.9, s.2)

REPLACE SECTION 1 TO READ:

2[1.] 2.2 Section 38 of P.L.1999, c.23 (C.48:3-87) is amended to read as follows:

38. a. The board shall require an electric power supplier or basic generation service provider to disclose on a customer’s bill or on customer contracts or marketing materials, a uniform, common set of information about the environmental characteristics of the energy purchased by the customer, including, but not limited to:

(1) Its fuel mix, including categories for oil, gas, nuclear, coal, solar, hydroelectric, wind and biomass, or a regional average determined by the board;

(2) Its emissions, in pounds per megawatt hour, of sulfur dioxide, carbon dioxide, oxides of nitrogen, and any other pollutant that the board may determine to pose an environmental or health hazard, or an emissions default to be determined by the board; and

(3) Any discrete emission reduction retired pursuant to rules and regulations adopted pursuant to P.L.1995, c.188.

b. Notwithstanding any provisions of the “Administrative Procedure Act,” P.L.1968, c.410 (C.52:14B-1 et seq.) to the contrary, the board shall initiate a proceeding and shall adopt, in consultation with the Department of Environmental Protection, after notice and opportunity for public comment and public hearing, interim standards to implement this disclosure requirement, including, but not limited to:

(1) A methodology for disclosure of emissions based on output pounds per megawatt hour;

(2) Benchmarks for all suppliers and basic generation service providers to use in disclosing emissions that will enable consumers to perform a meaningful comparison with a supplier’s or basic generation service provider’s emission levels; and

(3) A uniform emissions disclosure format that is graphic in nature and easily understandable by consumers. The board shall periodically review the disclosure requirements to determine if revisions to the environmental disclosure system as implemented are necessary.

Such standards shall be effective as regulations immediately upon filing with the Office of Administrative Law and shall be effective for a period not to exceed 18 months, and may, thereafter, be amended, adopted or readopted by the board in accordance with the provisions of the “Administrative Procedure Act.”

c. (1) The board may adopt, in consultation with the Department of Environmental Protection, after notice and opportunity for public comment, an emissions portfolio standard applicable to all electric power suppliers and basic generation service providers, upon a finding that:

(a) The standard is necessary as part of a plan to enable the State to meet federal Clean Air Act or State ambient air quality standards; and

(b) Actions at the regional or federal level cannot reasonably be expected to achieve the compliance with the federal standards.

(2) By July 1, 2009, the board shall adopt, pursuant to the “Administrative Procedure Act,” P.L.1968, c.410 (C.52:14B-1 et seq.), a greenhouse gas emissions portfolio standard to mitigate leakage or another regulatory mechanism to mitigate leakage applicable to all electric power suppliers and basic generation service providers that provide electricity to customers within the State. The greenhouse gas emissions portfolio standard or any other regulatory mechanism to mitigate leakage shall:

(a) Allow a transition period, either before or after the effective date of the regulation to mitigate leakage, for a basic generation service provider or electric power supplier to either meet the emissions portfolio standard or other regulatory mechanism to mitigate leakage, or to transfer any customer to a basic generation service provider or electric power supplier that meets the emissions portfolio standard or other regulatory mechanism to mitigate leakage. If the transition period allowed pursuant to this subparagraph occurs after the implementation of an emissions portfolio standard or other regulatory mechanism to mitigate leakage, the transition period shall be no longer than three years; and

(b) Exempt the provision of basic generation service pursuant to a basic generation service purchase and sale agreement effective prior to the date of the regulation.

Unless the Attorney General or the Attorney General’s designee determines that a greenhouse gas emissions portfolio standard would unconstitutionally burden interstate commerce or would be preempted by federal law, the adoption by the board of an electric energy efficiency portfolio standard pursuant to subsection g. of this section, a gas energy efficiency portfolio standard pursuant to subsection h. of this section, or any other enhanced energy efficiency policies to mitigate leakage shall not be considered sufficient to fulfill the requirement of this subsection for the adoption of a greenhouse gas emissions portfolio standard or any other regulatory mechanism to mitigate leakage.

d. Notwithstanding any provisions of the “Administrative Procedure Act,” P.L.1968, c.410 (C.52:14B-1 et seq.) to the contrary, the board shall initiate a proceeding and shall adopt, after notice, provision of the opportunity for comment, and public hearing, renewable energy portfolio standards that shall require:

(1) that two and one-half percent of the kilowatt hours sold in this State by each electric power supplier and each basic generation service provider be from Class I or Class II renewable energy sources;

(2) beginning on January 1, 2001, that one-half of one percent of the kilowatt hours sold in this State by each electric power supplier and each basic generation service provider be from Class I renewable energy sources. The board shall increase the required percentage for Class I renewable energy sources so that by January 1, 2006, one percent of the kilowatt hours sold in this State by each electric power supplier and each basic generation service provider shall be from Class I renewable energy sources and shall additionally increase the required percentage for Class I renewable energy sources by one-half of one percent each year until January 1, 2012, when four percent of the kilowatt hours sold in this State by each electric power supplier and each basic generation service provider shall be from Class I renewable energy sources.

