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RESOLUTION NO.
A RESOLUTION OF THE CITY COUNCIL OF RIVERSIDE, CALIFORNIA, (1) ADOPTING REVISED SCHEDULE NEM, “NET ENERGY METERING FOR RENEWABLE ELECTRICAL GENERATION FACILITIES ”,
ELECTRIC RULE 22 “DISTRIBUTED GENERATION FACILITIES
INTERCONNECTION”, AND NEW SCHEDULE SELF-GEN, “SELF -
GENERATION PROGRAM FOR RENEWABLE ELECTRICAL
GENERATION FACILITIES”; AND (2) MAKING RELATED FINDINGS OF FACT
WHEREAS, the City of Riverside (“City”) by and through its Public Utilities Department (“RPU”) is obligated to : (1) serve its water and electric customers safe, reliable and equitably priced water and electricity ; (2) operate its Electric and Water Utilities in an efficient an d economical manner; and (3) operate, maintain and preserve its Electric and Water Utilities in good repair and working order; and
WHEREAS, RPU is responsible for operating the Electric and Water Utilities in such a manner that revenues from the sale of electric and water shall at least equal the costs of operation, including all maintenance and operating, administrative and general, debt service, capital improvements, tax-related payments and other costs incurred in complying with prudent utility business practices; and
WHEREAS, RPU staff submitted to the City's Board of Public Utilities (“Board ”) the proposed adoption and approval of revised Schedule NEM, “Net Energy Metering for Renewable Electrical Generation Facilities ,” Electric Rule 22 “Distributed Generation Facilities Interconnection,” and new Schedule Self -Gen, “Self -Generation Program for Renewable Electrical Generation Facilities;” and
WHEREAS, after considering all staff and public comment thereon, on February 28, 2022, the Board adopted and established, by resolution, revised Schedule NEM, “Net Energy Metering for Renewable Electrical Generation Facilities ,” Electric Rule 22 , “Distributed Generation Facilities Interconnection,” and new Schedule Self-Gen, “Self-Generation Program for Renewable Electrical Generation Facilities;” and
WHEREAS, the Board Resolution, (Resolution No. 2022-1), which Resolution is attached hereto as At tachment 1, incorrectly noted that a public hearing was conducted by the Board of
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Public Utilities on February 28, 2022. However, the public hearing is being conducted by the City Council, as noted herein; and
WHEREAS, the City Council conducted a public hearing, notice of which was duly published in The Press -Enterprise on April 25, 2022, and May 2, 2022, in compliance with Government Code Sections 66018 and 6062a, on May 10, 2022, at 3.00 p.m. before the City Council to consider the revisions noted herein; and
WHEREAS, the revised Schedule NEM, “Net Energy Metering for Renewable Electrical Generation Facilities” and Electric Rule 22 “Distributed Generation Facilities Interconnection” are to be effective upon the date of approval by the City Council.
WHEREAS, t he new Schedule Self -Gen, “Self -Generation Program for Renewable Electrical Generation Facilities” is effective by approval of the City Council as of November 1, 2022.
NOW, THEREFORE, IT IS RESOLVED:
Section 1: That the findings of fact of the Board of Public Utilities made in its Resolution No. 2022-1, which Resolution is attached hereto as Attachment 1 and incorporated herein in its entirety by this reference, are hereby adopted as findings of the City Council.
S
ection 2: That the Public Utilities Department is directed to prepare and file the Notice of Exemption and such other documents as are required by the California Environmental Quality Act (Public Resources Code sections 21000 et seq.) in connection with the proposed rule revisions.
Section 3: That the revised Schedule NEM, “Net Energy Metering for Renewable Electrical Generation Facilities and Electric Rule 22 , “Distributed Generation Facilities Interconnection,” all as set forth in Exhibit A to Attachment 1, are hereby approved under and pursuant to Section 1202(e) of the Charter of the City of Riverside, California , and shall become effective upon such date of approval.
Section 4 : That the new Schedule Self-Gen, “Self -Generation Program for Renewable Electrical Generation Facilities,” as set forth in Exhibit A to Attachment 1, are hereby approved under and pursuant to Section 1202(e) of the Charter of the City of Riverside, California, and shall become effective as of November 1, 2022.
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ADOPTED by the City Council and signed by the Mayor and att ested by the City Clerk this ____ day of _______________, 2022.
___________________________________
Mayor of the City of Riverside
____________________________
City Clerk of the City of Riverside
I, Donesia Gause, City Clerk of the City of Riverside, California, hereby certify that the foregoing resolution was duly and regularly introduced at a meeting of the City Council on the ____ day of _______________, 2022, by the following vote, to wit:
Ayes:
Noes:
Abstain:
Absent:
IN WITNESS WHEREOF, I have hereunto set my hand and affixed the official seal of the City of Riverside, California, this ________ day of _________________, 2022.
____________________________
City Clerk of the City of Riverside
https://riversideca-my.sharepoint.com/personal/eroyle_riversideca_gov/Documents/Desktop/Revised Resolution (March 29, 2022).docx
22-0128.1 SDW 3/29/2022
Attachment 1
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CITY ATTORNEY’S OFFICE
3750 UNIVERSITY AVENUE
RIVERSIDE, CA 92501
(951) 826-5567
ATTACHMENT 1
RESOLUTION NO. 2022-1 OF THE BOARD OF PUBLIC UTILITIES
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RESOLUTION NO. 2022-1 A RESOLUTION OF THE BOARD OF PUBLIC UTILITIES OF THE CITY OF RIVERSIDE, CALIFORNIA (1) ADOPTING REVISED SCHEDULE NEM, “NET ENERGY METERING FOR RENEWABLE ELECTRICAL GENERATION FACILITIES, ELECTRIC RULE 22 “DISTRIBUTED GENERATION FACILITIES INTERCONNECTION”, AND NEW SCHEDULE SELF-GEN, “SELF-GENERATION PROGRAM FOR RENEWABLE ELECTRICAL GENERATION FACILITIES”; (2) MAKING FINDINGS OF FACT; AND (3) RECOMMENDING CITY COUNCIL APPROVAL THEREOF WHEREAS, the City of Riverside (“City”) by and through its Public Utilities Department (“RPU”) is obligated to (1) serve its water and electric customers safe, reliable and equitably priced water and electricity, (2) operate its Electric and Water Utilities in an efficient and economical manner, and (3) operate, maintain and preserve its Electric and Water Utilities in good repair and working order; and
WHEREAS, RPU is responsible for operating the Electric and Water Utilities in such a manner that revenues from the sale of electric and water shall at least equal the costs of operation, including all maintenance and operating, administrative and general, debt service, capital improvements, tax-related payments and other costs incurred in complying with prudent utility business practices; and
WHEREAS, the City of Riverside’s (“City”) Department of Public Utilities (“RPU”) has submitted for action by the Board of Public Utilities (“Board”) and the City Council, the proposed adoption and approval of revised Schedule NEM, “Net Energy Metering for Renewable Electrical Generation Facilities, Electric Rule 22 “Distributed Generation Facilities Interconnection”, and new Schedule Self-Gen, “Self-Generation Program for Renewable Electrical Generation Facilities” as further explained herein; ; and WHEREAS, in accordance with Public Utilities Code (PUC) Section 2827, the City Council approved Schedule NEM “Net Energy Metering for Renewable Electrical Generation Facilities” (“Schedule NEM”) which became effective on July 1, 2002, for eligible customer generators who install a solar or wind turbine generating facility intended to primarily offset part
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or all their own electrical requirements. The existing Schedule NEM was established on July 1, 2002 to comply with PUC Section 2827; and
WHEREAS, Net Energy Metering (NEM) eligible customers are those with solar and or wind generating facilities on the customers owned or leased premises with a capacity of less than 1 megawatt MW intended to primarily offset all or a portion of the customers own electrical requirements. Schedule NEM allows a customer to carryforward monthly credits for customers who were net generators (e.g., their facility generated more energy than the customer consumed during the billing period that was fed back into Riverside’s electric system) in any given month and allows those credits to offset energy usage in subsequent months in which the customer consumes more energy than the renewable facility generated; and WHEREAS, State Assembly Bill 920 (“AB 920”), enacted on October 11, 2009, modified the NEM requirements of PUC Section 2827 by requiring RPU to compensate eligible customer generators on a per kilowatt hour rate effective January 1, 2011 for the amount of energy generated and fed back to RPU’s electric system that exceeds the amount of energy consumed over a twelve month period. On December 14, 2010, the City Council adopted the required changes to Schedule NEM and the NEM Interconnection Agreement and established the net surplus compensation rate which is set annually at RPU’s average cost of renewable energy; and
WHEREAS, the utility industry has changed dramatically over the past decade, with renewable resources now readily available and more cost-effective. RPU now has over 4,700 solar customers under the current NEM program with the number of new solar installations continuing to average over 500 per year. Under the current NEM program, customers net the monthly energy received from RPU with the energy generated. If more energy was generated than consumed, the energy sent back to RPU’s electric system is compensated to the customer at the retail rate. Because the retail rate paid to solar generation customers is greater than the average cost of new renewable energy sources from RPU, the utility increases its costs for budgeted energy which impacts all customers. The proposed program amendments address this situation to provide the lowest cost of total energy supply to the benefit of all customers; and
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WHEREAS, RPU met its State-mandated legal obligation to offer the current NEM program, as the total rated generating capacity of NEM program customers as of June 30, 2021 is
37.5 MW and exceeds five percent of RPU’s aggregate customer peak demand (32 MW for RPU) ; and
WHEREAS, the proposed Self-Generation Program establishes a new program for customers installing qualifying renewable electric generation facilities including solar, wind and other renewable resources. The Self-Generation Program provides many benefits including simplifying the application process by eliminating the interconnection service agreement, increasing the maximum system size, and relaxing the sizing limitations, while continuing the sustainable growth of self-generation including solar, wind and other renewable energy within our community. The Self-Generation Program includes characteristics that are similar to rates offered or being proposed by other large utilities in California that compensates new solar customers according to the time they generate and provide excess power to RPU’s electric system at RPU’s avoided cost of energy, thus ensuring there is greater equity across the community by reducing the cost shift to customers without solar; and WHEREAS, RPU has established a transition Plan for current NEM Program Customers:
the current NEM program will be closed to new applicants as of November 1, 2022; Customers must receive permit completion for their renewable generation facility no later than October 31, 2022 to be eligible for Schedule NEM; and current NEM program customers will remain on the current NEM program according to the NEM agreement until they no longer receive service at the premise, increases the original renewable generation facility capacity by more than twenty-five percent (25%), or installs a new self-generation facility at the premise; and
WHEREAS, Electric Rule 22, “Distributed Generation Facilities Interconnection” (“Electric Rule 22”) defines the interconnection, operating and metering requirements for generation facilities to be connected to RPU’s distribution system. The proposed changes to Electric Rule 22 include changes consistent with the proposed Self-Generation Program, with
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additional non-substantive changes are recommended to clarify the intent and address routine administrative updates; and
WHEREAS, a public hearing, notice of which was duly published in The Press- Enterprise on February 11 and 21, 2022, in compliance with Government Code Sections 66018 and 6062a, was held on February 28, 2022 at 6:30 p.m. before the Board of Public Utilities to consider the revisions noted herein; and
WHEREAS, the Board is charged by Section 1202(e) of the City Charter to establish and adopt the rates, rules, fees and charges for the Electric and Water Utilities, subject to the approval of the City Council; and
WHEREAS, the Board intends to establish and adopt the revised Schedule NEM, “Net Energy Metering for Renewable Electrical Generation Facilities, revised Electric Rule 22 “Distributed Generation Facilities Interconnection”, and new Schedule Self-Gen, “Self- Generation Program for Renewable Electrical Generation Facilities,” all in accordance with staff recommendations; and
NOW, THEREFORE, BE IT RESOLVED, based upon the foregoing facts, the staff report, and other evidence submitted by staff to the Board, by the Board of Public Utilities of the City of Riverside, California, as follows:
Section 1: The foregoing recitals are true and correct and are adopted and incorporated herein by reference as findings of fact of this Board.
Section 2: On the basis of the RPU staff analyses, data and reports, the foregoing recitals and the other evidence submitted by staff to the Board, the Board hereby finds and determines that the revised Schedule NEM, “Net Energy Metering for Renewable Electrical Generation Facilities, revised Electric Rule 22 “Distributed Generation Facilities Interconnection”, and new Schedule Self-Gen, “Self-Generation Program for Renewable Electrical Generation Facilities,” are exempt from the provisions of the California Environmental Quality Act (Pub. Res. Code Section 21000 et seq.) under Public Resources Code section 21080(b)(8), as the proposed revisions to the existing rules are for the purpose of (A) meeting operating expenses, including employee wage rates and fringe benefits, (B) purchasing or leasing
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RIVERSIDE, CA 92522
(951) 826-5567
EXHIBIT A
Schedule NEM, “Net Energy Metering for Renewable Electrical Generation Facilities” Electric Rule 22 “Distributed Generation Facilities Interconnection” Schedule Self-Gen, “Self-Generation Program for Renewable Electrical Generation Facilities” City of Riverside
Public Utilities Department
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No.
Effective Date:
SCHEDULE NEM
NET ENERGY METERING FOR
RENEWABLE ELECTRICAL GENERATION FACILITIES
(This rate schedule is closed to new Customers as of November 1, 2022. Customers must receive Permit Completion for their Renewable Electrical Generation Facility no later than October 31, 2022 to be eligible for Schedule NEM.)
Applicability:
Applicable to all end
‐use Eligible Customer‐Generators who execute the applicable Standard Contract‐NEM.
An Eligible Customer Generator is a residential, commercial, industrial or agricultural Customer who uses a Renewable Electrical Generation Facility, or a combination of those facilities, with a capacity of not more than 1,000 kilowatts, that is located on the
Customer’s owned, leased, or rented premises, and is interconnected and operates in parallel with the Utility’s transmission and distribution facilities, and is intended primarily to offset part or all of the Customer’s own electrical requirements on the premises.
