Intermittent generators, such as solar and wind based generators, only produce electricity when their energy source is available (e.g. when the sun shines or the wind blows). With distributed generation (DG), intermittent generators are often connected behind the same utility meter as customer loads (e.g. HVAC, consumer electronics, lights) that can be turned off and on based on the needs of the customer. As a result, on-site electric power production does not necessarily match on-site electric power consumption (also known as the customer 'load' or demand') on a moment-to-moment basis. In Rhode Island, net metering allows these DG customers to financially balance out the total amount of energy imported with the total amount of energy exported over the course of a billing period (typically about a month). Then, the customer is only billed (or credited) for the net difference between these two amounts.
ISO-NE stands for the Independent System Operator. It is responsible for managing the bulk power generation and transmission systems in New England. and transmission systems in New England.
Refer to R.I.G.L. Chapter 39-26-5 for official requirements
This depends on whether or not your city or town follows the Net Metering rules that apply to Investor Owned Utilities.
Please consult with your Local Electric Distribution Company.
(Note: Net Metering Services will be administered through the Local Electric Distribution Company.)
No, the retail customer does not have to be the owner of the generation system.
The Host Customer is the account holder (the name on the electric bill). A Host Customer may or may not own the generating facilities served by their meter. Host Customers generate electricity on the Customer side of the meter.
National Grid is not responsible for the terms and conditions of any agreement between the Host Customer and the third party system owner. This is not to be confused be confused with a PPA with National Grid through a (wholesale) P-rate, or with credit allocation (Schedule B).
For Simplified Applications, the Host Customer must fill out, sign, and submit an Exhibit H along with the remainder of the Interconnection Application documents. The sections that refer to the "Customer" in the Exhibit H should include information about the Host Customer (the legal entity listed on the electric utility bill). The sections that refer to the "Interconnecting Customer" in the Exhibit H should include information about the third party system owner.
For Expedited or Standard Applications, National Grid will provide the Exhibit H as an attachment to the Interconnection Service Agreement. However, the Interconnecting Customer (i.e. third party system owner) must confirm that they have site control on the Interconnection Application and must provide contact information for the Host Customer on the Legal Information Document.
Please see National Grid's Wholesale Energy Procurements website if you are interested in a PPA.
If you wish to pursue a transmission interconnection as a Qualifying Facility (the local retail company would purchase 100% of output) then you would follow a state jurisdictional process which is administered by the (Distributed Generation) team.
However, if you wish to sell the output to the market you would be required to interconnect under ISO-New England's Schedule 23 Tariff (if size is < 20 MW) which can be found at http://www.iso-ne.com/regulatory/tariff/sect_2/sch23/index.html. Documents and directions for submitting the interconnection application under Schedule 23 can be found at
http://www.iso-ne.com/genrtion_resrcs/nwgen_inter/smgen_20/index.html.This process is led by ISO New England and would consist of an initial scoping meeting to discuss regional/local planning variables, an overview of the proposed project, and next steps for the System Impact study phase.
Without understanding the size of your project and whether there are any significant system impacts, a connection to National Grid's 115 kV (transmission) system would typically consist of tap line facility to a transmission substation consisting of a three-breaker ring bus, which would require about an acre of property adjacent to the Right of Way. This connection is estimated around $3-5 million dollars (depending on site location, etc), but the estimates would tighten during the study phase.
As stated in section 8.1 of the interconnection Tariff, the Company shall own the meter and the Interconnecting Customer shall pay the Company a monthly charge to cover taxes, meter maintenance, incremental reading and billing costs, the allowable return on the invoice cost of the meter and the depreciation of the meter.
Only if the project is above 60 kW and exporting power will the customer be required to provide a phone.
You are eligible after:
1) Your standard meter has been replaced with a bi-directional meter (i.e. net meter); and
2) You have received the formal "Authorization to Interconnect" e-mail or letter from National Grid.