An electric power supplier or basic generation service provider may satisfy the requirements of this subsection by participating in a renewable energy trading program approved by the board in consultation with the Department of Environmental Protection; 2and2

(3) that the board establish a multi-year schedule, applicable to each electric power supplier or basic generation service provider in this State, beginning with the one-year period commencing on June 1, 2010, and continuing for each subsequent one-year period up to and including, the one-year period commencing on 1[June 1, 2025] 2[June 1, 20241] June 1, 20302, that requires suppliers or providers to purchase at least the following number of kilowatt-hours from solar electric power generators 2connected to the distribution system2 in this State:

EY 2011 306 Gigawatthours (Gwhrs)

EY 2012 442 Gwhrs

1[EY 2013 596 Gwhrs

EY 2014 772 Gwhrs

EY 2015 965 Gwhrs

EY 2016 1,150 Gwhrs

EY 2017 1,357 Gwhrs

EY 2018 1,591 Gwhrs

EY 2019 1,858 Gwhrs

EY 2020 2,164 Gwhrs

EY 2021 2,518 Gwhrs

EY 2022 2,928 Gwhrs

EY 2023 3,433 Gwhrs

EY 2024 3,989 Gwhrs

EY 2025 4,610 Gwhrs

EY 2026 5,316 Gwhrs

EY 2027]

2[EY 2013 772 G whrs

EY 2014 965 Gwhrs

EY 2015 1,150 Gwhrs

EY 2016 1,357 Gwhrs

EY 2017 1,591 Gwhrs

EY 2018 1,858 Gwhrs

EY 2019 2,164 Gwhrs

EY 2020 2,518 Gwhrs

EY 2021 2,928 Gwhrs

EY 2022 3,433 Gwhrs

EY 2023 3,989 Gwhrs

EY 2024 4,610 Gwhrs

EY 2025 5,316 Gwhrs

EY 20261]

EY2013 1,020 Gwhrs

EY2014 1,264 Gwhrs

EY2015 1,450 Gwhrs

EY2016 1,680 Gwhrs

EY2017 1,987 Gwhrs

EY2018 2,180 Gwhrs

EY2019 2,368 Gwhrs

EY2020 2,510 Gwhrs

EY2021 2,709.658 Gwhrs

EY2022 2,929.164 Gwhrs

EY2023 3,166.451 Gwhrs

EY2024 3,422.96 Gwhrs

EY2025 3,700.249 Gwhrs

EY2026 4,000 Gwhrs

EY 2027 4,200 Gwhrs

EY 2028 4,400 Gwhrs

EY 2029 4,600 Gwhrs

EY 2030 4,800 Gwhrs

EY20312 , and for every energy year thereafter, at least 2[5,316] 5,0002 Gwhrs per energy year to reflect an increasing number of kilowatt-hours to be purchased by suppliers or providers from solar electric power generators 2connected to the distribution system2 in this State, and to establish a framework within which suppliers and providers shall purchase at least 2[2,518] 2,709.6582 Gwhrs in the energy year 1[2021] 2[20201] 20212 and 2[5,316] 5,0002 Gwhrs in the energy year 1[2026] 2[20251] 20312 from solar electric power generators 2connected to the distribution system2 in this State, provided, however, that 2:

(a) when the board establishes the multi-year schedule and framework for annual Statewide Gwhr requirements for Energy Years 2011 through 2031 required in paragraph (3) of subsection d. of this section, and any requirements for Energy Years thereafter, the board ensures that each such annual Statewide Gwhr requirement annually requires that a percentage of the kilowatt-hours sold in this State by each provider and supplier be purchased from solar electric power generators connected to the distribution system in this State, based on the percentage relationship that each annual Statewide Gwhr requirement has to the board’s weather-normalized projection of the number of kilowatt hours to be sold in this State by all providers and suppliers for each Energy Year, subject to adjustment pursuant to subparagraph (d) of paragraph (3) of this subsection;

(b)2 the number of solar kilowatt-hours required to be purchased by each supplier or provider, when expressed as a percentage of the total number of solar kilowatt-hours purchased in this State, shall be equivalent to each supplier’s or provider’s proportionate share of the total number of kilowatt-hours 2projected by the board to be2 sold in this State by all suppliers and providers 2;

(c) the board shall determine an appropriate period of no less than 120 days following the end of an Energy Year prior to which a provider or supplier must demonstrate compliance with the annual renewable portfolio standard;

(d) within 45 days following the period set forth in subparagraph (c) of paragraph (3) of this subsection, to the extent that the board determines that the solar Gwhrs purchased in an Energy Year by all providers and suppliers pursuant to the percentage established by the board were less than the annual Statewide Gwhr requirement specified in paragraph (3) of this subsection, the board shall add the Gwhrs that constitute the shortfall to the annual Gwhr requirement for the Energy Year that is three years after the Energy Year in which the shortfall occurs, and use the increased Gwhr requirement to recalculate the percentage of kilowatt-hours that each provider and supplier sells that are required to be purchased from solar electric power generators connected to the distribution system in this State for that future Energy Year; and

(e) providers and suppliers shall comply with the provisions of paragraph (3) of this subsection by complying with the board’s percentage requirements established pursuant to subparagraphs (a) through (d) of paragraph (3) of this subsection.

(f) No more than 24 months following the date of enactment of P.L. , c. (C. ) (pending before the Legislature as this bill), the board shall complete a proceeding to investigate approaches to mitigate excessive SREC price and solar development volatility and prepare and submit a report to the Legislature, detailing its findings and recommendations pursuant to P.L.1991, c.164 (C.52:14-19.1). As part of the proceeding, the board shall evaluate other techniques used nationally and internationally2 .

The solar renewable portfolio standards requirements in paragraph (3) of this subsection shall automatically increase by 20% for the remainder of the schedule in the event that the following two conditions are met: (a) the number of SRECs generated 2or available for sale2 meets or exceeds the requirement for three consecutive reporting years, starting with energy year 2013; and (b) the average SREC price for all SRECs purchased by entities with renewable energy portfolio standards obligations has decreased in the same three consecutive reporting years. The board shall exempt providers’ existing supply contracts that are: (a) effective prior to the date of 2[P.L.2009, c.289] enactment of P.L. , c. (C. ) (pending before the Legislature as this bill)2; or (b) effective prior to any future increase in the solar renewable portfolio standard beyond the multi-year schedule established in paragraph (3) of this subsection. This exemption shall apply to the number of SRECs that exceeds the number mandated by the solar renewable portfolio standards requirements that were in effect on the date that the providers executed their existing supply contracts. This limited exemption for providers’ existing supply contracts shall not be construed to lower the Statewide solar purchase requirements set forth in paragraph (3) of this subsection. Such incremental new requirements shall be distributed over the electric power suppliers and providers not subject to the existing supply contract exemption until such time as existing supply contracts expire and all suppliers are subject to the new requirement 2in a manner that is competitively neutral between providers as a whole and suppliers, such that non-exempt providers are assigned the requirements that would have otherwise been assigned to the exempt providers2 .