Territory:
Within the service area of the City of Riverside
Rates:
All rates
charged under this schedule will be in accordance with the Eligible Customer‐Generator’s otherwise applicable tariff (OAT) or rate schedule, in effect from time to time, on a Net Energy Metering basis. An Eligible Customer‐ Generator served under this schedule is responsible for all charges in its OAT including the monthly or annual minimum charges (including service, customer, reliability, network access, and demand charges, when applicable), regardless of the Customer’s monthly or annual net generation.
Eligible Customer‐Generators under this schedule are subject to any new or additional charge(s) that may be imposed by the Utility on the other customers in
the rate class to which Customer would otherwise be assigned.
Special Conditions:
1. Availability:
A Customer shall be eligible for this Schedule NEM provided the Customer has received final approval of all required building permit applications from the City’s Building and Safety Division, or authority having jurisdiction, and the
Utility’s requirements (“Permit Completion”) for their Renewable Electrical Generation Facility no later than October 31, 2022 (“Schedule NEM Deadline”). Any Customer who is eligible for Schedule NEM, shall remain on the Schedule NEM until either the Customer ceases to receive electric service at the Premises where the Renewable Electrical Generation Facility is located, increases the original Renewable Electrical Generation Facility capacity by more than twenty‐five percent (25%), or installs a new Renewable Electrical Generation Facility, whichever is earlier. In addition, a Schedule NEM Customer may elect to permanently switch to the Schedule Self‐Gen “Self‐Generation Program for Renewable Electrical Generation Facilities” (Schedule Self‐Gen), or available rate for Renewable Electrical Generation Facilities, at any time.
New customers establishing service at an existing Premise with a Renewable Generation Electrical Facility are not eligible for this Schedule NEM.
Customers who receive Final Permit Approval for their Renewable Electrical Generation Facility subsequent to the Schedule NEM Deadline, shall not be eligible for Schedule NEM; however, these Customers shall be eligible for Schedule Self‐Gen, subject to the terms and conditions of Schedule Self‐Gen.
2. Agreement:
In order for this schedule to apply, Customer must sign the Utility’s Standard Contract – NEM. The Standard Contract – NEM shall contain additional terms and conditions, including without limitation, indemnification, insurance, and access to Customer’s premises and Generating Facilities requirements.
City of Riverside
Public Utilities Department
Schedule NEM – Net Energy Metering For Renewable Electric Generation Facilities ‐ 2‐
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No.
Effective Date:
3. Billing:
a. Residential and Small Commercial (Schedule A Flat Rate) Customers:
(1) The annualized Net Energy Metering calculation shall be made by measuring the difference between the energy supplied to
the Customer and the energy generated by
the Customer and fed back to the Utility’s grid over a Twelve‐Month Period. At the end of each Twelve‐Month Period, and at each anniversary date thereafter, the Utility shall determine if the Customer was a net consumer or a net generator of energy during the Twelve‐Month Period. In the event the energy supplied by the Utility during the Twelve‐ Month Period exceeds the energy generated by the Customer during that same period, the Customer is a net energy consumer.
(2) If the Customer is a net energy consumer, the Utility will bill the Customer for the net
energy consumed during the Twelve‐Month Period based on Customer’s OAT and Customer shall pay for such net energy consumed annually.
(3) The Customer may elect to be billed monthly for net energy consumed upon initiation of service under this Schedule or upon proper written notice to the Utility no later than
thirty‐days prior to the Customer’s regularly scheduled meter read date in January of each year. Such change shall be made by the Utility at the beginning of a new Twelve‐Month Period coinciding with the Customer’s regularly scheduled meter read date in January following receipt of Customer’s proper written notice.
b. Commercial (Schedule A Demand Rate), Industrial or Agricultural Rate Customers:
(1) The annualized Net Energy Metering calculation shall be made by measuring the difference between the energy supplied to the Customer and the energy generated by the Customer and fed back
to the Utility’s grid over a Twelve‐Month Period. Additionally, at the end of each billing period, the Utility shall determine if the Customer was a net consumer or a net generator of energy. In the event the energy supplied by the Utility to the Customer during the preceding billing period exceeds the energy generated by the Customer during that same billing period, the Customer is a net energy consumer.
(2) If the Customer is a net energy consumer, the Utility will bill the Customer for the net energy consumed during such billing period based on Customer’s OAT and Customer shall
pay for such net energy consumed monthly in accordance with the Customer’s monthly billing statement and the Electric Rules.
c. All Eligible Customer – Generators:
(1) If the Customer’s OAT employs “time of use” rates, any net energy consumed monthly shall be calculated according to the terms of the OAT. When the Customer is a net generator during any discrete time of use period over a billing period, the net kilowatt‐ hours generated shall be valued at the same price per kilowatt‐hour as the Utility would charge for retail kilowatt‐hour sales during that same time of use period.
(2) If the Customer’s OAT employs “tiered” rates, any net energy consumed monthly shall be calculated according to the terms of the OAT. When the Customer is a net generator over a billing period, the net kilowatt‐hours generated shall be valued at the same price per kilowatt‐hour as the Utility would charge for the same tiered quantity of energy during that billing period.
(3) The Utility shall provide all customers with Net Energy Metering consumption and generation information on a monthly basis. Such monthly update shall include the City of Riverside
Public Utilities Department
Schedule NEM – Net Energy Metering For Renewable Electric Generation Facilities ‐ 3‐
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No.
Effective Date:
current accrued balance owed to the Utility for Net Energy Metering charges, or current accrued credits for Net Energy Metering generation, whichever applies.
(4) If the energy generated exceeds the energy consumed by the Customer, the Customer is
a net energy generator. If the Customer is a net generator of energy over a normal billing period, any excess kilowatt‐hours generated during the billing period shall be carried forward as a monetary value to the following billing period (until the end of the Customer’s Twelve‐Month Period).
(5) At the end of each Twelve‐Month Period, the Utility shall retain any Net Surplus Energy generated by the Net Surplus Customer Generator, including any associated environmental attributes or renewable energy credits (REC), and Customer’s monetary value shall be reset to zero for the subsequent Twelve ‐Month Period. In addition, no
payment will be made to any Customer for the excess energy delivered to the Utility’s grid, unless the Customer elects to receive Net Surplus Energy Compensation for that excess energy by electing a compensation option, as set forth in Subsection 2.c.6 herein.
(6) Customer may, upon the Utility’s timely receipt of Customer’s written affirmative election, be eligible for Net Surplus Energy Compensation. The Customer’s Net Surplus Energy Compensation shall be calculated over a Twelve‐Month Period beginning with the Customer’s regularly scheduled meter read date in January following receipt of a timely filed affirmative election and conclude as of the Customer’s regularly scheduled meter read date the following December.
Customers may receive Net Surplus Energy Compensation for Net Surplus Energy at the end of a Twelve‐Month Period by affirmatively electing one of the following methods:
i. Receive compensation based on an annual time‐differentiated per kilowatt‐hour rate for Net Surplus Energy generated during the prior Twelve‐Month Period. The rate will be posted on the Utility’s website (RiversidePublicUtilities.com/ElectricRates) on January 1 of each year and will be effective from January 1 through December 31. The rate shall be established annually by the Public Utilities General Manager based upon the average hourly cost of renewable energy purchased by the Utility and reported in the most recently audited fiscal year; or
ii. Receive the Net Surplus Energy as a kilowatt‐hour credit calculated using the Net Surplus Energy Compensation rate and applied against future billing periods.
(7) Affirmative elections remain effective for each Twelve‐Month Period following the execution of such election. Customers are eligible to revise their Net Surplus Energy Compensation elections by giving written notice to the Utility at least thirty days prior to the beginning of each succeeding Twelve‐Month Period.
(8) If
any Customer terminates service under this Schedule prior to the end of any Twelve‐ Month Period, the Utility shall reconcile the Customer’s energy consumed and generated following the last reconciliation, according to the requirements set forth in this schedule, except that those requirements shall apply only to the months since the most recent twelve‐month bill.
4. Metering:
Net Energy Metering shall be accomplished using a Required Meter. The Utility shall own, operate and maintain the Required Meter on the Customer’s premises. If the existing meter at Customer’s premises is not capable of measuring the flow of energy in two
directions, Customer shall be responsible for all expenses City of Riverside
Public Utilities Department
Schedule NEM – Net Energy Metering For Renewable Electric Generation Facilities ‐ 4‐
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No.
Effective Date:
involved in the Utility’s purchase and installation of the Required Meter. The Utility, at its expense, may purchase and install additional meters with the consent of the Customer to provide the information necessary to accurately credit or bill the Customer or to collect generating system performance information for research purposes. If an additional meter or meters are installed, the net metering calculation shall yield a result identical to that of a single meter.
5. Definitions:
a. “Renewable Electrical Generation Facility” means a facility that generates electricity from a
renewable source listed in paragraph (1) of subdivision (a) of Section 25741 of the California Public Resources Code including biomass, solar thermal, photovoltaic, wind, geothermal, fuel cells using renewable fuels, small hydroelectric generation, digester gas, municipal solid waste conversion, landfill gas, ocean wave, ocean thermal, or tidal current, and any additions or enhancements to the facility using that technology.
b. “Net Energy Metering” means measuring the difference between the energy supplied through the electric grid to the Customer and the energy generated by an Eligible Customer‐Generator and fed back to the electric grid over a
Twelve‐Month Period, as described in California Public Utilities Code Section 2827 (c) and (h).
c. “Net Surplus Customer Generator” means an Eligible Customer‐Generator that generates more energy in a Twelve‐Month Period than is supplied by the Utility to the Eligible Customer‐Generator during the same Twelve‐Month Period.
d. “Net Surplus Energy” means all energy generated by an Eligible Customer‐Generator measured in kilowatt‐hours over a Twelve‐Month Period that exceeds the amount of energy consumed by that Eligible Customer‐Generator.
e. “Net Surplus Energy Compensation” means compensation, either monetary or as a billing credit, at a per kilowatt‐hour rate, established by Riverside’s Board of Public Utilities and adopted by Riverside’s City Council, offered by the Utility to the Net Surplus Customer Generator for Net Surplus Energy.
f. “Required Meter” means a single meter capable of registering the flow of energy in two directions.
g. “Small
Commercial Customer” means a customer that has a maximum peak demand of less than 20 kilowatts, as defined in subdivision (h) of Section 331 of the California Public Utilities Code.
h. “Standard Contract – NEM” means that standard contract entitled “Net Energy Metering Interconnection Agreement for Solar or Wind Turbine Electric Generating Facilities” available to Eligible Customer Generator, as established by Riverside’s Board of Public Utilities and adopted by Riverside’s City Council from time to time, and offered in accordance with California Public Utilities Code Section 2827.
i. “Twelve‐Month Period” means the Twelve‐Month Period commencing with the Customer’s regularly scheduled meter read date in January and concluding as of the Customer’s regularly scheduled meter read date the following December. The Customer’s first such period will commence as of the date of interconnection and conclude as of the regularly scheduled meter read date the following December, and may be less than 12 months.
6. State Mandated Public Benefits Charge:
The rates in Eligible Customer‐Generator’s OAT are subject to a surcharge as adopted by City Council Resolution No. 19203, and such surcharge as in effect from time to time. The applicable Public Benefits Charge will be applied in accordance with
the Customer’s OAT. The Public Benefits Charge that is applicable to the Customer under the Customer’s OAT shall be calculated based upon the Customer’s total energy usage City of Riverside
Public Utilities Department
Schedule NEM – Net Energy Metering For Renewable Electric Generation Facilities ‐ 5‐
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No.
Effective Date:
charges including net energy consumed, monthly or annual minimum charges (including service, customer, reliability, and demand charges, when applicable), for the applicable billing period.
7. Miscellaneous Fees and Charges:
Rates charged pursuant
to this Schedule shall be subject to any Energy Users Taxes, Utility Users Taxes and any other governmental taxes, duties, or fees which are applicable to Electric Service provided to Customer by the Utility. Rates are also subject to adjustment, as established by Riverside’s Board of Public Utilities and adopted by Riverside’s City Council in response to federal or state climate change laws, renewable portfolio standard or other mandated legislation. These adjustments may include but are not limited to charges to mitigate the impacts of greenhouse gas emissions or “green power” premiums.
8. Power Cost Adjustment Factor (“PCAF”):
The “PCAF”,
as provided in Part C of the General Provisions, shall apply to Customer’s net energy consumed and such other charges as indicated by Customer’s OAT.
9. Environmental Attributes and Renewable Energy Credits (“REC”):
Customers electing service under this Schedule must certify that they have sole ownership of the environmental attributes
and RECs. For Customers who elect to receive Net Surplus Energy Compensation, any environmental attributes and RECs associated with such compensation shall be the property of the Utility.
Customers who elect to receive net surplus energy as a kilowatt‐hour credit calculated using the Net Surplus Energy Compensation rate and applied against future billing periods may transfer ownership of any environmental attributes and RECs to the Utility.
10. Program Cap:
The total contract generating capacity for qualifying customers of this Schedule shall collectively not exceed the required total rated generating capacity percentage of the Utility’s aggregate peak customer demand as required
by California Public Utilities Code section 2827 (c)(1).
Until the program cap is reached, the Schedule shall be open to eligible customers on a first‐come‐first‐served basis. Once the program cap is reached, the Schedule will be closed to any new customers, until such time as qualified customers included within the program cap, with an executed Standard Contract – NEM, no longer receives service under this Schedule, thus allowing participation by additional eligible customers until a new program cap is reached.
11. Applicable Rate Schedule:
a. Applicable Rate Schedule
For Customers applying for service at an existing service address, the Utility will assign the electric rate schedule based on the characteristics of the service address. The Utility will presume that any electric rate previously assigned to that service address is the appropriate schedule, unless Customer requests a review for another applicable rate schedule, rate, or optional provision. In certain situations when a Customer does not qualify for an electric rate previously assigned to that service address, the Utility will assign the applicable rate to the Customer. The Utility assumes no responsibility for advising the Customer of lower optional rates under existing schedules available as a result of the Customer’s changes to the characteristics of the service address.
b. Change of Rate Schedule
A change to the applicable rate schedule may be made if the Utility determines that the Customer no longer qualifies for the assigned rate schedule. Subject to meter availability, the change will become effective for service rendered after the next regular meter reading following verification and approval City of Riverside
Public Utilities Department
Schedule NEM – Net Energy Metering For Renewable Electric Generation Facilities ‐ 6‐
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No.
