reglab/statecodes huggingface dataset:
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 39 - NET METERING RULES › Section 860-039-0015 - Installation, Operation, Maintenance, and Testing of Net Metering Facilities

Current through Register Vol. 63, No. 7, July 1, 2024
(1) Except for customer-generators
			 established as net metering customers prior to the effective date of this rule,
			 a customer-generator of a public utility must install, operate and maintain a
			 net metering facility in compliance with IEEE 1547 and IEEE 1547.1.
(2) Except for customer-generators
			 established as net metering customers prior to the effective date of this rule,
			 a customer-generator of a public utility must install and maintain a manual
			 disconnect switch that will disconnect the net metering facility from the
			 public utility's system. The disconnect switch must be a lockable, load-break
			 switch that plainly indicates whether it is in the open or closed position. The
			 disconnect switch must be readily accessible to the public utility at all times
			 and located within 10 feet of the public utility's meter.
(a) For customer services of 600 volts or
			 less, a public utility may not require a disconnect switch for a net metering
			 facility that is inverter-based with a maximum rating as shown below.
(A) Service type: 240 Volts, Single-phase, 3
			 Wire - Maximum size 7.2 kW AC.
(B)
			 Service type: 120/208 Volts, 3-Phase, 4 Wire - Maximum size 10.5 kW
			 AC.
(C) Service type: 120/240
			 Volts, 3-Phase 4 Wire - Maximum size 12.5 kW AC.
(D) Service type: 277/480, 3-Phase, 4 Wire -
			 Maximum size 25.0 kW AC.
(E) For
			 other service types, the net metering facility must not impact the
			 customer-generator's service conductors by more than 30 amperes.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 39 - NET METERING RULES › Section 860-039-0020 - Net Metering Facility Requirements

Current through Register Vol. 63, No. 7, July 1, 2024
(1) To qualify for
			 the Tier 1 and the Tier 2 interconnection review procedures set forth below, a
			 net metering facility must be certified as complying with the following
			 standards, as applicable:
(a) IEEE 1547
			 standards; and
(b) UL 1741, Third
			 Edition, Supplement SB (2021).
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 39 - NET METERING RULES › Section 860-039-0025 - Application for Net Metering Interconnection

Current through Register Vol. 63, No. 7, July 1, 2024
(1) An application
			 for interconnection review will be submitted on a standard form, available from
			 the public utility and posted on the public utility's website. The application
			 form will require the following types of information:
(a) The name of the applicant and the public
			 utility involved;
(b) The type and
			 specifications of the net metering facility;
(c) The level of interconnection review
			 sought; e.g., Tier 1, Tier 2, or Tier 4;
(d) The contractor who will install the net
			 metering facility;
(e) Equipment
			 certifications;
(f) The anticipated
			 date the net metering facility will be operational; and
(g) Other information that the utility deems
			 is necessary to determine compliance with these net metering rules.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 39 - NET METERING RULES › Section 860-039-0030 - Tier 1 Net Metering Interconnection Review

Current through Register Vol. 63, No. 7, July 1, 2024
(1) A net
			 metering facility meeting the following criteria is eligible for Tier 1
			 interconnection review:
(a) The facility is
			 inverter-based; and
(b) The
			 facility has a generation capacity of 50 kilowatts or less and an export
			 capacity of 25 kilowatts or less.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 39 - NET METERING RULES › Section 860-039-0035 - Tier 2 Net Metering Interconnection Review

Current through Register Vol. 63, No. 7, July 1, 2024
(1) A public
			 utility must apply the following Tier 2 interconnection review procedure for an
			 application to interconnect a net metering facility that meets the following
			 criteria:
(a) The facility has a capacity of
			 two megawatts or less; and
(b) The
			 facility does not qualify for Tier 1 interconnection review
			 procedures.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 39 - NET METERING RULES › Section 860-039-0040 - Tier 4 Net Metering Interconnection Review

Current through Register Vol. 63, No. 7, July 1, 2024
(1) The public
			 utility must apply the Tier 4 review procedure for an application to
			 interconnect a net metering facility that meets the following criteria:
(a) The facility has a capacity of two
			 megawatts or less; and
(b) The
			 facility does not qualify for or failed to receive approval in Tier 1 or Tier 2
			 interconnection review procedures.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 39 - NET METERING RULES › Section 860-039-0045 - Net Metering Interconnection Fees and Costs