An electric power supplier or basic generation service provider may satisfy the requirements of this subsection by participating in a renewable energy trading program approved by the board in consultation with the Department of Environmental Protection, or compliance with the requirements of this subsection may be demonstrated to the board by suppliers or providers through the purchase of SRECs.

The renewable energy portfolio standards adopted by the board pursuant to paragraphs (1) and (2) of this subsection shall be effective as regulations immediately upon filing with the Office of Administrative Law and shall be effective for a period not to exceed 18 months, and may, thereafter, be amended, adopted or readopted by the board in accordance with the provisions of the “Administrative Procedure Act.”

The renewable energy portfolio standards adopted by the board pursuant to paragraph (3) of this subsection shall be effective as regulations immediately upon filing with the Office of Administrative Law and shall be effective for a period not to exceed 30 months after such filing, and shall, thereafter, be amended, adopted or readopted by the board in accordance with the “Administrative Procedure Act”; and

(4) within 180 days after the date of enactment of P.L.2010, c.57 (C.48:3-87.1 et al.), that the board establish an offshore wind renewable energy certificate program to require that a percentage of the kilowatt hours sold in this State by each electric power supplier and each basic generation service provider be from offshore wind energy in order to support at least 1,100 megawatts of generation from qualified offshore wind projects.

The percentage established by the board pursuant to this paragraph shall serve as an offset to the renewable energy portfolio standard established pursuant to paragraphs (1) and (2) of this subsection and shall reduce the corresponding Class I renewable energy requirement.

The percentage established by the board pursuant to this paragraph shall reflect the projected OREC production of each qualified offshore wind project, approved by the board pursuant to section 3 of P.L.2010, c.57 (C.48:3-87.1), for twenty years from the commercial operation start date of the qualified offshore wind project which production projection and OREC purchase requirement, once approved by the board, shall not be subject to reduction.

An electric power supplier or basic generation service provider shall comply with the OREC program established pursuant to this paragraph through the purchase of offshore wind renewable energy certificates at a price and for the time period required by the board. In the event there are insufficient offshore wind renewable energy certificates available, the electric power supplier or basic generation service provider shall pay an offshore wind alternative compliance payment established by the board. Any offshore wind alternative compliance payments collected shall be refunded directly to the ratepayers by the electric public utilities.

The rules established by the board pursuant to this paragraph shall be effective as regulations immediately upon filing with the Office of Administrative Law and shall be effective for a period not to exceed 18 months, and may, thereafter, be amended, adopted or readopted by the board in accordance with the provisions of the “Administrative Procedure Act,” P.L.1968, c.410 (C.52:14B-1 et seq.).

e. Notwithstanding any provisions of the “Administrative Procedure Act,” P.L.1968, c.410 (C.52:14B-1 et seq.) to the contrary, the board shall initiate a proceeding and shall adopt, after notice, provision of the opportunity for comment, and public hearing:

(1) net metering standards for electric power suppliers and basic generation service providers. The standards shall require electric power suppliers and basic generation service providers to offer net metering at non-discriminatory rates to industrial, large commercial, residential and small commercial customers, as those customers are classified or defined by the board, that generate electricity, on the customer’s side of the meter, using a Class I renewable energy source, for the net amount of electricity supplied by the electric power supplier or basic generation service provider over an annualized period. Systems of any sized capacity, as measured in watts, are eligible for net metering. If the amount of electricity generated by the customer-generator, plus any kilowatt hour credits held over from the previous billing periods, exceeds the electricity supplied by the electric power supplier or basic generation service provider, then the electric power supplier or basic generation service provider, as the case may be, shall credit the customer-generator for the excess kilowatt hours until the end of the annualized period at which point the customer-generator will be compensated for any remaining credits or, if the customer-generator chooses, credit the customer-generator on a real-time basis, at the electric power supplier’s or basic generation service provider’s avoided cost of wholesale power or the PJM electric power pool’s real-time locational marginal pricing rate, adjusted for losses, for the respective zone in the PJM electric power pool. Alternatively, the customer-generator may execute a bilateral agreement with an electric power supplier or basic generation service provider for the sale and purchase of the customer-generator’s excess generation. The customer-generator may be credited on a real-time basis, so long as the customer-generator follows applicable rules prescribed by the PJM electric power pool for its capacity requirements for the net amount of electricity supplied by the electric power supplier or basic generation service provider 2[. The board may authorize an electric power supplier or basic generation service provider to cease offering net metering whenever the total rated generating capacity owned and operated by net metering customer-generators Statewide equals 2.5 percent of the State's peak electricity demand]2;

(2) safety and power quality interconnection standards for Class I renewable energy source systems used by a customer-generator that shall be eligible for net metering.

Such standards or rules shall take into consideration the goals of the New Jersey Energy Master Plan, applicable industry standards, and the standards of other states and the Institute of Electrical and Electronic Engineers. The board shall allow electric public utilities to recover the costs of any new net meters, upgraded net meters, system reinforcements or upgrades, and interconnection costs through either their regulated rates or from the net metering customer-generator; and

(3) credit or other incentive rules for generators using Class I renewable energy generation systems that connect to New Jersey’s electric public utilities’ distribution system but who do not net meter.

Such rules shall require the board or its designee to issue a credit or other incentive to those generators that do not use a net meter but otherwise generate electricity derived from a Class I renewable energy source and to issue an enhanced credit or other incentive, including, but not limited to, a solar renewable energy credit, to those generators that generate electricity derived from solar technologies.