Effective Date:
by the Utility of such eligibility. Any change in rate schedules pursuant to this section shall be made prospectively.
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-1
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
ELECTRIC RULE 22
DISTRIBUTED GENERATION FACILITIES INTERCONNECTION
A. APPLICABILITY
Applicability. This Rule describes the inte rconnection, operating and metering requirements for Generating Facilities to be connected to the Riverside Public Utilities (RPU) Distribution System. Subject to the requirements of this Rule, RPU will allow the interconnection of Generating Facilities with its Distribution System.
Definitions: Capitalized terms used in this Rule, and not otherwise defined, shall have the meaning ascribed to such terms in Se ction H. The definitions in this Rule shall only apply to this Rule and may not apply to RPU’s other rate schedules.
B. GENERAL RULES, RIGH TS AND OBLIGATIONS
1. Authorization Required to Operate. A Producer must comply with this Rule, execute an Interconnection Agreement with RPU, and receive RPU’s express written permission to operate a Generat ing Facility in parallel with the Distribution System. RPU shall apply this Rule in a non-discriminatory manner and shall not unreasonably withhold its permission to interconnect an Electric Producer’s Generating Facility.
2. Separate Arrangements Required for Other Services. A Producer requiring other electric services from RPU including, but not limited to, Distribution Service during periods of curtailment or interruption of a Generating Facility, must enter into separate arrangements with RPU for such services, in accordance with RPU Bo ard and City Council approved rate schedules.
3. Transmission Service Not Provided with Interconnection. Interconnection with RPU’s Distribution System under this Rule does not provide a Producer any rights to utilize RPU’s Distributi on System for the transmission or distribution, or wheeling of electric power, nor does it limit those rights.
4. Compliance with Laws, Rules, and Tariffs. A Producer shall ascertain and comply with RPU rules, rate schedules, and regulations of RPU; applicable Federal Energy Regulatory Commissi on approved rules, tariffs, and regulations; and any local, state or f ederal law, statue or regulation which applies to the design, siting, construction, installation, operation, or any other aspect of the Producer’s Generating Facility and Interconnection Facilities.
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-2
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
5. Design Reviews and Inspections. RPU shall have the right to review the design of a Producer’s Generating Facility and Interconnection Facilities and to inspect a Producer’s Generating and Interconnection Facilities prior to the commencement of Parallel Operation wit h RPU’s Distribution System. RPU may require a Producer to make modifi cations as necessary to comply with the requirements of this Rule. RPU’ s review and authorization for Parallel Operation shall not be construed as c onfirming or endorsing the Producer’s design or as warranting t he Generating or Interconnection Facilities’ safety, durability or reliability. RPU shall not, by reason of such review or lack of review, be responsible for the strengt h, adequacy, or capacity of such equipment.
6. Right to Access. A Producer’s G enerating Facility and Interconnection Facilities shall be reasonably accessible to RPU personnel as necessary for RPU to perform its duties and exercise its rights under its rate schedules and rules, and any Interconnection Agreement between RPU and the Producer.
7. Confidentiality of Information. Any information pertaining to Generating or Interconnection Facilities provided to RPU by a Producer shall be treated by RPU in a confidential manner. RPU shall not use information contained in the Application to propose discounted rates to the Customer unless authorized to do so by the Customer or the information is provided to RPU by the Customer through other means.
8. Prudent Operation and Maintenance Required. A Producer shall operate and maintain its Generating Facility and Interconnection Facilities in accordance with Prudent Electrical Prac tices and shall maintain compliance with this Rule.
9. Curtailment or Disconnection. RPU may limit the operation or disconnect or require the disconnection of a Produc er’s Generating Facility from RPU’s Distribution System at any time, with or without notice, in the event of an Emergency, or to correct Unsafe Operating Conditions. However, RPU must provide written notice as soon as po ssible following such disconnect. RPU may also limit the operat ion or disconnect or requi re the disconnection of a Producer’s Generating Fac ility from RPU’s Distri bution System upon the provision of reasonable wri tten notice: 1) to allow for routine maintenance, repairs or modifications to RPU’s Distribution System; 2) upon RPU’s determination that a Producer ’s Generating Facility is not in compliance with this Rule; or, 3) upon termination of the Interconnection Agreement. Upon the Producer’s written request RPU shall pr ovide a written ex planation of the reason for such curtailment or disconnection.
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-3
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
C. APPLICATION AND IN TERCONNECTION PROCESS
1. Application Process
a. Applicant Initiat es Contact with RPU. Upon request, RPU will provide information and documents (such as sample agreements, the Application, technical information, listing of Certified Equipment, application fee information, applicab le rate schedules and metering requirements) in response to a pot ential Applicant’s inquiry. Unless otherwise agreed upon, all such info rmation shall normally be sent to an Applicant within three (3) business days following receipt of the initial request from the Applicant. RP U will establish an individual representative as the si ngle point of contact fo r an Applicant, but may allocate responsibilities among its staff to best coordinate the Interconnection of an Applicant’s Generating Facility.
b. Applicant Completes a nd Files an Application. All Applicants shall be required to complete and file an Application and supply any relevant additional information requested by RP U. The filing must include the completed Application and a fee fo r processing the application and performing the Initial Review to be completed by RPU pursuant to Section C.1.c. The appl ication fee shall vary with the type of the proposed Generating Facility as follows:
Type of Service Initial Review Supplemental
Review
Net Ener
gy Metering
(per Public Utilities Code Section 2827)
- Residential
- Commercial
Flat & Demand
TOU
All others
$225
$360
$865
$800
None
None
None
$600 (additional)
Fifty percent of the fees associ ated with the Initial Review will be returned to the Applicant if the App lication is reject ed by RPU or the Applicant retracts the Application.
The Applicant may propose and RPU ma y negotiate specific costs for processing non-standard applications such as multi-units, multi-sites, or otherwise as conditions warrant. The costs for the Initial Review and City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-4
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
the Supplemental Review contained in this Section, as well as the language provided in Sections C.1. c and C.1.d, do not apply under these circumstances.
Within ten (10) business days of re ceiving an Application, RPU shall normally acknowledge its receipt and state whether the Application has been completed adequately. If def iciencies are noted, RPU and Applicant shall cooperate in a timely manner to establish a satisfactory Application.
c. RPU Performs an Initial Review and Develops Preliminary Cost Estimates and Interconnection Requirements.
(1) Upon receipt of a satisfactorily completed Application and any additional information necessary to evaluate the Interconnection of a Generating Facility, RPU s hall perform an Initial Review using the process defined in Se ction I. The Initial Review determines if (a) the Generating Fa cility qualifies for Simplified Interconnection, (b) the Generat ing Facility can qualify for Interconnection subject to additional requirements, or (c) it will be necessary for RPU to perform an Interconnection Study to determine the Interconnection Requirements.
(2) The RPU shall complete its Initial Review, absent any extraordinary circumstances, within 10 business days, upon determination that the Application is complete, if the Generating Facility qualifies for Simplifi ed Interconnection. If the Initial Review determines that the proposed facility can be
interconnected by means of a Simplified Interconnection, RPU will provide the Applicant with a written description of the requirements for interconnection and a draft Interconnection Agreement pursuant to Section C.1.e.
(3) If the Generating Facility does not qualify for Simplified Interconnection as proposed, RPU will notify the Applicant and perform a Supplemental Review as described in Section I. The Supplemental Review will provi de either (a) Interconnection Requirements beyond those for Si mplified Interconnection, and a draft Interconnection Agreement, or (b) a cost estimate and schedule for an Interconnection Study. The Supplemental Review shall be completed, absent any extraordinary
circumstances, within 20 business days upon determination that the Application is complete. Payment for the Supplemental Review shall be submitted to RPU within 10 calendar days after the results of the Supplementa l Review are provided to the Applicant.
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-5
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
d. When Required, Applicant and RPU Commit to Additional Interconnection Study Steps. When an Initial Review reveals that the proposed facility cannot be interconnected to RPU’s Distribution System by means of a Simplified In terconnection, or that significant RPU Interconnection Facilities or Dis tribution System improvements must be installed or made to RPU’s Distr ibution System to accommodate the interconnection of an Applicant’s Generating Facility, RPU and Applicant shall enter into an agreement that provides for RPU to perform additional studies, facili ty design, and engineering and to provide detailed cost estimates for fixe d price or actual cost billing, to the Applicant at the Applicant’s expense. The interconnection study agreement shall set forth RPU’s schedule for completing such work and the estimated or fixed price costs of such studies and engineering.
Upon completion of an Interconnecti on Study, RPU shall provide the Applicant with the specific requi rements, costs and schedule for interconnecting the Generating Facili ty to accommodate execution of agreements pursuant to Section C.1.e.
e. Applicant and RPU Enter In to a Generation Interconnection Agreement and, Where Required, a Financing and Ownership Agreement for Interconnection Facilities or Electric System Modifications. The RPU shall provide the Applicant with an executable version of the Generat ing Facility Interconnection Agreement, net energy metering agreement, or Power Purchase Agreement appropriate for the Appl icant’s Generating Facility and desired mode of operation. Where the Initial Review or Interconnection Study performed by RPU has determined that modifications or additions are required to be made to its Elec tric System, or that additional metering, monitoring, or protection devices will be necessary to accommodate an Applicant’s Generat ing Facility, RPU may also provide the Applicant with other interconnection facilities financing and ownership agreements. These agr eements shall set forth the Applicant’s responsibilities, completion schedules, and estimated or fixed price costs for the required work.
f. Where Applicable, RPU or Producer Installs Required
Interconnection Facilities or Modi fies RPU’s Distribution System.
After executing the applicable agr eements, RPU or Producer will commence construction/installation of the modification s or metering and monitoring requirements identified in the agreements. The parties will use good faith efforts to meet the schedules and cost estimates.
g. Producer Arranges for and Co mpletes Commissioning Testing of Generating Facility and, Where Applicable, Producer Installed Interconnection Facilities. The producer is responsible for testing City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-6
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
new Generating Facilities and associ ated Interconnection Facilities, according to Section J.5 to ensur e compliance with the safety and reliability provisions of this Rule, and RPU rules and regulations prior to being operated in parallel with RPU’s Distribution System.
h. RPU Authorizes Parallel Operation or Momentary Parallel Operation. The Producer’s Generating Fa cility shall be allowed to operate in Parallel Oper ation or Momentary Pa rallel Operation, as applicable, with RPU’s Distributi on System upon satisfactory compliance with the terms of all applicable agreements and express written permission. Compliance may include, but not be limited to, provision of any required documentati on and satisfactorily completing any required inspections or tests as described herein or in the agreements formed between the Producer and RPU.
i. RPU Reconciles Costs and Payments. If the Produc er selected a fixed price billing for the Interc onnection Facilities or Distribution System modifications, no reconc iliation will be ne cessary. If the Producer selected actual cost billi ng, a true-up will be required. RPU will reconcile its actual costs relat ed to the Producer’s facility against any advance payments made by t he Producer for interconnection facilities or Distribution System modifications. The Producer will receive either a bill for any balance due or a reimbursement for overpayment as determined by RPU’s reconciliation. The Producer shall be entitled to a reasonably detailed and under standable report detailing RPU’s reconciliation process.
D. GENERATING FACILITY DESIGN AND OPERATING REQUIREMENTS
1. General Interconnection and Protection Requirements
a. Protective Functions Required. The Protective Functions for Generating Facilities operating in parallel with RPU’s Distribution System shall include:
(1) Over and under voltage trip f unctions and over and under frequency trip functions;
(2) A means for disconnecting the Generating Facility from RPU’s Distribution System when a protective function initiates a trip;
(3) An automatic means to prevent the Generating Facility from energizing a de-energized Distribu tion System circuit and to prevent the Generating Facilit y from reconnecting with the Distribution System unless the Distribution System service City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-7
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
voltage and frequency is of specified settings and is stable for at least 60 seconds;
(4) A means to prevent the Generati ng Facility from contributing to the formation of an Unintended Island.
b. Momentary Paralleling Generating Facilities. With RPU’s approval, the transfer switch or system used to transfer the Producer’s loads from RPU’s Distribution System to Produc er’s Generating Facility may be used in lieu of the Protective Functions required for Parallel Operation.
c. Purpose of Protective Functions. The Protective Functions and requirements of this Rule are desi gned to protect RPU’s Distribution System and not the Gener ating Facility. A Pr oducer shall be solely responsible for providing adequate protection for its Generating Facility and Interconnection Facilities. The Producer’s protective equipment shall not impact the operation of other protective devices utilized on the Distribution System in a manner that would affe ct RPU’s capability of providing reliable service to its Customers.
d. Suitable Equipment Required. Circuit breakers or other interrupting devices located at the Point of Co mmon Coupling must be Certified or “Listed” (as defined in Article 100, the Definitions Section of the National Electrical Code) as suitable for their intended application. This includes being capable of interrupting the maximum available fault current expected at their location. Pr oducer’s Generating Facility and Interconnection Facilities shall be desi gned so that the failure of any one device shall not potentially compromise the safety and reliability of RPU’s Distribution System.
e. Visible Disconnect Required. The Producer shall furnish and install a manual disconnect device that has a Visible Disconnect to isolate the Generating Facility from RPU’s Distribution System. The device must be accessible to RPU personnel and be capable of being locked in the open position. Generating Facilit ies with Non-Islanding inverters totaling 1 kVA or less are exempt from this requirement.
f. Single-Phase Generators. For single-phase Generators connected to a shared single-phase secondary system, the maximum Net Nameplate Rating of the Generating Facilities shall be 20 kVA.