Current through Register Vol. 63, No. 7, July 1, 2024
(1) A
			 public utility may not charge an application, or other fee, to an applicant
			 that requests Tier 1 interconnection review. However, if an application for
			 Tier 1 interconnection review is denied, and the applicant resubmits the
			 application under another review procedure, the public utility may impose a fee
			 for the resubmitted application, consistent with this section.
(2) For a Tier 2 interconnection review, the
			 public utility may charge fees of up to $50.00 plus $1.00 per kilowatt of the
			 net metering facility's capacity, plus the reasonable cost of any required
			 minor modifications to the electric distribution system or additional review.
			 Costs for such minor modifications or additional review will be based on the
			 public utility's non-binding, good faith estimates and the ultimate actual
			 installed costs. Costs for engineering work done as part of any additional
			 review will not exceed $100.00 per hour. A public utility may adjust the
			 $100.00 hourly rate once in January of each year to account for inflation and
			 deflation as measured by the Consumer Price Index.
(3) For a Tier 4 interconnection review, the
			 public utility may charge fees of up to $100.00 plus $2.00 per kilowatt of the
			 net metering facility's capacity, as well as charges for actual time spent on
			 any required impact or facilities studies. Costs for engineering work done as
			 part of an impact study or interconnection facilities study will not exceed
			 $100.00 per hour. A public utility may adjust the $100.00 hourly rate once in
			 January of each year to account for inflation and deflation as measured by the
			 Consumer Price Index. If the public utility must install facilities in order to
			 accommodate the interconnection of the net metering facility, the cost of such
			 facilities will be the responsibility of the applicant.
Statutory/Other Authority: ORS 183, ORS 756 & ORS
				  757
Statutes/Other Implemented: ORS
				  756.040 & ORS
				  757.300
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 39 - NET METERING RULES › Section 860-039-0050 - Requirements After Approval of a Net Metering Interconnection

Current through Register Vol. 63, No. 7, July 1, 2024
(1) A public utility may not require an
			 applicant whose facility meets the criteria for interconnection approval under
			 the Tier 1 or Tier 2 interconnection review procedure to perform or pay for
			 additional tests, except if agreed to by the applicant.
(2) A public utility may not charge any fee
			 or other charge for connecting to the public utility's distribution system or
			 for operation of a net metering facility for the purposes of net metering,
			 except for the fees provided for under these net metering rules.
(3) Once a net metering interconnection has
			 been approved under these net metering rules, the public utility may not
			 require a customer-generator to test or perform maintenance on its facility
			 except for the following:
(a) An annual test
			 in which the net metering facility is disconnected from the public utility's
			 equipment to ensure that the inverter stops delivering power to the
			 grid;
(b) Any
			 manufacturer-recommended testing or maintenance;
(c) Any post-installation testing necessary
			 to ensure compliance with IEEE 1547 or to ensure safety; and
(d) The customer-generator replaces a major
			 equipment component that is different from the originally installed
			 model.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 39 - NET METERING RULES › Section 860-039-0055 - Net Metering Billing

Current through Register Vol. 63, No. 7, July 1, 2024
(1)
			 Each monthly billing period, the public utility will charge the
			 customer-generator the minimum monthly charge and all applicable charges for
			 the net electricity that the public utility supplied. Subject to sections (2)
			 and (3) of this rule, if in a monthly billing period a customer-generator
			 supplies to the public utility more electricity than the public utility
			 supplies the customer-generator, the public utility will apply the excess
			 kilowatt-hours as a cumulative credit to the customer-generator's next monthly
			 bill. The credit for the excess kilowatt-hours will be applied at the full
			 retail rate for each rate component on the bill that uses kilowatt-hours as the
			 billing determinant.
(2) Unless the
			 public utility and the customer-generator otherwise agree, the annual billing
			 cycle will end at the end of the March billing month of each year. Should the
			 public utility and a customer-generator reach an agreement for a billing cycle
			 ending other than at the end of the March billing month, the public utility
			 must inform the Commission in writing of the alternative billing period within
			 30 calendar days of the agreement's execution.
(3) The alternative billing period must be
			 for a period of twelve months or less.
Stat. Auth.: ORS 183, 756 & 757
Stats. Implemented: ORS
				  756.040,
				  757.300
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 39 - NET METERING RULES › Section 860-039-0060 - Excess Energy from Net Metering Facilities