For the utility company, a stand-alone generating system is a grid-connected generating system that does not have any (non-parasitic) load behind the same meter. This is not to be confused with an isolated (or backup) generating system, which does not operate in parallel with the utility grid.
Stand-alone generating systems are referred to as Independent Power Producers (IPP) (i.e. a generating system that uses little or no power and was constructed solely for the purpose of generating electricity).
While the terms "Remote" or "Virtual" net metering are not used in Rhode Island, and Rhode Island's net metering regulations do not allow for credits to be transferred to other account holders. In Massachusetts, customers with net metered distributed generation systems may allocate net metering credits to other National Grid electric accounts within the same ISO-NE load zone.
Schedule B is only required for customers who want net metering.
The Exhibit H is an agreement between National Grid and the Host Customer (the named legal entity on the electric billing account) to interconnect a third-party generation unit behind the Host Customer's meter.
The Exhibit H must be completed when the retail customer is not the owner and operator of the proposed generation system. (For simplified applications, this must be submitted with the initial application. For all other applicants, the Exhibit H will be included in the Interconnection Service Agreement.)
Customers that net export power over the billing period will notice the following differences on their bill:
1) The total usage will appear as a negative number.
2) Net Metering Credit will be a line item in the Delivery section of the bill.
If the Net Metering Credit exceeds the total of the other charges on the bill, the "Current Charges" will be negative.
If the Net Metering Credit does not exceed the total of the other charges, then the "Current Charges" will be positive.
Excess Net Metering Credits are forfeited.
No. Allocation of credits is not allowed to gas accounts per the RI PUC No. 2075 Net Metering Provision. Currently, there is no mechanism in the tariff.
Yes. The project would be considered a Qualifying Facility (QF).
A Qualifying Facility is a renewable energy generating facility that receives a special rate and regulatory treatment. They can either be a small power production facility (less than or equal to 80 MW) or a cogeneration facility (produces electricity and heat).
It is a rate specific to Qualifying Facilities determined by ISO-NE.
QFs have their output metered hourly and this energy is purchased at hourly rates equal to the wholesale payments received by National Grid from ISO-NE. These rates are generally significantly lower than retail rates. Each month the customer will receive a check from National Grid.
Net Metering projects are limited to an aggregate generating capacity of 5MW.
According to Rhode Island regulations, (as of December 2011) the aggregate total of generating facilities taking net metering service is capped at 3% of the utility's historic peak load.
An SREC is a Solar Renewable Energy Certificate, which represents the renewable and/or environmental attributes associated with electricity that is produced by solar generators. An SREC is created for every megawatt-hour of solar electricity created. In states with SREC legislation, the Renewable Portfolio Standard (RPS) mandates that distribution companies buy a certain quantity of SRECs each year.
Rhode Island does not have an SREC market. However, it does have a REC market. A Renewable Energy Certificate (REC) is similar to an SREC, but it is generally associated with electricity produced by non-solar renewable technologies, such as wind turbines or anaerobic digesters.
Utilities are not automatically granted the RECs (Renewable Energy Certificates). The RECs are separate from the power the distribution company is buying. (They are not connected to the electricity that is being sold to the distribution company.)
If you are the new homeowner you would need to agree to the terms and conditions set forth in the original Interconnection Service Agreement (ISA) - or the terms and conditions of the Simplified Application.
You also need to:
1) Understand how your generation system works.
2) If possible, ensure that the transfer of ownership is appropriately documented during the sale of the house. (Verify the status of any third party ownership of the generation system.)
3) Contact National Grid to request an updated Interconnection Service Agreement (ISA).
This information can be found at the top of your electricity bill.
This depends on a number of factors. If the weather is not favorable to your generating facility (eg.: little sun for solar systems and insufficient wind for turbines), then your system will not be supplying power to its full potential. Similarly, clouds that block the sun will reduce the power output from solar panels. Choosing the right location for your generating facility is critical.
A comprehensive list of tax credits, rebates, incentives and more can be found at
Our W-9 forms can be found at http://www.nationalgridus.com/shortcut_w9.asp