Generators applied on a center-tapped neutral 240-volt service must be installed such that no more than 6 kVA of imbalance in capacity exists between the two sides of the 240-vo lt service. For Dedicated Distribution Transformer services, the maximum Net Nameplate Rating of a single-phase Generating Fac ility shall be the transformer nameplate rating.
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-8
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
g. Drawings Required. RPU, prior to Paralle l Operation or Momentary Parallel Operation of the Generating Facility, shall approve the Producer’s protection and control diagrams of the Generating Facility.
Generating Facilities equipped with a protection and control scheme previously approved by RPU for system-wide application or with Certified Equipment only may satisfy this requirement by reference to previously approved drawings and diagrams.
h. Generating Facility Conditions Not Identified. In the event this Rule does not address the interconnecti on requirements for a particular Generating Facility, RPU and Producer may agree upon other requirements.
2. Prevention of Interference.
The Producer shall not operate equipm ent that superim poses upon RPU’s Distribution System a volt age or current that interf eres with RPU operations, service to RPU Customers, or RPU communication facilities. If such interference occurs, the Producer must diligently pursue and take corrective action at its own expense after being given notice and reasonable time to do so by RPU. If the Producer does not take timely corrective action, or continues to operate the equipment causing interference without restriction or limit, RPU may, without liability, disconnect t he Producer’s equipment from the Distribution System, in accordance with Section B.9 of this Rule.
To eliminate undesirable interference caused by operation of the Generating Facility, each Generating Facility shall meet the following criteria:
a. Normal voltage operating range. The voltage operating range limits for Generating Facilities shall be sele cted as a protection function that responds to abnormal Distribution System conditions and not as a voltage regulation function.
(1) Generating Facilities (11 kVA or less). Generating Facilities with a Gross Nameplate Rating 11 kVA or less shall be capable of operating within the limits normally experienced on the Distribution System. The operating range shall be selected in a manner that minimizes nuisance tripping between 106 volts and 132 volts (88-110% of nominal vo ltage) on a 120-volt base.
Generating Facilities shall cease to energize RPU circuits whenever the voltage at the Point of Common Coupling deviates from the allowable voltage operating range.
(2) Generating Facilities (Greater than 11 kVA). RPU may have specific operating voltage ranges for Generating Facilities with Gross Nameplate Ratings greater than 11 kVA and may require City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-9
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
adjustable operating voltage settings . In the absence of such requirements, the Generating Faci lity shall operate at a range between 88% and 110% of the applicable interconnection
voltage.
(3) Voltage Disturbances. System voltage assumes a nominal 120 V base. The Generator shoul d sense abnormal voltage and respond accordingly. The following conditions should be met, with voltages in root mean square and measured at the Point of Common Coupling, as described in Table D-1.
Table D-1: Voltage Trip Setting
Voltage at Point of
Common Coupling
(Assuming 120V base)
Maximum Trip Setting
(Assuming 60 cycles per
Second)
Less than 60 Volts
10 Cycles
Greater than or equal to
60 Volts but less than
106 Volts
120 Cycles
Greater than or equal to
106 volts but less than or
equal to 132 Volts
Normal Operation
Greater than 132 volts
But less than or equal to
165 Volts
120 cycles
(30 cycles for facilities greater
than 11 kVA)
Greater than 165 Volts 6 c ycles
*”Maximum Trip time” refers to the time between the onset of the abnormal condition and the Generating Facility ceasing to energize the Distribution System. Protective Function sensing devices and circuits may remain connected to the Distribution System to allow sensing of electrical conditions for use by the “reconnect” feature.
The purpose of the time delay is to allow Generating Facility to “ride through” short- term disturbances to avoid nuisance tripping. For Generating Facilities with a Gross Nameplate Rating of 11 kVA or less, the set points are to be non-user adjustable. For Generating Facilities with a Gross Nameplate Rating greater than 11 kVA, different voltage set points and trip times from those in Table D-1 may be negotiated with RPU.
b. Flicker. Any voltage flicker at the Po int of Common Coupling caused by the Generating Facility should not exceed the limits defined by the “Maximum Borderline of Irritation Curve” identified in IEEE 519 (IEEE Recommended Practices and Requirements for Harmonic Control in Electric Power Systems, IEEE STD 519-1992, Institute of Electrical and Electronic Engineers, Piscataway, NJ April 1992.) This requirement is necessary to minimize the adverse voltage effects experienced by other customers on RPU’s Distribution System. Induction Generators may City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-10
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
be connected and brought up to synch ronous speed (as an induction motor) provided these flicker limits are not exceeded.
c. Frequency. RPU controls system frequency, and the Generating Facility shall operate in synchroni sm with the Distribution System.
Generating Facilities with a Gross Nameplate Rating of 11 kVA or less shall have a fixed operating frequency range of 59.3-60.5 Hertz. The Generating Facility must cease to energize RPU’s Distribution System in a maximum of ten cycles should Distribution System remain outside of the frequency limits. The purpose of the time delay is to allow the Generating Facility to ride through short-term disturbances to avoid nuisance tripping. RPU may require adjustable operating frequency settings for Generating Facilities with a Gross Nameplate Rating greater than 11 kVA.
d. Harmonics. Harmonic distortion shall be in compliance with IEEE 519.
Exception: The harmonic distortion of a Generating Facility located at a Customer’s site shall be evaluated using the same criteria as for the loads at that site.
e. Direct Current Injection. Generating Facilities should not inject Direct Current greater than 0.5% of ra ted output current into RPU’s Distribution System.
f. Power Factor. Each Generator in a G enerating Facility shall be capable of operating at some point within a power fact or range of 0.9 leading and 0.9 lagging. Operation outside this range is acceptable provided the reactive power of the Generating Facility is used to meet the reactive power needs of on-site loads or that reactive power is otherwise provided under tariff by RPU. The Producer shall notify RPU if it is using the Generating Facility for power factor correction.
3. Control, protection and saf ety equipment requirements
a. Technology Specific Requirements
(1) Three-phase Synchronous Generators. For three-phase Generators, the circuit breaker s shall be three-phase devices with electronic or electromechanical control. The Producer shall be responsible for properly synchronizing its Generating Facility with the Distribution System by means of either a manual or automatic synchronizing function. Automatic synchronizing is required for all synchronous gener ators, which have a Short Circuit Contribution Ratio (SCCR) exceeding 0.05. A Generating Facility whose SCCR exceeds 0.05 shall be equipped with Protective Functions suitable fo r detecting loss of synchronism City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-11
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
and rapidly disconnecting the Generating Facility from the Distribution System. Unless otherwise agreed to between the Producer and RPU, synchronous generators shall automatically regulate power factor, not voltage, while operating in parallel with the Distribution System. Powe r system stabilization functions are specifically not required fo r Generating Facilities under 10 MW Net Nameplate Rating. Sync hronization means that at the time of connection, the frequency difference shall be less than
0.2 Hz, the voltage difference shall be less than 10%, and the phase angle difference shall be less than 10 degrees.
(2) Induction Generators. Induction Generators do not require a synchronizing function. Starting or rapid load fluctuations on induction generators can adverse ly impact the Distribution System’s voltage. Corrective step-switched capacitors or other techniques may be necessary and may cause undesirable
ferroresonance. When these counter measures (e.g. additional capacitors) are installed on the Producer’s side of the Point of Common Coupling, RPU must review these measures.
Additional equipment may be required as determined in a Supplemental Review or an Interconnection Study.
(3) Inverter Systems. Utility-interactive inverters do not require separate synchronizing equipment. Non-utility-interactive or “stand-alone” inverters shall not be used for parallel operation with the Distribution System.
b. Supplemental Generating Facility Requirements
(1) Unintended Islanding For Gene rating Facilities that fail the Export Screen (Section I.3.b.) Generating Facilities must mitigate their potential contribution to an Unintended Island. This can be accomplished by one of the following options: (1) incorporating certified Non-Isl anding control functions into the Protective Functions, or (2) verify ing that local loads sufficiently exceed the Net Nameplate Rating of the Generating Facility, or (3) incorporating a transfer trip or an equivalent Protective Function.
(2) Fault Detection. A Generating Facility with an SCCR exceeding
0.1 or that does not meet any one of the options for mitigating Unintended Islands in D.3.b.1 shall be equipped with Protective Functions designed to detect Dis tribution System faults, both line-to-line and line-to-ground, and promptly cease to energize the Distribution System in the event of a fault. For a Generating Facility that cannot detect these faults within two seconds, a City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-12
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
transfer trip or equivalent func tion may be required. Reclose- blocking of RPU’s affected recloser(s) may also be required by RPU for generators that exceed 15% of the peak load on the Line Section.
E. INTERCONNECTION FACILITY OWNERSHIP AND FINANCING
1. Scope and Ownership of Interconnection Facilities
a. Scope. The interconnection of a Producer’s Generating Facility with RPU’s Distribution System is made through the use of Interconnection Facilities. Such interconnection may also require Distribution System improvements. The type, extent and costs of Interconnection Facilities and Distribution System Improvements shall be co nsistent with this Rule and determined through the Init ial Review and Interconnection Study described in Section C.
b. Ownership. Interconnection Facilities in stalled on Producer’s side of the Point of Common Coupling may be owned, operated and maintained by the Producer or RPU. Interconnection Facilities installed on RPU’s side of the Point of Common Coupling and Distribution System improvements shall be owned operated and maintained by RPU.
2. Responsibility for Costs of In terconnecting a Generating Facility
a. Study and Review Costs. A Producer shall be responsible for the reasonably incurred costs of the reviews and studies conducted pursuant to Section C.1 of this Rule.
b. Facility Costs. A Producer shall be responsible for all costs associated with Interconnection Facilities owned by the Producer. The Producer shall also be responsible for any costs reasonably incurred by RPU in providing, operating, or maintain ing Interconnection Facilities and Distribution System improvements required solely for the interconnection of the Producer’s Generating Facility with RPU’s Distribution System.
c. Separation of Costs. Should RPU combine the installation of Interconnection Facilities, or Distri bution System Improvements with modifications or additions to RPU’s Distribution System to serve other Customers or Producers, RPU shall not include the costs of such separate or incremental facilities in the amounts billed to the Producer for the Interconnection Facilities or Distribution System Improvements required pursuant to this Rule.
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-13
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
3. Installation and Financing of Distribution System Improvements
a. Agreement Required. Costs for Added Facilities shall be paid by the Producer pursuant to the provisions contained in the Generating Facility Interconnection Agreement. Where the type and extent of the Interconnection Facilities and Distr ibution System Improvements warrant additional detail, the detail shall be found in a separate agreement between the Producer and RPU, and RPU’s applicable rate schedules and rules for Added Facilities.
b. Attachments and Modificatio ns to Distribution System. Except as provided for in Section E.3.c of th is Rule, Interconnection Facilities connected directly to RPU’s Distr ibution System and Distribution System Improvements shall be pr ovided, installed, owned and maintained by RPU as Added Facilities.
c. Reservation of Unused Facilities. When a Producer wishes to reserve RPU-owned Interconnection Faci lities or Distribution System Improvements installed and financed as Added Facilities for the Producer, but idled by a change in the operation of the Producer’s Generating Facility or otherwise, Producer may elect to abandon or reserve such facilities consistent with the terms of its agreement with RPU. If Producer elects to reserve idle Interconnection Facilities or Distribution System Improvements, RPU shall be entitled to continue to charge Producer for the costs rela ted to the ongoing operation and maintenance of the Added Facilities.
d. Refund of Salvage Value. When a Producer elects to abandon the Added Facilities for which it has eit her advanced the installed costs or constructed and transferred to RPU, the Producer shall, at a minimum, receive from RPU a credit for t he net salvage value of the Added Facilities.
F. METERING, MONITO RING AND TELEMETRY
1. General Requirements. All Generating Faciliti es shall be metered in accordance with this Section and shall meet all applicable standards of RPU’s applicable rate schedules, rules, and published RPU manuals dealing with metering specifications. The requirem ents in this Section do not apply to metering of Generating Facilities oper ating under RPU’s net metering tariff pursuant to California Public Utilities Code Section 2827.
2. Metering by Third Parties. The ownership, installa tion, operation, reading, and testing of metering for Generating Facilities shall be by RPU.
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-14
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
3. Net Generation Metering. For purposes of moni toring Generating Facility operation for determination of standby charges and applicable non-bypassable charges as defined in RPU’s rate sc hedules, and for Distribution System planning and operations, consistent with Section B.4 of these Rules, RPU shall have the right to specif y the type, and require th e installation of, Net Generation Metering. RPU shall require the provision of generator output data to the extent reasonably necessary to provide information for the utility to administer its tariffs or to operate and plan its system. RPU shall only require Net Generating Metering to the extent that less intrusive and/or more cost effective options for providing the nec essary generator output data are not available. In exercising its discretion to require Net Generation Metering, RPU shall consider all relevant factors, including but not limited to:
a. Data requirements in proportion to need for information; b. Customer election to insta ll equipment that adequately addresses RPU’s operational requirements;
c. Accuracy and type of required metering consistent with purposes of collecting data;
d. Cost of metering relative to the need for and accuracy of the data; e. The project size relative to t he cost of the metering/monitoring; f. Other means of obtaining the dat a (e.g. generator logs, proxy data, etc.);
g. Requirements under any powe r purchase agreement with the Customer.
4. Point of Common Coupling Metering. For purposes of assessing RPU charges for retail service, the Electricity Producer’s Point of Common Coupling Metering shall be a bi-directional meter so that power deliveries to and from the Electricity Producer’s site can be s eparately recorded. Alternately, the Electricity Producer may, at its sole option and cost, require RPU to install multi-metering equipment to separately record pow er deliveries to the Distribution System and retail purchases from RPU. Such Point of Common Coupling Metering shall be designed to prevent reverse registration.
5. Telemetering. If the nameplate rating of the G enerating Facility is 1 MW or greater, Telemetering equipment at the Net Generator Metering location may be required at the Electricity Producer’s (and Customer’s) expense. If the Generating Facility is interconnected to a Distribution System operating at a voltage below 10 kV, then Telemeteri ng equipment may be required on Generating Facilities 250 kW or greater. RPU shall only require Telemetering to the extent that less intrusive and more cost effective options for providing the necessary data in real time are not available.