Current through Register Vol. 63, No. 7, July 1, 2024
(1) Any unused kilowatt-hour credit
			 accumulated by a customer-generator of a public utility at the conclusion of
			 the annual billing cycle will be transferred, in a manner approved by the
			 Commission, to customers enrolled in the public utility's low-income assistance
			 programs. The public utility will value any unused kilowatt-hour credit at the
			 applicable average annual avoided cost tariff rate.
(2) The customer-generator may not elect to
			 receive a credit or payment for any unused credit accumulated at the conclusion
			 of the annual billing cycle.
(3)
			 The public utility will report in writing to the Commission by July 1 each year
			 the unused kilowatt-hour credits and the dollar amount transferred to the
			 low-income assistance program in the previous billing year.
Stat. Auth.: ORS 183, 756 & 757
Stats. Implemented: ORS
				  756.040,
				  757.300
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 39 - NET METERING RULES › Section 860-039-0065 - Aggregation of Meters for Net Metering

Current through Register Vol. 63, No. 7, July 1, 2024
(1) For the purpose
			 of measuring electricity usage under the net metering program, a public utility
			 must, upon request from a customer-generator, aggregate for billing purposes
			 the meter that is physically attached to the net metering facility ("designated
			 meter") with one or more meters ("aggregated meter") in the manner set out in
			 this rule. This rule is mandatory upon the public utility only when:
(a) The aggregated meters are located on the
			 customer-generator's premises or property that is contiguous to such
			 premises;
(b) The electricity
			 recorded by the designated meter and any aggregated meters is for the
			 customer-generator's requirements, and;
(c) The designated meter and the aggregated
			 meters are served by the same primary feeder at the time of
			 application.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 39 - NET METERING RULES › Section 860-039-0070 - Public Utility Maps, Records and Reports

Current through Register Vol. 63, No. 7, July 1, 2024
(1) Each public utility must maintain current
			 maps and records of customer-generator net metering facilities showing size,
			 location, generator type, and date of installation.
(2) By April 1 of each year, the public
			 utility will submit to the Commission an annual report with the following
			 summary information for the previous year:
(a) The total number of net metering
			 facilities by resource type; and
(b) The total estimated rated generating
			 capacity of net metering facilities by resource type.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 39 - NET METERING RULES › Section 860-039-0075 - Public Utility Not to Limit Net Metering Systems

Current through Register Vol. 63, No. 7, July 1, 2024
A public utility will not limit the cumulative generating
				capacity of net metering systems in any manner except as expressly ordered by
				the Commission under ORS
				757.300(6).
Stat. Auth.: ORS 183, 756 & 757
Stats. Implemented: ORS
				  756.040,
				  757.300
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 39 - NET METERING RULES › Section 860-039-0080 - Net Metering Insurance

Current through Register Vol. 63, No. 7, July 1, 2024
A public utility will not require a customer-generator whose
				net metering facility is in compliance with the standards in paragraphs (a) and
				(b) of ORS 757.300(4) and
				the safety standards contained in these rules to purchase additional liability
				insurance or to name the utility as an additional insured on the
				customer-generator's liability insurance policy.
Stat. Auth.: ORS 183, 756 & 757
Stats. Implemented: ORS
				  756.040,
				  757.300
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 82 - SMALL GENERATOR INTERCONNECTION RULES › Section 860-082-0005 - Scope and Applicability