Such standards or rules shall be effective as regulations immediately upon filing with the Office of Administrative Law and shall be effective for a period not to exceed 18 months, and may, thereafter, be amended, adopted or readopted by the board in accordance with the provisions of the “Administrative Procedure Act.”

f. The board may assess, by written order and after notice and opportunity for comment, a separate fee to cover the cost of implementing and overseeing an emission disclosure system or emission portfolio standard, which fee shall be assessed based on an electric power supplier’s or basic generation service provider’s share of the retail electricity supply market. The board shall not impose a fee for the cost of implementing and overseeing a greenhouse gas emissions portfolio standard adopted pursuant to paragraph (2) of subsection c. of this section, the electric energy efficiency portfolio standard adopted pursuant to subsection g. of this section, or the gas energy efficiency portfolio standard adopted pursuant to subsection h. of this section.

g. The board may adopt, pursuant to the “Administrative Procedure Act,” P.L.1968, c.410 (C.52:14B-1 et seq.), an electric energy efficiency portfolio standard that may require each electric public utility to implement energy efficiency measures that reduce electricity usage in the State by 2020 to a level that is 20 percent below the usage projected by the board in the absence of such a standard. Nothing in this section shall be construed to prevent an electric public utility from meeting the requirements of this section by contracting with another entity for the performance of the requirements.

h. The board may adopt, pursuant to the “Administrative Procedure Act,” P.L.1968, c.410 (C.52:14B-1 et seq.), a gas energy efficiency portfolio standard that may require each gas public utility to implement energy efficiency measures that reduce natural gas usage for heating in the State by 2020 to a level that is 20 percent below the usage projected by the board in the absence of such a standard. Nothing in this section shall be construed to prevent a gas public utility from meeting the requirements of this section by contracting with another entity for the performance of the requirements.

i. After the board establishes a schedule of solar kilowatt-hour sale or purchase requirements pursuant to paragraph (3) of subsection d. of this section, the board may initiate subsequent proceedings and adopt, after appropriate notice and opportunity for public comment and public hearing, increased minimum solar kilowatt-hour sale or purchase requirements, provided that the board shall not reduce previously established minimum solar kilowatt-hour sale or purchase requirements, or otherwise impose constraints that reduce the requirements by any means.

j. The board shall 2[determine an appropriate level of solar alternative compliance payment, and establish a 15-year solar alternative compliance payment schedule, that permits] permit2 each supplier or provider to submit an SACP to comply with the solar electric generation requirements of paragraph (3) of subsection d. of this section. 2The value of the SACP for each fiscal year shall be at least:

EY 2013 $437

EY 2014 $422

EY 2015 $407

EY 2016 $393

EY 2017 $377

EY 2018 $362

EY 2019 $347

EY 2020 $334

EY 2021 $320

EY 2022 $307

EY 2023 $298

EY 2024 $289

EY 2025 $281

EY 2026 $272

EY 2027 $270

EY 2028 $265

EY 2029 $260

EY2030 $255

EY2031 $2502

The board may initiate subsequent proceedings and adopt, after appropriate notice and opportunity for public comment and public hearing, an increase in solar alternative compliance payments2[, provided that the] . The board shall initiate a proceeding and may adopt, after appropriate notice and opportunity for public comment and public hearing, an increase in solar alternative compliance payments if the 30 percent federal business energy tax credit available pursuant to 26 U.S.C. s.48 is not extended by June 30, 2015. The2 board shall not reduce previously established levels of solar alternative compliance payments, nor shall the board provide relief from the obligation of payment of the SACP by the electric power suppliers or basic generation service providers in any form. Any SACP payments collected shall be refunded directly to the ratepayers by the electric public utilities.

k. The board [may allow] shall require electric public utilities to offer long-term contracts through a competitive process and other means of financing, including but not limited to loans, for the purchase of SRECs and the resale of SRECs to suppliers or providers or others, provided that after such contracts have been approved by the board, the board’s approvals shall not be modified by subsequent board orders. On and after the effective date of P.L. , c. (C. ) (pending before the Legislature as this bill), the number of SRECs offered under this subsection shall include solar electric power generators of 2MW or less and shall comprise at least 30 percent of the annual Gwhrs under the solar renewable energy portfolio requirements under subsection d. of this section to assist in managing the marketplace until such time as the board determines that such requirements are no longer necessary to support development of the solar industry in this State. Of the SRECs approved by the board and offered under this subsection by electric public utilities, no more than 20 percent shall be set aside for residential and small commercial projects of 20 kilowatts or less, and such SRECs shall be offered through a similar competitive process.

l. The board shall implement its responsibilities under the provisions of this section in such a manner as to:

(1) place greater reliance on competitive markets, with the explicit goal of encouraging and ensuring the emergence of new entrants that can foster innovations and price competition;

(2) maintain adequate regulatory authority over non-competitive public utility services;

(3) consider alternative forms of regulation in order to address changes in the technology and structure of electric public utilities;

(4) promote energy efficiency and Class I renewable energy market development, taking into consideration environmental benefits and market barriers;

(5) make energy services more affordable for low and moderate income customers;

(6) attempt to transform the renewable energy market into one that can move forward without subsidies from the State or public utilities;

(7) achieve the goals put forth under the renewable energy portfolio standards;

(8) promote the lowest cost to ratepayers; and

(9) allow all market segments to participate.

m. The board shall ensure the availability of financial incentives under its jurisdiction, including, but not limited to, long-term contracts, loans, SRECs, or other financial support, to ensure market diversity, competition, and appropriate coverage across all ratepayer segments, including, but not limited to, residential, commercial, industrial, non-profit, farms, schools, and public entity customers.

n. For projects which are owned, or directly invested in, by a public utility pursuant to section 13 of P.L.2007, c.340 (C.48:3-98.1), the board shall determine the number of SRECs with which such projects shall be credited; and in determining such number the board shall ensure that the market for SRECs does not detrimentally affect the development of non-utility solar projects and shall consider how its determination may impact the ratepayers.