6. Location. Where RPU-owned metering equipment is located on the Electricity Producer’s (or Customer’s) premises, Electricity Produc er (and Customer) City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-15
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
shall provide, at no expens e to the RPU, a suitable location for all such metering equipment.
7. Costs of metering. The Electricity Producer (and Customer) will bear all costs of the metering required by this Rule , including the incremental costs of operating and maintaining the metering.
G. DISPUTE RESOLUTION PROCESS
Any disputes arising from this Rule shall be submitted in writing by the Producer or Customer to the Board of Public Utilities for resolution. Their decision shall be final.
H. DEFINITIONS
Active Anti-Islanding Scheme: A control scheme inst alled with the Generating Facility that senses and prevents the formation of an Unintended Island.
Applicant: The entity submitting an Application for Interconnection pursuant to this Rule.
Application: A standard RPU form submitted to RPU requesting Interconnection of a Generating Facility.
Certification Test: A test pursuant to this Rule that verifies conformance of certain equipment with RPU-approved per formance standards in order to be classified as Certified Equipment. Certification Tests are performed by NRTLs.
Certification; Cert ified; Certificate: The documented results of a successful Certification Testing.
Certified Equipment: Equipment that has passed all required Certification Tests.
Commissioning Test: A test performed during the commissioning of all or part of a Generating Facility to achieve one or more of the following:
Verify specific aspects of its performance;
Calibrate its instrumentation;
Establish instrument or Protective Function set-points.
Customer: The entity that receiv es or is entitled to re ceive Distribution Service through the Distribution System.
Dedicated Transformer; Dedicated Distribution Transformer: A transformer that provides electricity service to a single Customer. The Customer may or may not have a Generating Facility.
Distribution Service: All services required by, or provided to, a Customer pursuant to the approved rate schedules and rules of RPU.
Distribution System: All electrical wires, equipm ent, and other facilities owned or provided by RPU by which RPU provides Distribution Service to its Customers.
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-16
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
Emergency: An actual or imminent condition or situation, which jeopardizes the Distribution System integrity.
Field Testing: Testing performed in the field to determine whether equipment meets RPU’s requirements for safe and reliable Interconnection.
Generating Facility: All Generators th at are included in an Interconnection Agreement.
Generator: An individual electrical power plant (including required equipment, appurtenances, protective equipm ent and structures) that is capable of Distributed Generation. A Generator is part of a Generating Facility.
Gross Nameplate Rating: The total gross generating capacity of a Generator or Generating Facility as designated by the manufacturer of the Generator.
Host Load: Electrical power that is consumed by the Custom er at the pr operty on which the Generating Facility is located.
Initial Review: The review by RPU, following receipt of an Application, to determine the following:
a) the Generat ing Facility qualifies for Simplified Interconnection; or b) the Generating Facility can be m ade to qualify for Interconnection with Supplemental Review determining any potential additional requirements; or c) if neither a nor b, prov ides the cost estimate and schedule for performi ng an Interconnection Study.
In-rush Current: The current determined by the In-rush Current Test.
Interconnection; (Interconnected): The physical connecti on of a Generating Facility in accordance with the requirements of this Rule so that Parallel Operation with the Distribution System can occur (has occurred).
Interconnection Agreement: An agreement between RP U and the Producer that gives certain rights and obligations to effect or end Interconnection. Customers with Generating Facilities qualifying under the Self-Generation Program do not require an Interconnection Agreement.
Interconnection Facilities: The electrical wires, s witches and related equipment that are required in addition to the facilitie s required to provide electric Distribution Service to a Customer to allow Interconnec tion. Interconnection Facilities may be located on either side of the Point of Common Coupling as appropriate to their purpose and design. Interconnection Facilit ies may be integral to a Generating Facility or provided separately. Interconnection Facilities may be owned by either Producer or RPU.
Interconnection Study: A study to establish the requirements for Interconnection of a Generating Facility.
Island; Islanding: A condition on the Distribution System in which one or more Generating Facilities deliver power to Cust omers using a portion of the Distribution System that is electrically isolated from the remainder of the Distribution System.
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-17
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
Line Section: That portion of the Distributi on System connected to a Customer bounded by automatic sectionalizing devices or the end of the distribution line.
Momentary Parallel Operation: The interconnection of a Generating Facility to the Distribution System for one second (60 cycles) or less.
Nationally Recognized Test ing Laboratory (NRTL): A laboratory accredited to perform the certification testing requirements under this Rule.
Net Energy Metering: Metering for the receipt and delivery of electricity between the Producer and RPU pursuant Section 2827 of the Public Utilities Code. Over a given time frame (typically a month) the difference between these two values yields either net consumption or surplus. The meter registers are ra tcheted to prevent reverse registration. If available, a single meter may be allowed to spin backward to yield the same effect as a directional, two meter (or register) arrangement.
Net Generation Metering: Metering of the net electric al power or energy output in kW or kWh, respectively, from a given G enerating Facility. This may also be the measurement of the differ ence between the total electr ical energy produced by a Generating Facility and the electrical ener gy consumed by the auxiliary equipment necessary to operate the Generating Facility. For a Generating Facility with no Host Load or no Public Utilities Code Section 21 8 Load, Metering that is located at the Point of Common Coupling. For a Generating Facility with Host Load or Section 218 Load, Metering that is located at the Generating Facility bus after the point of auxiliary load(s) and prior to serving Host Load or Section 218 Load.
Net Nameplate Rating: The Gross Nameplate Rati ng minus the consumption of electrical power of a Gener ator or Generating Facilit y as designated by the manufacturer(s) of the Generator(s).
Network Service: More than one electrical feeder providing Distribution Service at a Point of Common Coupling.
Non-Export; Non-Exporting: Designed to prevent the trans fer of electrical energy from the Producer to RPU.
Non-Islanding: Designed to detect and disconnect from a stable Unintended Island with matched load and generation. Relia nce solely on under/over voltage and frequency trip is not considered sufficient to qualify as Non-Islanding.
Parallel Operation: The simultaneous operation of a Generator with power delivered or received by RPU while Interconnected. For the purpose of this Rule, Parallel Operation includes only those generators that are interconnected with the Distribution System for more than one second (60 cycles).
Periodic Test: A test performed on part or all of a Generating Facility at pre- determined time or operational intervals to achieve one or more of the following:
Verify specific aspects of its performance;
Calibrate instrumentation;
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-18
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
Verify and re-establish instrument or Protective Function set-points.
Point of Common Coupling Metering: Metering located at the Point of Common Coupling. This is the same Metering as Net Generation Metering for Generating Facilities with no Host Load or no Section 218 Load.
Point of Common Coupling (PCC): The transfer point for electricity between the electrical conductors of RPU and the electrical conductors of the Producer.
Point of Interconnection: The electrical transfer poi nt between a Generator or a Generating Facility and the electrical system. This may or may not be coincident with the Point of Common Coupling.
Power Purchase Agreement (PPA): An arrangement for the sale of electricity by the Producer to RPU.
Producer: The entity that executes an Inte rconnection Agreement with RPU. The Producer may or may not own or operate the Generating Facility, but is responsible for the rights and obligations related to the Interconnection Agreement.
Production Test: A test performed on each device coming off the production line to verify certain aspects of its performance.
Protective Function(s): The equipment, hardware or software in a Generating Facility (whether discrete or integrated with other functions) whose purpose is to protect against Unsafe Operating Conditions.
Prudent Electrical Practices: Those practices, methods, and equipment, as changed from time to time, that are commonly used in prudent electrical engineering and operations to design and operate electr ic equipment lawfully and with safety, dependability, efficiency, and economy.
Scheduled Operation Date: The date specified in t he Interconnection Agreement when the Generating Facility is, by the Producer’s estimate, expected to begin operation pursuant to this Rule.
Secondary Network: A network supplied by several primary feeders suitably interlaced through the area in order to achieve acceptable loading of the transformers under emergency conditions and to provi de a system of extremely high service reliability. Secondary networks usually operate at 600 V or lower.
Section 218 Load: Electrical power that is s upplied in compliance with California Public Utilities Code Section 218. Pub lic Utilities Code 218 defines an “Electric Corporation” and provides conditions under which a generator transaction would not classify a generating entity as an Electric Corporation. These conditions relate to “over-the-fence” sale of electricity from a generator wit hout using the Distribution System.
Self-Generation Program: Applicable to all end-use Eligible Customer-Generators.
An Eligible Customer Generator is a residential, commercial, industrial or agricultural Customer who uses a Renewable Electrical Generation Facility, or a combination of City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-19
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
those facilities, with a capacity of not more than 5,000 kilowatts, that is located on the Customer’s owned, leased, or rented premises, and is interconnected and operates in parallel with the Utility’s distribution facilities, and is intended primarily to offset part or all of the Customer’s ow n electrical requirements on the premises. Under this program maximum net export of the Generation Facility shall not exceed 1,000 kilowatts.
Simplified Interconnection: Interconnection conforming to the minimum requirements under these rules, as determined by Section I.
Short Circuit Contribution Ratio (SCCR): The ratio of the Generating Facility’s short circuit contribution to RPU’s short circuit contribution for a three-phase fault at the high voltage side of the distribution transformer connecting the Generating Facility to RPU’s system.
Single Line Diagram; Single Line Drawing: A schematic drawing, showing the major electrical switchgear, protection dev ices, wires, generators, transformers and other devices, providing sufficient detail to communicate to a qualified engineer the essential design and safety of the system being considered.
Stabilization; Stability: The return to normalcy of the RPU Distribution System, following a disturbance. Stab ilization is usually measured as a time period during which voltage and frequency are within acceptable ranges.
Starting Voltage Drop: The percentage voltage drop at a specified point resulting from In-rush Current. The Starting Voltage Drop can also be expressed in percentage on a particular base voltage, (e.g. 6 volts on a 120-volt base, yielding a 5% drop).
Supplemental Review: A process wherein RPU further reviews an Application that fails one or more of the Initial Review Process screens. The Supplemental Review may result in one of the following: a) Simplified Interconnection; b) approval of Interconnection with additional requirements; or c) cost and schedule for an Interconnection Study.
System Integrity: The condition under which a Distribution System is deemed safe and can reliably perform its intended functions in accordance with the safety and reliability rules of RPU.
Telemetering: The electrical or electronic transmittal of metering data in real-time to RPU.
Transfer Trip: A Protective Function that trip s a Generating Facility remotely by means of an automated communications link controlled by RPU.
Type Test: A test performed on a sample of a particular model of a device to verify specific aspects of its design, construction and performance.
Unintended Island: The creation of an island, usually following a loss of a portion of the Distribution System, without the approval of RPU.
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-20
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
Unsafe Operating Conditions: Conditions that, if left uncorrected , could result in harm to personnel, damage to equipment, lo ss of System Integrity or operation outside pre-established parameters required by the Interconnection Agreement.
Visible Disconnect: An electrical switching device that can separate the Generating Facility from the Distribution System and is designed to allow visible verification that separation has been accomplish ed. This requirement can be met by opening the enclosure to observe the contact separation.
I. Initial Review Process for Applications to Interconnect a Generating Facility
1. Introduction. This Initial Review Process was developed to create a path for selection and rapid approval for t he Interconnection of those Generating Facilities that do not require an In terconnection Study. The Initial Review process includes a screening to determine if a supplemental review is required.
2. Purpose. The Initial Review determines:
a. If a Generating Facility qualif ies for Simplified Interconnection; b. If a Generating Facility can be m ade to qualify for Interconnection with Supplemental Review determining any potential additional requirements, or
c. If an Interconnection Study is require d, the cost estimate and schedule for performing the Interconnection Study.
NOTE: Failure to pass any screen of the Initial Review means only that further review or studies are required before the Generating Facility can be approved for interconnection with the RPU Distributi on System. It does not mean that the Generating Facility cannot be interconnected.
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-21
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
Initial Review Process Flow Chart
Y e s
N o
Y e s
N o
N o
Y e s
N o
Y e s
N o
Y e s
N o
N o
Y e s
N o
Y e s N o
Applicant provides completed Application.
1. Is the PCC on a Networked Secondary System?
2. Will Power be exported across the PCC?
3. Is the Interconnection Equipment Certified for the
proposed application? or
Does the Interconnection Equipment have
Interim RPU Approval?
4. Is the aggregate Generating Facility Capacity on the Line Section less than 15% of Line Section peak load?
Does Supplemental Review determine requirements?
5. Is the Starting Voltage Drop screen met?
6. Is the Gross Nameplate Rating of the Generating
Facility Capacity 11 kVA or less?
Perform Supplemental Review
7. Is the Short Circuit Current Contribution
screen met?
8. Is the Line Configuration screen met?
Generating Facility qualifies for
Simplified Interconnection
subject to the provisions of
Rule 22
Generating Facility qualifies for
Simplified Interconnection
subject to the provisions of Rule
22 EC provides cost estimate
and schedule for
Interconnection
Stud
y
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-22
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
3. Initial Review Process Details
a. Screen 1: Is the PCC on a Networked Secondary System? If No, continue to next screen
If Yes, the Generating Facility does not qualify for Simplified Interconnection.
Perform Supplemental Review.
Significance:
Special considerations must be given to the Generating Facilities proposed to be installed on networked secondary distribut ion systems because of the design and operational aspects of network protectors. There are no such considerations for radial distribution systems.
b. Screen 2: Will power be exported across the PCC?
If Yes, the Generating Facility does not qualify for Simplified Interconnection.
Perform Supplemental Review.
If No, the Generating Facility must inco rporate one of the following four options:
Option 1:
To ensure power is never exported, a reverse power Protective Function must be implemented at the PCC.
Default setting shall be 0.1% (export) of transformer rating, with a maximum 2.0 second time delay.
Option 2:
To ensure at least minimum import of power an under-power Protective Function must be implemented at the PCC.
Default setting shall be 5% (import) of the Generating Fac ility Gross Nameplate Rating, with maximum 2.0 second time delay.