Current through Register Vol. 63, No. 7, July 1, 2024
(1) OAR
			 860-082-0005  through 860-082-0085  (the "small generator interconnection rules")
			 govern the interconnection of a small generator facility with a nameplate
			 rating of 10 megawatts or less to a public utility's transmission or
			 distribution system. These rules do not apply if the interconnection between
			 the small generator facility and the public utility is subject to the
			 jurisdiction of the Federal Energy Regulatory Commission (FERC).
(2) Except as specified in OAR
			 860-082-0025(1)(b), the small generator interconnection rules do not apply
			 retroactively to a small generator facility that was interconnected to a public
			 utility's transmission or distribution system prior to the effective date of
			 the small generator interconnection rules (an "existing small generator
			 facility"). These rules become applicable to an existing small generator
			 facility at the expiration of the agreement governing the terms of the
			 interconnection of the existing small generator facility to the interconnected
			 public utility's transmission or distribution system. If an existing agreement
			 does not have an expiration date, then the small generator interconnection
			 rules become applicable to the existing small generator facility 10 years after
			 the effective date of the rules. An existing small generator facility must
			 submit an application under OAR 860-082-0025(1)(e)  to the interconnected public
			 utility no later than 60 business days before the date that the small generator
			 interconnection rules become applicable.
(3) Except where explicitly noted in OAR
			 chapter 860, division 039, the small generator interconnection rules do not
			 apply to the interconnection of a net metering facility, which is governed by
			 OAR chapter 860, division 039.
(4)
			 A small generator facility that qualifies as a "small power production
			 facility" under OAR 860-029-0010(25)  must also comply with the rules in OAR
			 chapter 860, division 029. If there is a conflict between the small generator
			 interconnection rules and the rules in OAR chapter 860, division 029, then the
			 small generator interconnection rules control.
Statutory/Other Authority: ORS 183, ORS 756 & ORS
				  757
Statutes/Other Implemented: ORS
				  756.040 & ORS
				  756.060
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 82 - SMALL GENERATOR INTERCONNECTION RULES › Section 860-082-0010 - Waiver

Current through Register Vol. 63, No. 7, July 1, 2024
(1) Upon request or
			 its own motion, the Commission may waive any of the Division 082 rules for good
			 cause shown. A request for waiver must be made in writing, unless otherwise
			 allowed by the Commission.
(2) A
			 public utility and an applicant or interconnection customer may agree to
			 reasonable extensions to the required timelines in these rules without
			 requesting a waiver from the Commission.
(a)
			 If a public utility and an applicant or interconnection customer are unable to
			 agree to waive a timeline, then the public utility, applicant, or
			 interconnection customer may request that the Commission grant a
			 waiver.
(b) In deciding whether to
			 grant a waiver of a timeline, the Commission will consider the number of
			 pending applications for interconnection review and the type of applications,
			 including review level, facility type, and facility size.
(c) Waiver of a timeline, whether by
			 agreement or Commission order, does not affect an application's queue
			 position.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 82 - SMALL GENERATOR INTERCONNECTION RULES › Section 860-082-0015 - Definitions

Current through Register Vol. 63, No. 7, July 1, 2024
As used in OAR 860-082-0005  through 860-082-0085:
(1) "Adverse system impact" means a negative
			 effect caused by the interconnection of a small generator facility that may
			 compromise the safety or reliability of a transmission or distribution
			 system.
(2) "Affected system" means
			 a transmission or distribution system, not owned or operated by the
			 interconnecting public utility, which may experience an adverse system impact
			 from the interconnection of a small generator facility.
(3) "Aggregated export capacity" means the
			 total combined export capacity of:
(a) A
			 proposed small generator facility;
(b) Existing small generator facilities, net
			 metering facilities, FERC jurisdictional generators, and state jurisdictional
			 generators with a nameplate rating greater than 10 megawatts; and
(c) Small generator facilities, net metering
			 facilities, FERC jurisdictional generators, and state jurisdictional generators
			 with a nameplate rating greater than 10 megawatts that have pending completed
			 applications with higher queue positions than the proposed small generator
			 facility.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 82 - SMALL GENERATOR INTERCONNECTION RULES › Section 860-082-0020 - Pre-Application Process