o. The board, in consultation with the Department of Environmental Protection, electric public utilities, the Division of Rate Counsel in, but not of, the Department of the Treasury, affected members of the solar energy industry, and relevant stakeholders, shall periodically consider increasing the renewable energy portfolio standards beyond the minimum amounts set forth in subsection d. of this section, taking into account the cost impacts and public benefits of such increases including, but not limited to:

(1) reductions in air pollution, water pollution, land disturbance, and greenhouse gas emissions;

(2) reductions in peak demand for electricity and natural gas, and the overall impact on the costs to customers of electricity and natural gas;

(3) increases in renewable energy development, manufacturing, investment, and job creation opportunities in this State; and

(4) reductions in State and national dependence on the use of fossil fuels.

p. Class I RECs 2and ORECS2 shall be eligible for use in renewable energy portfolio standards compliance in the energy year in which they are generated, and for the following two energy years. SRECs 2[and ORECs]2 shall be eligible for use in renewable energy portfolio standards compliance in the energy year in which they are generated, and for the following 2[two] four2 energy years.

1[q. Notwithstanding any provisions of the “Administrative Procedure Act,” P.L.1968, c.410 (C.52:14B-1 et seq.) to the contrary, the board shall adopt, after notice, provision of the opportunity for comment, and pubic hearing, regulations that require contracts entered into by non-utility load serving entities for the purchase of SRECs after the effective date of P.L. , c. (C. ) (pending before the Legislature this bill) to be long-term contracts that extend for a term of 15 years or longer.

As used in this subsection, a "non-utility load serving entity" means any entity, other than an electric public utility, or the duly designated agent of such an entity, that serves the electric power needs of end-users within the PJM region, and that has been granted the authority or has an obligation pursuant to State or local law, regulation, or franchise to sell electric power to end-users within the PJM electric power pool region.]1

2q. Notwithstanding any provisions of the “Administrative Procedure Act,” P.L.1968, c.410 (C.52:14B-1 et seq.) to the contrary, the board shall initiate a proceeding to evaluate energy efficiency portfolio standards, and after notice, provision of the opportunity for comment, and public hearing, may adopt such competitively neutral energy efficiency portfolio standards that require each electric power supplier and each basic generation service provider to purchase a specified number of EE certificates from eligible energy efficiency and energy conservation programs. The board shall permit an electric power supplier or basic generation service provider to satisfy the requirements of this subsection by participating in an energy trading program approved by the board in consultation with the Department of Environmental Protection.

The board shall exempt suppliers and providers’ existing supply contracts that are effective prior to the date of a board decision approving a rule adoption pursuant to this subsection. Any purchases that would have otherwise been required from exempt suppliers or providers in the absence of such exemption may be distributed over suppliers and providers not subject to the existing contract exemption until such time as existing supply contracts expire and all suppliers and providers are subject to the new requirement.

r. A proposed solar facility that is greater than 10 megawatts in capacity and either not net metered or not an on-site generation facility, may be considered “connected to the distribution system” only upon designation as such by the board, after notice to the public and opportunity for public comment or hearing. A proposed solar facility seeking board designation as “connected to the distribution system” shall submit an application to the board that includes for the proposed facility: the nameplate capacity; the estimated energy and number of SRECs to be produced and sold per year; the estimated annual rate impact on ratepayers; the estimated capacity of the generator as defined by PJM for sale in the PJM capacity market; the point of interconnection; the total acreage and location; the current land use designation of the property; and the type of solar technology to be used.

The board shall approve the designation of the proposed solar facility as “connected to the distribution system” if the board determines that:

1) the SRECs forecasted to be produced by the facility do not have a detrimental impact on the SREC market or on the appropriate development of solar power in the State;

2) the loss of tillable acreage that would result from the approval of the designation of the proposed facility, together with the tillable acreage of all other facilities approved pursuant to this subsection, would be a loss of less than two percent of the total tillable acres of farmland in the State on the date of enactment of P.L. , c. (C. ) (pending before the Legislature as this bill), pursuant to information provided by the State Department of Agriculture; and

3) the impact of the designation on electric rates and economic development is beneficial.

The board shall act within 90 days of its receipt of a completed application for designation of a solar facility as “connected to the distribution system,” to either approve or disapprove such an application. If the board fails to either approve or disapprove such an application within 90 days, the application shall be deemed approved, and the solar facility submitting the application shall be considered “connected to the distribution system.” If the proposed solar facility does not commence commercial operations within two years following the date of the designation by the board pursuant to this subsection, the designation of the facility as “connected to the distribution system” shall be deemed to be null and void, and the facility shall thereafter be considered not “connected to the distribution system.”

Notwithstanding the provisions of this subsection, a solar facility for which a System Impact Study by PJM was issued prior to March 31, 2011, shall be considered “connected to the distribution system.” If such solar facility does not commence commercial operations within two years following the date of enactment of P.L. , c. (C. ) (pending before the Legislature as this bill), the designation of the facility as “connected to the distribution system” shall be deemed to be null and void, and the facility shall thereafter be considered not “connected to the distribution system.”

Notwithstanding the foregoing provisions of this subsection, a solar facility that would otherwise be subject to the provisions of this subsection, but that is located on a closed landfill or quarry, shall be considered “connected to the distribution system” and shall not require such designation by the board.

s. No more than 180 days after the date of enactment of P.L. , c. (C. ) (pending before the Legislature as this bill), the board shall complete a proceeding to establish a registration program. The registration program shall require solar projects greater than one megawatt of nameplate capacity to make periodic milestone filings with the board in a manner and at such times as determined by the board to provide full disclosure and transparency regarding the overall level of development and construction activity of solar projects statewide. The registration program shall also include a registration program filing fee, which shall be $2,500 for each facility with a nameplate capacity below five megawatts and an additional fee of $2,500 for every megawatt in excess of five megawatts of nameplate capacity. The registration program filing fee shall be reimbursed to the registrant in full upon the proposed solar project entering commercial production.2

(cf: P.L.2010, c.57, s.2)

RENUMBER SECTION 2 AS SECTION 3

REPLACE SYNOPSIS TO READ:

Makes changes to solar renewable energy programs and requirements, concerns energy efficiency and renewable energy requirements.
 