Option 3:
To limit the incidental export of power, all of the following conditions must be met:
The aggregate capacity of the Generating Facility must be no more than 25% of the nominal ampere rating of the Customer’s Service Equipment;
The total aggregate Generating Facility capacity must be no more than 50% of the service transformer rating. (This capacity requirement does not apply to Customers taking primary service without and intervening transformer);
The Generating Facility must be certified as Non-Islanding.
Option 4:
To ensure that the relative size (capac ity) of the Generating Facility compared to facility load results in no export of power without the use of additional devices, the Generating Facility capacity must be no greater than 50% of the Customer’s verifiable minimum load over the last 12 months.
Significance:
(1) If it can be assured that the Generating Facility will not export power, RPU’s Distribution System does not need to be studied for load-carrying capability or Generating Facility power flow e ffects on RPU voltage regulators as the Generating Facility will simply be reducing Customer’s load on RPU’s Distribution System.
(2) Permits use of reverse-power relaying at the PCC as positive anti-islanding protection.
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-23
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
c. Screen 3: Is the Interconnection Equipment Certified for the Application or does the Interconnection Equipment have Interim RPU Approval? If No, the Generating Facility does not qualify for Simplified Interconnection.
Perform Supplemental Review.
If Yes, continue to next screen.
Significance:
If the Generating Facility has been Certifi ed or previously approved by RPU, RPU does not need to repeat its review and/or test of the Generating Facility’s Protective Functions scheme. Site Commissioning Test ing may still be requir ed to ensure that the system is connected properly and that the protective functions are working properly.
Certification indicates the following criteria have been tested and verified:
- Basic protective function requirements.
- Harmonic distortion limits.
- Synchronizing requirements.
- Power factor regulation requirements.
- Non-Islanding requirements
- If used, reverse power function requirement.
- If used, under-power function requirement.
d. Screen 4: Is the aggregate Generating Facility capacity on the Line Section less than 15% of Line Section Peak Load?
If Yes, continue to next screen.
If No, Generating Facility does not qualify for Simplified Interconnection.
Perform Supplemental Review to determine cumulative impact on Line Section.
Significance:
Low penetration of Generating Facility installations will have a minimal impact on Distribution System and load operation and power restoration.
The operating requirements for a high penetration of Generating Facilities may be different since the impact on RPU’s Distribution System operation will no longer be minimal, therefore requiring additional study or controls.
e. Screen 5: Is the Starting Voltage Drop Within Acceptable Limits? If Yes, continue to next screen
If No, the Generating Facility does not qualify for Simplified Interconnection.
Perform Supplemental Review to determine cumulative impact on Line Section.
NOTICE: This screen only applies to Generating Facilities that start by motoring the Generator.
RPU has two options in determining w hether Starting Voltage Drop could be a problem; which option to use is at RPU’s discretion.
Option 1:
RPU may determine that the Generating Fac ility’s starting Inrush Current is equal to or less than the continuous ampere rating of the Customer’s service equipment.
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-24
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
Option 2:
RPU may determine the impedances of the service distribution transformer (if present) and secondary conductors to Customer’s service equipment and perform a voltage drop calculation. Alternatively, RPU may use tables or nomographs to determine the voltage drop. Voltage drops caused by starting a Generating Unit as a motor must be less than 2.5% for primary interconnection and 5% for secondary interconnection.
Significance:
(1) This screen addresses potential voltage fluctuation problems for generators that start by motoring.
(2) When starting, a Generating Facility s hould have minimal impact on the service voltage or other RPU Customers.
(3) Passing this screen does not relieve the Producer from ensuring that its Generating Facility complies with the flicker requirements of this Rule, Section D.
f. Screen 6: Is the Gross Nameplate Rating of the Generating Facility 11 kVA or less?
If Yes, the Generating Facility qualifies for Simplified Interconnection. Skip remaining screens.
If No, continue to next screen
Significance:
The Generating Facility has minimal impact on fault current levels and any potential line overvoltages from loss of system neutral grounding.
g. Screen 7: Is Short Circuit Current Contribution Within Acceptable Limits?
If No, the Generating Facility does not qualify for Simplified Interconnection.
Perform Supplemental Review.
If Yes, continue to next screen.
Short Circuit Current Contribution Screen:
The Short Circuit Current Contribution Scre en consists of two criteria; both of which must be met when applicable:
(1) At primary side (high side) of the D edicated Distribution Transformer, the sum of the Short Circuit Contribution Ratios (SCCR) of all Generating Facilities on the Distribution System circuit may not exceed 0.1.
(2) At secondary (low side) of a shared di stribution transformer, the short circuit contribution of the proposed Generating Facility must be less than or equal to
2.5% of the interrupting rating of the Producer’s Service Equipment .
Significance:
No significant Generating Facility impact on:
(1) Distribution System’s short circuit duty
(2) Distribution System fault detection sensitivity
(3) Distribution System relay coordination
(4) Distribution System fuse-saving schemes
If the Generating Facility passes this screen it can be expected that it will have no significant impact on RPU’s Distribution S ystem’s short circuit duty, fault detection sensitivity, relay coordination or fuse-saving schemes.
h. Screen 8: Is the Line Configuration Acceptable for Simplified Interconnection?
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-25
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
If No, then the Generating Facility does not qualify for Simplified Interconnection.
Perform Supplemental Review.
If Yes, the Generating Facility qualifies for Simplified Interconnection.
Line Configuration Screen:
Identify primary distribution line configuration that will serve the proposed Generating Facility. Based on the type of Interconnection to be used for the Generating Facility, determine from the following table if the proposed Generating Fa cility passes the screen.
Significance:
If the primary distribution circuit serving the Generating Facility is of a three-wire type, or if the Generating Facility’s Interco nnection transformer is single-phase and connected in a line-to-neutral configurat ion, then there is no concern about overvoltages to RPU’s or other Customer’s equipment caused by loss of system neutral grounding during the operating time of anti-islanding protection.
J. Testing and Certification Criteria
1. Introduction
This Section describes the test pr ocedures and requirements for equipment used for the Interconnection of a Gener ating Facility to RPU’s Distribution System. Included are Ty pe Testing, Production Te sting, Commissioning Testing, and Periodic Testing. The pr ocedures listed rely heavily on those described in applicable Under writers Laboratory (UL), In stitute of Electrical and Electronic Engineers (IEEE), and International Electrotechnical Commission (IEC) documents – most notably UL 1741 and IEEE 929 – as well as the testing described in the New Yo rk State Public Service Commission’s Interconnection requirements 1. These procedures and requirements were developed prior to the completion of IEEE P1547.
1 “New York State Standardized Interconnection Requirements, A pplication Process, Contract & Application Forms For New Distribu ted Generators, 300 Kilovolt - Amperes or Less, Connected In Parallel with Radial Distribution Lines”, November 9, 2000.
Standard for Distributed Resources In terconnected with Electric Power Systems, and should be revisited once that standard is published. The tests Primary Distribution Line
Type
Type of Interconnection
to Primary Distribution
Line
Result/Criteria
Three-phase, three wire Any Pass screen
Three-phase, four wire Single-phase, line-to-
neutral
Pass screen
Three-phase, four wire
(For any line that has
such a section OR mixed
3 wire & 4 wire)
All others To pass, aggregate
Generating Facility
Capacity must be less
than or equal to 10% of
Line Section Peak
Load.
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-26
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
described here, together with the technical requirem ents in Section D of this Rule, are intended to provide assuranc e that the Generating Facility’s equipment will not adversely affect RPU’s Distribution Syst em and that a Generating Facility will ceas e providing power to RP U’s Distribution System under abnormal conditions. The tests we re developed assuming a low level of Generating Facility penetra tion. At high levels of Generating Facility penetration, other requirements and corresponding test procedures may need to be defined.
This test specification also provides a means of certifying equipment. Once a Generating Unit or device has been Certified per this Certification Process, it may be considered to be suitable for use as part of a Generating Facility interconnected with RPU’s Distribution Sy stem. Subject to the exceptions described in this Section, RPU will not require a Producer to repeat the design review or test the Protective Functions of equipment that has been Certified.
It should be noted the Certification process is intended to facilitate Generating Facility interconnections. Certification is not a prerequisite to interconnect a Generating Facility. The use of non- certified equipment may be acceptable subject to testing and approval by RPU as discussed below.
2. Certification Criteria
Equipment tested and approved (e.g. lis ted) by a NRTL as having met both the Type Testing and Production Testing requirements is considered to be Certified Equipment for purposes of Interconnection with RPU’s Distribution System. Certification may apply to either a pre-packaged system or an assembly of components that address the necessary functions. Type Testing may be done in the factory/test lab or in the field. At the discretion of the testing laboratory, field-certification may apply only to the particular installation tested.
In such cases, some or all of t he tests may need to be repeated at other installations.
The use of Certified Equipment is not a requirement for interconnection.
However, the use of Certified Equi pment will simplify the interconnection approval process by reducing Co mmissioning and additional test requirements. For non-certified equipment, some or all of the tests described in this document may be required by RPU for each Generating Facility. The manufacturer or a laboratory acceptable to RPU may perform these tests. Test results for non-certified equipment must be submitted to RPU as part of the application process for RPU’s review and approval under the Supplemental Review. Approval by RPU for equipment used in a particular application does not guarantee RPU approval for use in other applications or by other California electric utilities.
When equipment is Certified by a NRT L, the NRTL shall provide to the manufacturer, at a minimum, a Certif icate with the following information for each device:
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-27
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
a. Administrative:
(1) Effective date of certification or applicable serial number (range or first in series), other proof that certification is current
(2) Equipment model number (s)
(3) Software version, if applicable
(4) Test procedures specified (including date or revision number)
(5) Laboratory accreditation (by whom and to what standard)
b. Technical (As appropriate)
(1) Device rating (k W, kVA, V, A, etc.)
(2) Maximum available fault current, A
(3) In-rush current, A
(4) Trip points, if factory set (trip value and timing) (5) Trip point and timing ranges for adjustable settings (6) Nominal power factor or range if adjustable
(7) If the device/system is ce rtified for non-export and the method used (reverse power or under power)
(8) If the device/system is certified non-islanding
It is the responsibility of the equipment manufacturer to ensure that certification information is made publicly available by the manufacturer, the testing laboratory, or by a third party. A sample certification information form is provided in Appendix K.
3. Type Testing
Type testing provides a basis for det ermining that equipment is designed appropriately and meets the specifications for being designated as Certified Equipment under this Rule. The requirements described in this section cover only issues related to Interconnection and are not intended to address device safety or other issues outside the needs of the relationship between RPU and the Producer operating a Generating Facility.
The following table defines the test requirements by technology. Test References that are preceded by “UL 1741” refer to the section numbers of the document that describe the test requirements
.2 While UL 1741 was written
specifically for photovoltaic inverters, the requirements are readily adapted to City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-28
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
inverter-based Generating Facilities, synchronous machines, induction machines, as well as single/multi-func tion controllers and protection relays.
Until a standardized test procedure is specified, RPU or NRTL shall adapt the procedures referenced in the following table as appropriate and necessary for a machine’s performance and its control and protection system functions.
Type Tests and Requirements for Interconnection Equipment Certification
Type Test
Reference1
Inverter
Synchronous
Machine
Induction
Machine
Utility Interaction UL 1741 – 39 X X X
DC Isolation UL 1741 – 40.1 X --- ---
Simulated PV Array
(Input)Requirements
UL 1741 – 41.2
X
---
---
Dielectric Voltage Withstand UL 1741 – 44 X X X
Power Factor UL 1741 – 45.2.2 X X X
Harmonic Distortion UL 1741 – 45.4 X X X
DC Injection UL 1741 – 45.5 X --- ---
Utility Voltage and
Frequency Variation
UL 1741 – 46.2
X
X
X
Reset Delay UL 1741 – 46.2.3 X X X
Loss of Control Circuit UL 1741 – 46.4 X X X
Short Circuit UL 1741 – 47.3 X X X
Load Transfer UL 1741 – 47.7 X X X
Surge Withstand J.3.a X X X
Anti Islanding J.3.b (2) (2) (2)
Non-Export J.3.c (3) (3) (3)
In-Rush Current J.3.d (4) (4) (4)
Synchronization J.3.e (5) X ---
Notes: X = Required; - = Not required
Table Notes:
(1) Reference refers to section number in either UL 1741 or this Rule. References within UL1741 to “photovoltaics” or “inverter” may have to be interrupted by the testing laboratory to appropriately apply the tests to other technologies.
(2) Required only if Non-Islanding designation is desired. (3) Required only if Non-Export designation is desired. (4) Required for devices that use RPU power to motor to speed. (5) Required for all synchronous machines as well as inverters that operate as voltage sources when connected to RPU.
___________________________________
2 UL 1741, Inverters, Converters and Charge Controllers for use in Independent Power Systems, Revised January 2001
a. Anti-Islanding Test
Devices that are tested to and pass the Anti-Islanding test procedure described in UL 1741 Section 46.3 will be considered Non-Islanding for the purposes of these interconnecti on requirements. This test is City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-29
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
required only for devices for which a certified Non-Islanding designation is desired.
b. Non-Export Test
Devices that pass the Non-Export te st procedure described in Section J.7.a. will be considered Non-Exporti ng for the purposes of these interconnection requirements. This test is required only for devices for which a certified Non-Export designation is desired.
c. In-rush Current Test
Will be tested using the procedure defined in Section J.7.b. to determine the maximum current drawn during this startup process. The resulting in-rush current is used to estimate the starting voltage drop.
d. Surge Withstand Capability Test
Interconnection equipment shall be tested for surge withstand capability (SWC), both oscillatory and fast trans ient, in accordance with the test procedure defined in IEEE/ANSI C62.45 using the peak values defined in IEEE/ANSI C62.41 Tables 1 and 2 for location category B3. An acceptable result occurs even if the device is damaged by the surge, but is unable to operate or energize RP U’s Distribution System. If the device remains operable after being subject to the surge conditions, previous type tests related to RPU protection and power quality will need to be repeated to ensure the unit will still pass those tests following the surge test.
e. Synchronization Test
This test verifies that the uni t synchronizes within the specified voltage/frequency/phase angle requir ements. It is applied to synchronous generators and inverters capable of operating as voltage- sources while connected to RPU. This test is not necessary for induction generators or current- source inverters.