Current through Register Vol. 63, No. 7, July 1, 2024
(1) Each public utility must designate an
			 employee or office from which relevant information about the small generator
			 interconnection process, the public utility's transmission or distribution
			 system, and affected systems may be obtained through informal requests for a
			 potential applicant proposing a small generator facility at a specific site.
			 The public utility must post contact information for the employee or office on
			 the public utility's website. The information provided by the public utility in
			 response to a potential applicant's request must include relevant existing
			 studies and other materials that may be used to understand the feasibility of
			 interconnecting a small generator facility at a particular point on the public
			 utility's transmission or distribution system. The public utility must comply
			 with reasonable requests for access to or copies of such information, except to
			 the extent that providing such materials would violate security requirements,
			 confidentiality obligations to third parties, or be contrary to federal or
			 state regulations. The public utility may require a person to sign a
			 confidentiality agreement if required to protect confidential or proprietary
			 information. For a potential small generator facility requiring Tier 4 review,
			 and at the potential applicant's request, the public utility must meet with the
			 potential applicant to exchange information. A public utility employee with
			 relevant technical expertise must attend any such meeting.
(2) A person requesting information under
			 section (1) must reimburse the public utility for the reasonable costs of
			 gathering and copying the requested information.
Statutory/Other Authority: ORS 183, ORS 756 & ORS
				  757
Statutes/Other Implemented: ORS
				  756.040 & ORS
				  756.060
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 82 - SMALL GENERATOR INTERCONNECTION RULES › Section 860-082-0030 - Construction, Operation, Maintenance, and Testing of Small Generator Facilities

Current through Register Vol. 63, No. 7, July 1, 2024
(1) IEEE 1547. An
			 interconnection customer or applicant must construct, operate, and maintain a
			 small generator facility and its associated interconnection equipment in
			 compliance with IEEE 1547 and 1547.1. New interconnection applicants will be
			 required to use IEEE 1547-2018 compliant equipment by no earlier than June 1,
			 2024. For purposes of OAR 860-082-0030, capitalized terms not otherwise defined
			 in Division 082 have the meaning set forth in IEEE 1547.
(a) Small generator facilities compliant with
			 IEEE 1547 must conform with the following minimum requirements:
(A) Abnormal performance requirements:
			 Category III Ride-Through capabilities must be supported for inverter-based
			 small generator facilities. Rotating small generator facilities must meet
			 Category I Ride-Through capabilities, at minimum.
(B) Normal performance requirements:
			 Inverter-based small generator facilities must meet reactive power requirements
			 of IEEE 1547 Category B. Rotating small generator facilities must meet Category
			 A, and may meet Category B.
(C)
			 Inverter-based interconnection equipment will be tested to and certified as
			 being compliant with UL 1741 Third Edition, Supplement SB, by a NRTL. Equipment
			 that is not certified by a NRTL may require additional evaluation and
			 commissioning testing to confirm compliance with IEEE 1547.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 82 - SMALL GENERATOR INTERCONNECTION RULES › Section 860-082-0033 - Export Controls

Current through Register Vol. 63, No. 7, July 1, 2024
(1) If a small
			 generator facility uses any configuration or operating mode in section (3) to
			 limit the export of electrical power across the Point of Interconnection, then
			 the export capacity is only the amount capable of being exported (not including
			 any Inadvertent export). To prevent impacts on system safety and reliability,
			 any inadvertent export from a small generator facility must comply with the
			 limits identified in this rule. The export capacity specified by the
			 interconnection customer in the application will subsequently be included as a
			 limitation in the interconnection agreement.
(2) An application proposing to use a
			 configuration or operating mode to limit the export of electrical power across
			 the Point of Interconnection must include proposed control and/or protection
			 settings.
(3) Acceptable export
			 control methods.
(a) Export control methods
			 for non-exporting small generator facility:
(A) Reverse Power Protection (Device 32R): To
			 limit export of power across the Point of Interconnection, a reverse power
			 protective function is implemented using a utility grade protective relay. The
			 default setting for this protective function is 0.1 percent (export) of the
			 service transformer's nominal base nameplate power rating, with a maximum 2.0
			 second time delay to limit inadvertent export. When a project is located on a
			 circuit using high-speed reclosing, the utility may require a maximum delay of
			 less than 2.0 seconds to safely facilitate the reclosing. To minimize the need
			 for case-by-case design, which shall remain available, the utility handbook
			 must provide:
(i) The rationale and standards
			 that interconnection applications must meet;
(ii) A list of specific additional equipment
			 that, if installed, will satisfy the requirement; and
(iii) A list of any inverter specifications
			 and options that, if configured, will satisfy the requirement without the need
			 for additional equipment.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 82 - SMALL GENERATOR INTERCONNECTION RULES › Section 860-082-0040 - Insurance