More on Flett Exchange:
 
Flett Exchange is a leading environmental exchange and brokerage firm. Our online trading platform brings transparency, price discovery, and liquidity to Solar Renewable Energy Certificates (SRECs). Our knowledgeable staff is also available to assist you in selling your SRECs for you. Over 3,500 active clients utilize Flett Exchange to negotiate the price, quantity, and details of SRECs in a secure and seamless online trading platform. Upon each SREC transaction Flett Exchange remits immediate payment to our sellers. Flett Exchange operates SREC markets in NJ, PA, DE, MD, OH, CT, MA, and DC and supported by trained solar professionals with specialized knowledge and proven experience.
 
Flett Exchange also brokers bilateral long-term SREC contracts between qualified counterparties. Flett Exchange buyers and sellers can secure price, quantity, and terms of SREC contracts 1-5 years in duration. Our stringent vetting process ensures that quality solar projects are presented to the market in a skillful manner. Buyers and sellers utilize Flett Exchange for long-term SREC contracts gain direct access to large pools of SRECs, while mitigating risk and locking-in profits. Please visit www.flettexchange.com to learn more about our services. 201-209-0324

Prices for New Jersey SRECs have appreciated in the last month in anticipation of potential changes in legislation. The legislation may require electric companies to procure more SRECs. The State of New Jersey has experienced a tremendous influx of investment in solar in the last twelve months. This investment has outstripped the requirements for electric companies to purchase SRECs for the next 2 years by an estimated 40%. The SREC market is designed to protect the ratepayer from an overinvestment of solar and has dropped accordingly.

The sale was conducted on the Flett Exchange trading platform. Public officials choose to utilize the Flett Exchange auctions to ensure that the price they receive for SRECs is competitive and transparent. The sales are all conducted on the Flett Exchange Internet Platform and is viewable to the public in real-time during the sale. Flett Exchange advertises the sales to all of the electric companies that are required by law to procure SRECs for renewable portfolio standards.

Town Managers can schedule to sell their SRECs in an easy and transparent fashion by filling out the Public Auction Request form or calling us at our Jersey City office.

201-209-0234

http://www.flettexchange.com/index.php?page=schedule

Not only is it transparent, it is FREE for sellers! Flett Exchange charges a nominal $5 per SREC fee to the buyers.

More on Flett Exchange:

   
     Flett Exchange is a leading environmental exchange and brokerage firm. Our online trading platform brings transparency, price discovery, and liquidity to Solar Renewable Energy Certificates (SRECs). Our knowledgeable staff is also available to assist you in selling your SRECs for you. Over 3,500 active clients utilize Flett Exchange to negotiate the price, quantity, and details of SRECs in a secure and seamless online trading platform. Upon each SREC transaction Flett Exchange remits immediate payment to our sellers. Flett Exchange operates SREC markets in NJ, PA, DE, MD, OH, CT, MA, and DC and supported by trained solar professionals with specialized knowledge and proven experience.
 
     Flett Exchange also brokers bilateral long-term SREC contracts between qualified counterparties. Flett Exchange buyers and sellers can secure price, quantity, and terms of SREC contracts 1-5 years in duration. Our stringent vetting process ensures that quality solar projects are presented to the market in a skillful manner. Buyers and sellers utilize Flett Exchange for long-term SREC contracts gain direct access to large pools of SRECs, while mitigating risk and locking-in profits. Please visit www.flettexchange.com to learn more about our services. 201-209-0324

Flett Exchange does not want to convey false signals to the market in Massachusetts by posting settlements with very little volume behind the trading. We are very critical of the “floor” mechanism since it is untested. With the current costs for installations and levels of incentives, long term offers in the bilateral market long term market are significantly below the $300 ($285 after expenses). Ten year offers by developers have been shown $100 below the “floor” in recent months.

The energy master plan, released last week, suggested increasing the amount of SRECs purchased by electricity providers to correct the recent overbuild and subsequent dropping SREC values. The solar legislation that is expected to be introduced this month will most likely mandate an increase in SRECs purchased.The state legislature and Governor will have to approve it first. It is expected that if the legislation increases costs too much it will not be signed by the Governor.

We see three potential scenarios:

1. No Legislation: The SREC market will most likely drop under $150 and stay low for years unless there are new laws in the future.
2. Legislation with slight increase in RPS: SREC prices may stabilize between $250 and $350 with potential spikes higher
3. Legislation with large increase in RPS: SREC prices will most likely rise to $400+ for current year

What you may want to do if you have SRECs to sell: 

1. If you don’t want to take the risk of the market dropping, sell now and take advantage of the $125 rise over August lows.
2. Place orders above the market to sell at levels $20 to $70 above the market to take advantage of a “pop” in the market that does not maintain momentum and later drop off.
3. If you think the legislation is going to be strong, wait for it to come out and try to maximize your profits if the market continues to rally.

Accelerate the RPS

 
     A temporary acceleration of the RPS would provide some interim relief for the current market in SRECs and an opportunity for the industry to adjust. This acceleration would require increasing the RPS over the next three years and reducing the outlier years of the RPS schedule to minimize the impact to ratepayers129. This should provide the foundation for the solar industry to continue to develop and receive SREC payments trading within a reasonable range and would facilitate a reduced SACP schedule.
 