The test will start with only one of the three param eters --voltage difference between Generating Facili ty and RPU Distribution System, frequency difference, or phase angle --outside of the synchronization specification. Initiate the synchroni zation routine and verify that the Generating Facility is brought within specification prior to synchronization. Repeat the test fi ve times for each of the three parameters.
For manual synchronization with synch check or manual control with auto synchronization, the test must verify that paralleling does not occur until the parameters are brought within specifications.
4. Production Testing
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-30
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
As a minimum, the Utility Voltage and Frequency Variation Test procedure described in UL1741 under Manufacturing and Production Tests, Section 68 shall be performed as part of routine production (100 percent) on all equipment used to interconnect Generating Facilities to RPU’s Distribution System. This testing may be performed in the factor y or as part of a Commissioning Test (Section J.5).
5. Commissioning Testing
Commissioning Testing, where required, will be performed on-site to verify protective settings and functionality. Upon initial Parallel Operation of a Generating Facility, or any time interface hardware or software is changed that may affect the functions listed bel ow, a Commissioning Test must be performed. An individual qualifi ed in testing protective equipment (professional engineer, factory-certified technician, or licensed electrician with experience in testing protective equi pment) must perform commissioning testing in accordance with the manufacture’s recommended test procedure to prove the settings and requirements of this Rule.
The RPU has the right to witness Co mmissioning Tests as described below, or to require written cert ification by the installer describing which tests were performed and their results.
Functions to be tested during commissioning, particularly with respect to non- certified equipment, may consist of the following:
a. Over-and under-voltage
b. Over- and under-frequency
c. Anti-Islanding (if applicable)
d. Non-Export (if applicable)
e. Inability to energize dead line
f. Time delay restart afte r utility source is stable
g. Utility system fault detection (if used)
h. Synchronizing controls (if applicable)
i. Other interconnection protective func tions that may be required as part of the Interconnection Agreement
Other checks and tests that may need to be performed include:
a. Verifying final protective settings
b. Trip test
c. In-service test
a. Certified Equipment
Generating Facilities qualifying for Simplified Interconnection incorporate Certified E quipment that have, at a minimum, passed the Type Tests and Production Tests de scribed in this document, are judged to have little or no potent ial impact on RPU’s Distribution City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-31
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
System. For such Generating Facilities, it is necessary to perform only the following test:
1. Protection settings that have been changed after factory testing will require field verification. Tests will be performed using injected secondary voltages and currents, applied waveforms, a test connection using a generator to simulate abnormal utility voltage or frequency, or varying the set points to show that the device trips at the measured (actual) utility voltage or frequency.
2. Non-Islanding function, if included, will be checked by opening a load break disconnect switch to verify the interconnection equipment ceases to energize the line and does not re-energize for the required time delay after the switch is closed.
3. Non-Export function, if in cluded, will be checked using secondary injection techniques. This function may also be tested by adjusting the Generating Facility output and local loads to verify that the applicable non -export criteria (i.e., reverse power or under power) are met.
The Supplemental Review or an Interconnection Study may impose additional components or additional testing.
b. Non-Certified Equipment
Non-certified equipment shall be subj ected to the appropriate tests described in Type Testing (Section J.3. ) as well as those described in Certified Equipment (Section J.5.a.). With RPU approval, these tests may be performed in the factory, in the field as part of commissioning, or a combination of both. RPU, at its discretion, may also approve a reduced set of tests for a particular application or, for example, if it determines it has sufficient experience with the equipment.
c. Verification of Settings
If the testing is part of the co mmissioning process, then, at the completion of such test ing, the Producer shall confirm all devices are set to RPU-approved settings. This step shall be documented in the Commissioning Test Certification.
d. Trip Test
Interconnection protective devices (e.g. reverse power relay) that have not previously been tested as part of the interconnection system with their associated interrupting devices (e .g. contactor or circuit breaker) shall be trip tested during commissi oning. The trip test shall be adequate to prove that the associat ed interrupting devices open when the protective devices operate.
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-32
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
Interlocking circuits between protective devices or between interrupting devices shall be similarly tested unle ss they are part of a system that has been tested and approved during manufacture.
e. In-service Test
Interconnection protective devices that have not previously been tested as part of the interconnection system with their associated instrument transformers or that are wired in the field shall be given an in-service test during commissioning. This test will verify proper wiring, polarity, CT/PT ratios, and proper operation of the measuring circuits. The in- service test shall be made wit h the power system energized and carrying a known level of current. A measurement shall be made of the magnitude and phase angle of each ac voltage and current connected to the protective device and the results compared to expected values.
For protective devices with built-in metering functions that indicate current and voltage magnitudes and phase angles, or magnitudes of current, voltage, and real and reactive power, the metered values may be used for in-service testing. Otherwise, portable ammeters, voltmeters, and phase-angle meters shall be used.
6. Periodic Testing
Periodic Testing of Interconnection-related Protective Functions shall be performed as specified by t he manufacturer, or at leas t every four years. All periodic tests prescribed by the m anufacturer shall be performed. The Producer shall maintain periodic test repor ts or a log for inspection by RPU.
Periodic Testing conforming to RPU test intervals for the particular line section may be specified by RPU under special ci rcumstances, such as high fire hazard areas.
A system that depends upon a battery fo r trip power shall be checked and logged once per month for proper voltage. Once every four years, the battery must be either replaced or a discharge test performed.
7. Detailed Type Test Procedures and Requirements
This section describes the additional Type Test procedures necessary to qualify a device as Certified, for use on the RPU Distribution System. These Type Tests are not contained in Underwriters Laboratories UL 1741 Standard Inverters, Converters and Controllers for Use in Independent Power Systems, or other referenced standards.
a. Non-Export Test Procedure
The non-export test is intended to verify the operation of relays, controllers and inverters designed to limit the export of power and certify City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-33
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
the equipment as meeting the requirements of Screen 2, Options 1 and 2, of the Initial Review Process. Tests are provided for discrete relay packages and for controllers and inve rters that include the intended function.
(1) Reverse Power Relay Test
This version of the Non-Export test procedure is intended for stand-alone reverse power and under power relay packages provided to meet the requirements of Options 1 and 2 of the Non- Export Screen. It should be understood that in the reverse power application, the relay will provide a trip output with power in the export (toward RPU system) direction.
Step 1: Power Flow Test at Minimum, Midpoint and Maximum Pickup Level Settings
Determine the appropriate sec ondary pickup current for the desired export power flow of 0.5 secondary watts (the agreed- upon minimum pickup setting assumes 5 Amp and 120V CT/PT secondary). Apply nominal voltage with minimum current setting at 0 degrees in the trip direction. Increase the current to pick up level. Observe the relay’s (LCD or computer display) indication of power values. Note the indi cated power level at which the relay trips. The power indica tion should be within 2 percent of the expected power. For relays with adjustable settings, repeat this test at the midpoint, and maximum settings.
Repeat at phase angles of 90, 180, and 270 degrees and verify that the relay does NOT operate (measured watts will be zero or negative).
Step 2: Leading Power Factor Test
Apply rated voltage with a minimum pickup current setting (calculated value for system application) and apply a leading power factor load current in the non-trip direction (current lagging voltage by 135 degrees). Increase the current to relay rated current and verify that the relay does NOT operate. For relays with adjustable settings, this te st should be repeated at the minimum, midpoint, and maximum settings.
Step 3: Minimum Power Factor Test
At nominal voltage and with th e minimum pickup (or ranges) determined in Step 1, adjust the current phase angle to 84 or 276 degrees. Increase the current level to pickup (about 10 times higher than at 0 degrees) and veri fy that the relay operates.
Repeat for angles 90, 180, and 270 degrees and verify that the relay does NOT operate.
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-34
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
Step 4: Negative Sequence Voltage Test
Using the pickup settings determined in Step 1, apply rated relay voltage and current at 180 degrees from tripping direction, to simulate normal load conditions (for 3-phase relays, use I a at
180, Ib at 60 and Ic and 300 degrees). Remove Phase-1 voltage and observe that the relay does not operate.
Repeat for phase-2 and 3.
Step 5: Load Current Test
Using the pickup settings dete rmined in Step 1, apply rated voltage and current at 180 degrees from the tripping direction, to simulate normal load conditions (use I
a at 180, Ib at 300 and Ic at
60 degrees). Observe that the relay does NOT operate.
Step 6: Unbalanced Fault Test
Using the pickup settings dete rmined in Step 1, apply rated voltage and 2 times rated curren t, to simulate an unbalanced fault in the non-trip direction (use V
a at 0 degrees, V b and Vc at
180 degrees, I a at 180 degrees, I b at 0 degrees and I c at 180 degrees). Observe that the relay, especially single phase, does not misoperate.
Step 7: Time Delay Settings Test
Apply Step 1 settings and set time delay to minimum setting.
Adjust the current source to th e appropriate level to determine operating time, and compare against calculated values. Verify that the timer stops when the relay trips. Repeat at midpoint and maximum delay settings.
Step 8: Dielectric Test
Perform the test described in IEC 414 using 2 kV RMS for 1 minute.
Step 9: Surge Withstand
Perform the surge withstand test described in IEEE
C37.90.1.1989 or the surge withstand test described in Section J.3.g.
(2) Under Power Relay Test
In the underpower application, the relay will provide a trip output when import power (toward th e Producer) drops below the specified power level.
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-35
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
Note: For an underpower relay, pickup is defined as the highest power level at which the relay indicates that the power is less than the set setting.
Step 1: Power Flow Test at Minimum, Midpoint and Maximum Pickup Level Settings
Determine the appropriate sec ondary pickup current for the desired power flow pickup level of 5% of peak load (the agreed- upon minimum pickup setting). Apply rated voltage and current setting at 0 degrees in the direct ion of normal load current.
Decrease the current to pickup level. Observe the relay’s (LCD or computer display) indication of power values. Note the indicated power level at which the relay trips. The power indication should be within 2 percent of the expected power. For relays with adjustable settings, repe at the test at the midpoint, and maximum settings.
Repeat at phase angles of 90, 180, and 270 degrees and verify that the relay operates (measured watts will be zero or negative).
Step 2: Leading Power Factor Test
Using the pickup current setting determined in step 1, apply rated voltage and rated leading power factor load current in the normal load direction (current leading voltage by 45 degrees). Decrease the current to 145% of the pickup level determined in Step 1 and verify that the relay does NOT operate. For relays with adjustable settings, repeat the test at the minimum, midpoint, and maximum settings.
Step 3: Minimum Power Factor Test
At nominal voltage and with th e minimum pickup (or ranges) determined in Step 1, adjust the current phase angle to 84 or 276 degrees. Decrease the current level to pickup (about 10% of the value at 0 degrees) and verify t hat the relay operates. Repeat for angles 90, 180 and 270 degrees and verify that the relay operates for any current less than rated current.
Step 4: Negative Sequence Voltage Test
Using the pickup settings determined in Step 1, apply rated relay voltage and 25% of rated current in the normal load direction, to stimulate light load conditions. Remove Phase-A voltage and observe that the relay does not operate, repeat for phase-B and C.
Step 5: Unbalanced Fault Test
Using the pickup settings dete rmined in Step 1, apply rated voltage and 2 times rated curre nt, to stimulate an unbalanced City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-36
Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
fault in the normal load direction (use Va at 0 degrees, Vb and Vc at 180 degrees, I a at 0 degrees, I b at 180 degrees, and I c at 0 degrees). Observe t hat the relay, especially single phase, operates properly.
Step 6: Time Delay Settings Test
Apply Step 1 settings and set time delay to minimum setting.
Adjust the current source to th e appropriate level to determine operating time, and compare against calculated values. Verify that the timer stops when the relay trips. Repeat at midpoint and maximum delay settings.
Step 7: Dielectric Test
Perform the test described in IEC 414 using 2 kV RMS for 1 minute.
Step 8: Surge withstand
Perform the surge withstand test described in IEEE
C37.90.1.1989 or the surge withstand test described in Section J.3.g.
(3) Functional Test for Inverters and Controllers
Inverters and controllers design ed to provide reverse or under power functions shall be tested to certify the intended operation of this function. Two methods are provided.
Method 1: If the controller utilizes external current/voltage measurement to determine the reverse or underpower condition, then the controller shall be functi onally tested by application of appropriate secondary currents a nd potentials as described in the Reverse Power Relay Test, Section J.7.a.(1) of this Rule.
Method 2: If external secondary current or potential signals are not used, then unit-specific tests must be conducted to verify that power cannot be exported across the PCC for a period
exceeding two seconds. These tests may be factory tests, if the measurement and control points are part of a single unit, or may be provided for in the field.
b. In-Rush Current Test
This test will determine the maximum in-rush current drawn by the unit.
(1) Locked-Rotor Method
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Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
Use the test procedure defined in NEMA MG-1 (manufacturer’s data is acceptable if available).
(2) Start-up Method
Install and setup the Generating Facility equipment as specified by the manufacturer. Using a calibrated o scilloscope or data acquisition equipment with appropriate speed and accuracy, measure the current draw at the Point of Interconnection as the Generating Facility starts up and parallels with RPU’s Distribution System. St artup shall follow the normal, manufacturer-specified procedure.
Sufficient time and current resoluti on and accuracy shall be used to capture the maximum current draw within five percent. In-rush current is defined as the maximum current draw from RPU’s Distribution System during the startup process, using a 10-cycle moving average.
During the test, the utility source, real or simulated, must be capable of maintaining voltage within +/- five percent of rated at the connection to the unit under test. Repeat this test five times. Report the highest 10- cycle current as the in-rush current.
A graphical representation of the time-current characteristic along with the certified in-rush current must be included in the test report and made available to RPU.