Current through Register Vol. 63, No. 7, July 1, 2024
(1) A public utility may not require an
			 applicant or an interconnection customer with a small generator facility with a
			 nameplate rating of 200 kilowatts or less to obtain liability insurance in
			 order to interconnect with the public utility's transmission or distribution
			 system.
(2) A public utility may
			 require an applicant or an interconnection customer with a small generator
			 facility with a nameplate rating greater than 200 kilowatts to obtain prudent
			 amounts of general liability insurance in order to interconnect to the public
			 utility's transmission or distribution system.
Statutory/Other Authority: ORS 183, ORS 756 & ORS
				  757
Statutes/Other Implemented: ORS
				  756.040 & ORS
				  756.060
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 82 - SMALL GENERATOR INTERCONNECTION RULES › Section 860-082-0045 - Tier 1 Interconnection Review

Current through Register Vol. 63, No. 7, July 1, 2024
(1) A public
			 utility must use the Tier 1 review procedures when an applicant submits an
			 application to interconnect a small generator facility that meets the following
			 requirements:
(a) The small generator facility
			 must have an export capacity not greater than 25 kilowatts, a nameplate rating
			 not greater than 50 kilowatts, and use a UL 1741 certified inverter;
			 and
(b) The small generator
			 facility must not be interconnected to a transmission line or an area
			 network.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 82 - SMALL GENERATOR INTERCONNECTION RULES › Section 860-082-0050 - Tier 2 Interconnection Review

Current through Register Vol. 63, No. 7, July 1, 2024
(1) A public
			 utility must use the Tier 2 interconnection review procedures when an applicant
			 submits an application requesting Tier 2 review to interconnect a small
			 generator facility that meets the following requirements:
(a) The small generator facility does not
			 qualify for the Tier 1 interconnection review requirements;
(b) If the small generator facility is
			 inverter-based, the small generator facility's export capacity does not exceed
			 the limits identified in Table 1 attached, which vary according to the voltage
			 of the line at the proposed point of interconnection;
(c) Inverter-based small generator facilities
			 located within 2.5 line miles of a substation and on a main distribution line
			 with minimum 600-amp capacity are eligible for Tier 2 interconnection under
			 higher thresholds;
(d) If the small
			 generator facility is not inverter-based, the small generator facility's export
			 capacity is two megawatts or less;
(e) The small generator facility must not
			 interconnect to a transmission line, or area network; and
(f) The small generator facility must use
			 interconnection equipment that is either lab-tested equipment or field-tested
			 equipment. For equipment to gain status as field-tested equipment, the
			 applicant must provide all the documentation from the prior public utility
			 approval including any interconnection studies and the certificate of
			 completion.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 82 - SMALL GENERATOR INTERCONNECTION RULES › Section 860-082-0055 - Tier 3 Interconnection Review

Current through Register Vol. 63, No. 7, July 1, 2024
(1) A public
			 utility must use the Tier 3 interconnection review procedures when the
			 applicant submits an application requesting Tier 3 review to interconnect a
			 small generator facility that meets the following requirements:
(a) The small generator facility must have a
			 nameplate rating of 10 megawatts or less;
(b) The small generator facility must not be
			 connected to a transmission line;
(c) The small generator facility must not
			 export power beyond the point of interconnection; and
(d) The small generator facility must use low
			 forward power relays or other protection functions that prevent power flow onto
			 the area network.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 82 - SMALL GENERATOR INTERCONNECTION RULES › Section 860-082-0060 - Tier 4 Interconnection Review