Reduce the SACP

 
     In order to minimize the rate impact of RPS acceleration and reduce the cost burden borne by non-participants in New Jersey’s solar market, the State has initiated action to materially reduce the SACP. The efficacy of lower cost C&I programs coupled with the anticipated continued cost decline in installing solar PV support a step-down in the SACP levels through 2025.According to the CEEEP analysis, with SREC prices starting at $500/MWh and declining 2.5%every year, the cost of a new solar installation can be recouped in about five years for a C&Iproject of 10-1,000 kW, and in ten years for a residential or small commercial project of less than 10 kW.130There have been a number of proposals to modify the SACP schedule; within the industry, there’s general agreement that a reduction in the overall schedule is warranted to reflect the
Continuing downward trend in installed costs. The BPU will propose a new schedule following the release of the EMP.”
 
     Keep in mind that the EMP is JUST A PLAN! It takes legislation to implement the increase in the RPS and decrease the SACP. If, and when, a bill is passed in the New Jersey Legislature it still has to be signed into law by Governor Christie. This bill will have to be sensitive to ratepayer impact and if it overreaches there is a high probability that it will not be singed into law.
 

Beware of the Fine Print

 
     Solar industry insiders will most likely try to insert special perks in a bill like requirements for ratepayers to enter into long term SREC contracts. Long term SREC contracts have shifted all risk on ratepayers in the past while locking in profits for developers. ($475 10 year fixed rate contracts were prevalent). Mandated long term contracts will create risk free investing for new solar investors while the ratepayer and most current solar owners will suffer any future losses in an oversupply and if solar becomes cheaper during the next 10 years. Long term contracting decisions should be flexible and the decision as to how much of the market should benefit should rest with the Board of Public Utilities like it has in the past. This BPU decision making is best and can be used to promote land use issues and satisfy net benefits tests when siting solar.
 

Job Retention and Stable SREC Prices

 
     Adjustments like these advocated by the Christie Administration will sustain the investment in solar in New Jersey thus retain thousands of jobs associated with the installation of solar. In the absence of an adjustment it is estimated that the solar industry in New Jersey will have to contract for years (Job losses) before the current state mandates catch up. It makes sense to speed up development due to the significant drop in the installed cost of solar. This drop was not modeled to happen for at least another decade when the current solar legislation was passed in January of 2010. Business’s, homeowners, schools and municipalities that invested in solar in the last few years can expect supported SREC prices if a bill is introduced and signed by the Governor. Hopefully this will happen within the next month!
 

More on Flett Exchange:

   
     Flett Exchange is a leading environmental exchange and brokerage firm. Our online trading platform brings transparency, price discovery, and liquidity to Solar Renewable Energy Certificates (SRECs). Our knowledgeable staff is also available to assist you in selling your SRECs for you. Over 3,500 active clients utilize Flett Exchange to negotiate the price, quantity, and details of SRECs in a secure and seamless online trading platform. Upon each SREC transaction Flett Exchange remits immediate payment to our sellers. Flett Exchange operates SREC markets in NJ, PA, DE, MD, OH, CT, MA, and DC and supported by trained solar professionals with specialized knowledge and proven experience.
 
     Flett Exchange also brokers bilateral long-term SREC contracts between qualified counterparties. Flett Exchange buyers and sellers can secure price, quantity, and terms of SREC contracts 1-5 years in duration. Our stringent vetting process ensures that quality solar projects are presented to the market in a skillful manner. Buyers and sellers utilize Flett Exchange for long-term SREC contracts gain direct access to large pools of SRECs, while mitigating risk and locking-in profits. Please visit www.flettexchange.com to learn more about our services. 201-209-0324

 
     At the current pace of solar development, the New Jersey Solar Renewable Energy Credit SREC market is expected to produce an oversupply of SRECs for the upcoming year. The next energy year (June 2011 to May 2012) requires load serving entities (LSEâ??s) in New Jersey to purchase 442,000 SRECs for their compliance. We estimate that 490,000 to 590,000 SRECs will be created by NJ solar installations at the current rate of solar installations. The change proposed in the Bill will mop up the expected oversupply and keep the SREC prices stable. Without such a change the extra supply of SRECs may take 2 years to filter out of the market, and prices for SRECs will be so low that investors in solar in NJ will receive prices for SRECs much lower than expected. Solar development, one of the bright spots in the New Jersey Economy, may drop over 50% from the current pace of installs. SREC prices have already dropped in anticipation of the over-supply and are trading at $375for July 29th delivery. This is a significant drop from the current price of $599.63 which was July 6, 2011 settlement price on the Flett Exchange Internet trading platform. It would take a virtual halt in the rate of solar installs over a period of a year to bring the SREC market into a balanced supply-demand scenario. In the meantime SREC prices for spot and forward terms would remain under significant pressure.
 
     During the June 20th meeting of the Senate Telecommunications and Utilities Committee in Trenton Senator Bob Smith identified that the solar industry and regulators did not expect that the rate of solar installations would be so successful so quickly and potentially exceed the strong State mandates. This Bill is the type of preventive measure that is needed periodically in a program to reach long term goals of solar installations while maintaining confidence with solar investors. With a confident class of investors the ratepayer is more likely to benefit over the long term with clean solar energy at ever decreasing costs.
 
     As this bill works its way through the process, Governor Christie and the BPU will clearly have their say. It is a well known fact that the Administration would like to see the cost of solar brought down for the ratepayer. One should not expect support for a bill from the Governor that would just push SREC prices back up to the $600 level for years. We expect there to be a compromise required from the Governor in the form of lowering the established SACP from energy year 2013 to 2017 (this was hinted to in the revised energy master plan). The current defined SACP is in the High $500 to low $600 Range. A $100 drop would save ratepayers a potential $150,000,000 in energy year 2017 in the case of a short, undersupplied SREC market. Most solar investors that we speak to would accept this compromise in return for the accelerated growth and price support that would transpire with this Bill. Regardless of the recent tensions between Democrats and Republicans in Trenton, we believe that Governor Christie, BPU President Solomom, Senator Bob Smith and Assemblyman Chivakula will work this Bill to continue NJ on the path of more solar for New Jersey residents, businessâ??s and municipalities at lower costs to ratepayers.
 