City of Riverside Distributed G eneration Facilities Interconnection Public Utilities Department 22-38
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Effective Date:
Appendix 1
Utility Interconnection Equipment Certification Form
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Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
Utility Interconnection Equipment Certification
The information on this form is provided to indicate the compliance of the generation equipment listed below with the utility interconnection certification requirements defined in this Rule.
Certifying Laboratory The information on this form is provided by the following Nationally Recognized Test Laboratory:
Laboratory:_______________________________________________________
Contact Name:______________ Phone:_____________ E-mail:_____________
Address:_________________________________________________________
City:__________________________ State:__________ Zip:________________
Accredited by:_________________________________ Date:_______________
Accredited to (test standards)1:________________________________________
Equipment Specification The information on this form applies to the following equipment:
Equipment Manufacturer: ___________________________________________
Address:_________________________________________________________
City:___________________________ State:__________ Zip:_______________
Model Number(s):__________________________________________________
Software Version(s):________________________________________________
Effective 2:________________________________________________________
Device Description 3:________________________________________________
_________________________________________________________________________________________________
_________________________________________________________________________________________________
_________________________________________________________________________________________________
_________________________________________________________________________________________________
_________________________________________________________________________________________________
_________________________________________________________________________________________________
_________________________________________________________________________________________________ Test results 4
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Adopted by Board of Public Utilities: Board Resolution No.
Approved by City Council: Council Resolution No
Effective Date:
Mark the box next to each requirement that has been met and each test that has been performed and successfully passed. Provide an explanation of any exceptions or omissions on a separate sheet. List additional test documents used on separate sheet.
UL 1741: (Section number listed)
-39 -40.1 -41.2 -44 -45.2.2 -45.4 -45.5
-46.2 -46.2.3 -46.4 -47.3 -47.7 Optional -46.3
- IEEE/ANSI C62.45/C62.41 (location Category B3)
California Rule 21: -J.3.e Non-export -J.3.f. In-Rush Current -J.3.h. Synchronization
Device Rating
5: ___________________________________________________
Maximum available fault current, A ____________________________________ In-rush current6, A __________________________________________________ Trip settings7:
Nominal Power Factor (Range, if adjustable)
______________________________________
Non Islanding: Yes___ No ___ Maximum trip time: _______________________________ Non Export: Yes___ No ___ Method: ________________________________________
Setting 1 Setting 2 Setting 3 Setting 4 Setting 5 Factory Settings 8
Fast Over
Voltage
Setting
Measured
Fast Over
Voltage
Setting
Measured
Fast Over
Voltage
Setting
Measured
Fast Over
Voltage
Setting
Measured
Fast Over
Voltage
Setting
Measured
Fast Over
Voltage
Setting
Measured
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Approved by City Council: Council Resolution No
Effective Date:
NOTES
____________________________
1 Accreditation must apply to tests standards listed herein 2 Note here the date of certific ation, applicable serial number (range or first in series), or other information that indicates which units the certification applies to. 3 List appropriate functions, capabilities, applic ations, limitations, etc. Use additional sheets as necessary.
4 List all test documents (i .e. UL 1741, IEEE C62.45) and specific procedures (i.e. UL 1741 Sec 39.1 – 39.5, etc.) used to eval uate device’s suitability for utility interconnection.
5 kW, kVA, V, A, etc. as appropriate
6 For devices that use grid power to motor to speed
7 Trip value (Voltage in volts or frequency in Hz) and timing (in cycles). Devices with adjustable settings shall provide test results over the range of settings. For each test setting provide the setting values in the upper box and measured results in the lower box. List device ranges, if adjustable.
8 Provide any additional informati on that may be useful in evaluating these results such as test configurations, device settings used to meet requirements, etc. Use additional sheets if necessary.
03/22/02
City of Riverside
Public Utilities Department
Adopted by Board of Public Utilities: Board Resolution No:
Approved by City Council: Council Resolution No:
Effective Date:
SCHEDULE SELF‐GEN
SELF‐GENERATION PROGRAM FOR
RENEWABLE ELECTRICAL GENERATION FACILITIES
Applicability:
Applicable to all end‐use Eligible Customer‐Generators.
An Eligible Customer Generator is a residential, commercial, industrial or agricultural Customer who uses a Renewable Electrical Generation Facility, or a combination of those facilities, with a capacity of not more than 5,000 kilowatts, that
is located on the Customer’s owned, leased, or rented premises, and is interconnected and operates in parallel with the Utility’s distribution facilities, and is intended primarily to offset part or all of the Customer’s own electrical requirements on the premises.
Territory:
Within the service area
of the City of Riverside
Rates:
All rates charged under this schedule will be in accordance with the Eligible Customer‐Generator’s otherwise applicable tariff (OAT) or rate schedule, in effect from time to time. An Eligible Customer‐Generator served under this schedule is responsible for all charges in its OAT including
the monthly or annual minimum charges (including service, customer, reliability, network access, and demand charges, when applicable), regardless of the Customer’s monthly generation.
Eligible Customer‐Generators under this schedule are subject to any new or additional charge(s) that may be imposed by the Utility on the other customers in the rate class to which Customer would otherwise be assigned.
Eligible Customer‐Generators under this rate schedule with Residential Service for Single‐Family Dwelling Units qualifying will be assigned rate Schedule D‐TOU “Domestic Time‐Of‐Use Service” as their OAT.
Special Conditions:
1. Eligibility:
A customer is eligible for this
schedule after receiving final inspection approval of all required building permit applications from the City’s Building and Safety Division, or authority having jurisdiction, and the Utility’s requirements (“Permit Completion”) for final release of the Renewable Electrical Generation Facility to be energized.
2. Billing:
a. For each Billing Period, the Utility shall bill the Eligible Customer‐Generator for all (a) energy delivered to their Premises by the Utility and (b) other charges contained in their OAT.
b. For each Billing Period, an Eligible Customer‐Generator will receive a bill credit for each kilowatt‐ hour of energy supplied by their Renewable Electrical Generating Facility to the Utility. For each supplied kilowatt‐hour of energy, the energy credit shall be calculated by multiplying the Avoided Cost of Energy (ACOE) rate and, if applicable, the time of delivery factor (“Time of Delivery Factor”) for that supplied kilowatt hour. Each Billing Period, the bill credit will be used to offset the utility bill of the Eligible Customer‐Generator and, if there are any remaining energy credits, these energy credits will be applied to subsequent utility bills until the earlier of (1) the exhaustion of the energy credit; or (2) the termination of electric service. If any net energy credits exist at the termination of service, the Utility will pay the Eligible Customer‐Generator the value of the remaining energy credits.
c. The Utility shall provide each Eligible Customer‐Generator with delivered and supplied energy information on each bill.
City of Riverside
Public Utilities Department
Schedule SELF‐GEN – Self‐Generation Program For Renewable Electrical Generation Facilities ‐ 2‐
Adopted by Board of Public Utilities: Board Resolution No:
Approved by City Council: Council Resolution No:
Effective Date:
d. Each Eligible Customer‐Generator shall comply with all applicable federal, state, and local laws, including applicable Rates, Rules and Regulations and the Electric Utility’s current standards and guidelines.
3. Avoided Cost of Energy (“ACOE”):
a. The ACOE, also referred to as the buy back rate, represents the avoided Utility costs and is the amount the Utility will credit Eligible Customer‐Generators for energy supplied to the Utility by Renewable Electrical Generation Facilities.
b. Components of the ACOE include:
i. Avoided Generation Energy Costs: Savings resulting from reduced purchases from the California Independent Systems Operator (CAISO) valued at the day ahead hourly locational marginal price of energy at the Vista take‐out point which is the Utility’s point of connection to the CAISO. The Utility may exclude periods of emergency declarations by the CAISO from the calculation.
ii. Avoided Generation Capacity Costs: Savings in system and local resource adequacy requirements.
iii. Avoided Ancillary Service Costs: Reduced CAISO energy purchases result in reduced CAISO ancillary service costs.
iv. Avoided Transmission Costs: Reductions in the Utility’s system load reduce CAISO transmission costs equal to the CAISO transmission access charge. v. Avoided Environmental/Green House Gas Costs: The value of avoided carbon credits resulting from energy received from the Renewable Electrical Generation Facility. vi. Avoided Renewable Portfolio Standard Costs: The value of avoided wholesale renewable energy determined by the market‐based value of Renewable Energy Credits. vii. Avoided System Losses: The values associated with the ACOE cost components are adjusted to account for distribution system losses.
c. Eligible Customer‐Generators whose OAT is a time of use rate schedule will have the ACOE applied by time of use period equivalent to the time of use period and energy rates Eligible Customer‐ Generator’s OAT. If the Eligible Customer‐Generator’s OAT is not time based, the ACOE will be applied equally to all energy supplied to the Utility.
d. The ACOE calculation includes the calendar year 3‐year historical average hourly Utility costs and is effective from July 1 through June 30 of the following year. The AOCE is approved annually by the General Manager and posted on the Utility’s website on July 1 of each year.
4. Renewable Electrical Generation Facility Capacity and Export Limit:
a. The capacity of a Renewable Electrical Generation Facility under this schedule is limited to one hundred fifty percent (150%) of the Customer’s annual energy consumption. The Customer may submit a request to the Utility to increase the capacity by submitting proof of purchase or a City Building and Safety Division issued permit providing reasonable assurance of increased electrical load.
b. The maximum export of the Renewable Electrical Generation Facility to RPU’s distribution system under this schedule shall not exceed 1,000 kilowatts.
5. Metering:
A bi‐directional Meter capable of measuring the flow of energy in two directions will be used by an Eligible Customer‐Generator under this Schedule. The Utility shall own, operate, and maintain the Required Meter
on the Eligible Customer‐Generator’s premises. If the existing meter at the premises is not capable of measuring the flow of energy in two directions, the Eligible Customer‐Generator shall be responsible for all City of Riverside
Public Utilities Department
Schedule SELF‐GEN – Self‐Generation Program For Renewable Electrical Generation Facilities ‐ 3‐
Adopted by Board of Public Utilities: Board Resolution No:
Approved by City Council: Council Resolution No:
Effective Date:
expenses involved in the Utility’s purchase and installation of the Required Meter. The Utility, at its expense, may purchase and install additional meters with the consent of the Eligible Customer‐Generator to provide the information necessary to accurately credit or bill the Eligible Customer‐Generator or to collect generating system performance information for research purposes. If an additional meter or meters are installed, the metering calculation shall yield a result identical to that of a single meter capable of measuring the flow of energy in two directions.
6. Electric Rule 22 Distributed Generation Facilities Interconnection
Under this Schedule, eligible Customer‐Generators with Renewable Electrical Generation Facilities shall comply with all applicable interconnection requirements of Electric Rule 22 “Distributed Generation Facilities Interconnection.”
7. Renewable Electrical Generation Facility
Defined as a facility that generates
electricity from a renewable source listed in paragraph (1) of subdivision (a) of Section 25741 of the California Public Resources Code including biomass, solar thermal, photovoltaic, wind, geothermal, fuel cells using renewable fuels, small hydroelectric generation, digester gas, municipal solid waste conversion, landfill gas, ocean wave, ocean thermal, or tidal current, and any additions or enhancements to the facility using that technology.
8. State Mandated Public Benefits Charge:
The rates in Eligible Customer‐Generator’s OAT are subject to a surcharge as adopted by City Council Resolution No. 19203, and such surcharge as in effect from time to time. The applicable Public Benefits Charge
will be applied in accordance with the Customer’s OAT. The Public Benefits Charge that is applicable to the Customer under the Customer’s OAT shall be calculated based upon the Customer’s total energy usage charges including energy delivered to their Premises by the Utility, monthly or annual minimum charges (including service, customer, reliability, network access, and demand charges, when applicable), for the applicable billing period.
9. Miscellaneous Fees and Charges:
Rates charged pursuant to this Schedule shall be subject to any Energy Users Taxes, Utility Users Taxes and any other governmental taxes, duties, or fees which are applicable to Electric Service provided to Customer
by the Utility. Rates are also subject to adjustment, as established by Riverside’s Board of Public Utilities and adopted by Riverside’s City Council in response to federal or state climate change laws, renewable portfolio standard or other mandated legislation. These adjustments may include but are not limited to charges to mitigate the impacts of greenhouse gas emissions or “green power” premiums.
10. Power Cost Adjustment Factor (“PCAF”):
The “PCAF”, as provided in Part C of the General Provisions, shall apply to Customer’s energy delivered to their Premises by the Utility and such other charges as indicated by Customer’s OAT.
11. Program Cap:
The program cap under this Schedule is 64 MW and includes existing customers under Schedule NEM. Until the program cap is reached, the Schedule shall be open to eligible customers on a first‐come‐first‐served basis. Once the program cap is reached, the Schedule will be closed to any new customers, until such time as qualified customers included within the program cap no longer receives service under this Schedule, thus allowing participation by additional eligible customers until a new program cap is reached.
12. Applicable Rate Schedule:
a. Applicable Rate Schedule
City of Riverside
Public Utilities Department
Schedule SELF‐GEN – Self‐Generation Program For Renewable Electrical Generation Facilities ‐ 4‐
Adopted by Board of Public Utilities: Board Resolution No:
Approved by City Council: Council Resolution No:
Effective Date:
For Customers applying for service at an existing service address, the Utility will assign the electric rate schedule based on the characteristics of the service address. The Utility will presume that any electric rate previously assigned to that service address is the appropriate schedule, unless Customer requests a review for another applicable rate schedule, rate, or optional provision. In certain situations when a Customer does not qualify for an electric rate previously assigned to that service address, the Utility will assign the applicable rate to the Customer. The Utility assumes no responsibility for advising the Customer of lower optional rates under existing schedules available as a result of the Customer’s changes to the characteristics of the service address.
b. Change of Rate Schedule
A change to the applicable rate schedule may be made if the Utility determines that the Customer no longer qualifies for the assigned rate schedule. Subject to meter availability, the change will become effective for service rendered after the next regular meter reading following verification and approval by the Utility of such eligibility. Any change in rate schedules pursuant to this section shall be made prospectively.