     There was not support from the competitive electric suppliers for forcing long term contracts on them for SRECs. This long term contracting and shifting of development risk to other parties, be they ratepayers or electric suppliers, is advocated by certain sectors of the solar installers and development industry in New Jersey and was included in this Bill in its original form. Long term contracts were scrapped from the Bill. Long term, 15 year contracts would have transferred all of the risk of solar developers on electric suppliers which in turn would bring electric costs up for all ratepayers. Shifting risk from future solar developers to entities that do not benefit would create a split risk market that would disenfranchise those who already invested in solar.
 
     Michael Flett, President of Flett Exchange, spoke in favor of the bill in Trenton on June 20th in front of the Senate Environment and Energy Committee. He reiterated the need to increase the RPS to prevent a prolonged collapse in SRECs, spoke out against forcing long term contracts on competitive electric suppliers, and also brought up the benefits of a $100 SREC price floor as a future mechanism.
 
     New Jersey is in the right place at the right time with an established solar industry to take advantage of Federal incentives along with plummeting panel prices. The SREC market can take most of the credit as a mechanism. With proactive measures like this Bill with support by Christie, Solomon, Smith and Chivakula the benefits to investors and ratepayers can continue in a competitive fashion.
 

The Energy Year Basics:
 

1. The energy year runs from June to May (example: energy year 2011 SRECs represent power produced from the beginning of June 2010 to the end of May 2011.
2. Power providers in NJ must produce a compliance report on October 1st and at that time they must retire SRECs and/or make Solar Alternative Compliance Payments (SACP).
3. The time between June and October is called the true-up period. The true-up period gives the buyers enough time to get their count of SREC needs and either buy more or dispose of extra SRECs.
4. Sellers who have accumulated SRECs and not sold them during the year have a short amount of time to sell their SRECs.

 
Why are things different this year?
 

1. SREC markets are based on supply and demand. In all of the previous years in NJ the amount of solar installed was far short of the State mandates. The result was high and stable SREC prices. This is about to change.
2. These high prices attract investment. Last year (energy year 2011) there was potentially enough investment in NJ solar to meet mandates. The next year (energy year 2012) appears to have enough and maybe even too much solar investment.
3. Prices for SRECs for future years have dropped 38% in the last few months.

 
What should I do if I have SRECs?
 

1. If you have SRECs in your GATS account you need to sell them now and sell them again at the end of this month when the last ones are posted in GATS. Don’t try for higher prices. In the past, sellers have been able to get a few extra dollars by holding out until the end. We don’t think the risk/reward is there this year. Trying to get $650 when the best bid is $645 is not wise. If prices start to drop just accept the bid and go on.
2. The last SRECs that can be used by the buyers for October’s compliance will be May 2011 generation. These SRECs will be available for transfer in GATS at the end of June.
3. Flett Exchange customers can log onto the Flett Exchange trading platform to lock in their prices 24 hours a day 7 days a week. You can also call our trading desk and we will lock in the price for you. Don’t just transfer SRECs to “Flett Exchange llc” on GATS without first locking in your price! Call us or trade them on our trading platform.

 
What is going to happen to prices in the future?
 
Prices for energy year 2012 SRECs are trading in the high $300s for future delivery. These prices are expected to go up and down based on the level of future solar installations. If homeowners, businesses, schools, municipalities and PPA firms continue to develop solar in excess of the State mandates then the SREC prices will continue to go down in price. If solar development throttles back the prices will stabilize. Prices can also stabilize based on Board of Public Utility rulemakings and future legislation changes.
 
More on Flett Exchange:
 
Flett Exchange is largest volume SREC exchange and brokerage firm. Our online trading platform brings transparency, price discovery, and liquidity to Solar Renewable Energy Certificates (SRECs). Over 2,800 active clients utilize Flett Exchange to negotiate the price, quantity, and details of SRECs in a secure and seamless online trading platform. Upon each SREC transaction Flett Exchange remits immediate payment to our sellers (its simple sell a SREC and receive a check!) Flett Exchange operates SREC markets in NJ, PA, DE, MD, OH, CT, MA, and DC and supported by trained solar professionals with specialized knowledge and proven experience.
 
Flett Exchange brokers bilateral long-term SREC contracts between qualified counterparties. Flett Exchange buyers and sellers can secure price, quantity, and terms of SREC contracts 1-5 years in duration. Our stringent vetting process ensures that quality solar projects are presented to the market in a skillful manner. Buyers and sellers utilize Flett Exchange for long-term SREC contracts gain direct access to large pools of SRECs, while mitigating risk and locking-in profits. Please visit www.flettexchange.com to learn more about our services.

More on Flett Exchange:

Flett Exchange is a leading environmental exchange and brokerage firm. Our online trading platform brings transparency, price discovery, and liquidity to Solar Renewable Energy Certificates (SRECs). Over 2,000 active clients utilize Flett Exchange to negotiate the price, quantity, and details of SRECs in a secure and seamless online trading platform. Upon each SREC transaction Flett Exchange remits immediate payment to our sellers (it’s simple sell a SREC and get a check!) Flett Exchange operates SREC markets in NJ, PA, DE, MD, OH, CT, MA, and DC and supported by trained solar professionals with specialized knowledge and proven experience.

Flett Exchange brokers bilateral long-term SREC contracts between qualified counterparties. Flett Exchange buyers and sellers can secure price, quantity, and terms of SREC contracts 1-7 years in duration. Our stringent vetting process ensures that quality solar projects are presented to the market in a skillful manner. Buyers and sellers utilize Flett Exchange for long-term SREC contracts gain direct access to large pools of SRECs, while mitigating risk and locking-in profits. Please visit www.flettexchange.com to learn more about our services.