Current through Register Vol. 63, No. 7, July 1, 2024
(1) A public
			 utility must use the Tier 4 interconnection review procedures when an applicant
			 submits an application requesting Tier 4 review to interconnect a small
			 generator facility meeting the following requirements:
(a) The small generator facility must have a
			 nameplate rating of 10 megawatts or less.
(b) An applicant whose Tier 1, Tier 2, or
			 Tier 3 application was denied may request that the public utility treat that
			 existing application already in the public utility's possession as a new Tier 4
			 application. Within ten business days of receipt of the applicant's request to
			 use the existing application, the public utility will transfer the existing
			 application to the Tier 4 process and notify the applicant whether or not the
			 application is complete. If the application is incomplete, the public utility
			 must provide a written list detailing all information that the applicant must
			 provide to complete the application. The applicant will have ten business days
			 after receipt of the list to submit the listed information. Otherwise, the
			 application will be deemed withdrawn. The public utility must notify the
			 applicant within ten business days of receipt of the revised application
			 whether the revised application is complete or incomplete. The public utility
			 may deem the application withdrawn if it remains incomplete.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 82 - SMALL GENERATOR INTERCONNECTION RULES › Section 860-082-0063 - Supplemental Review

Current through Register Vol. 63, No. 7, July 1, 2024
(1) To accept the offer of a supplemental
			 review, the applicant must submit a signed copy of the Supplemental Review
			 Agreement and pay a supplemental review fee of $1,000, both within 10 business
			 days of the offer. If the written agreement and fee have not been received
			 within that timeframe, the Application will be deemed withdrawn unless the
			 applicant has notified the public utility that they wish to continue being
			 evaluated under the Tier 4 review procedures.
(2) Within 20 business days of an applicant's
			 election to undergo supplemental review, the public utility must perform
			 supplemental review using the screens set forth below, notify the applicant of
			 the results, and include with the notification a written report of the analysis
			 and data underlying the public utility's determinations under the screens.
(a) Supplemental Review Penetration Screen:
			 Where 12 months of line section minimum load data (including onsite load, but
			 not station service load served by the proposed small generator facility) are
			 available, can be calculated, can be estimated from existing data, or can be
			 determined from a power flow model, the aggregate export capacity on the feeder
			 or line section is less than 100 percent of the relevant minimum load on the
			 feeder. If minimum load data are not available, or cannot be calculated,
			 estimated, or determined, the aggregated export capacity on the line section is
			 less than 30 percent of the peak load for all line Sections bounded by
			 automatic sectionalizing devices upstream of the proposed project.
(A) Load that is co-located with
			 load-following, non-exporting, or export-limited projects should be
			 appropriately accounted for. The public utility may take the impacts of
			 non-export or export limited generation on the calculation of daytime minimum
			 load when evaluating potential system impacts.
(B) The interconnecting public utility will
			 not consider as part of the aggregate export capacity for purposes of this
			 screen the export capacity of generators known to be already reflected in the
			 minimum load data, including combined heat and power (CHP) facility
			 capacity.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 82 - SMALL GENERATOR INTERCONNECTION RULES › Section 860-082-0065 - Recordkeeping and Reporting Requirements

Current through Register Vol. 63, No. 7, July 1, 2024
(1) The public
			 utility must maintain a record of the following information for at least two
			 years:
(a) The number of complete small
			 generator interconnection applications received;
(b) The time required to complete the review
			 process for each application; and
(c) The reasons for the approval or denial of
			 each application.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 82 - SMALL GENERATOR INTERCONNECTION RULES › Section 860-082-0070 - Metering and Monitoring

Current through Register Vol. 63, No. 7, July 1, 2024
(1) The public
			 utility must install, maintain, test, repair, operate, and replace any metering
			 and data acquisition equipment necessary under the terms of the public
			 utility's interconnection agreement, power purchase agreement, or power service
			 agreement with an applicant or interconnection customer. The applicant or
			 interconnection customer is responsible for all reasonable costs associated
			 with the metering and data acquisition equipment. The public utility and the
			 applicant or interconnection customer must have unrestricted access to such
			 equipment as necessary to conduct routine business or respond to an
			 emergency.
(2) Except as provided
			 in subsection 3(b), a public utility may not require an applicant or
			 interconnection customer with a small generator facility with a nameplate
			 rating of less than three megawatts to provide or pay for the data acquisition
			 or telemetry equipment necessary to allow the public utility to remotely
			 monitor the small generator facility's electric output.
(3) At its discretion, a public utility may
			 require an applicant or interconnection customer to pay for the purchase,
			 installation, operation, and maintenance of the data acquisition or telemetry
			 equipment necessary to allow the public utility to remotely monitor the small
			 generator facility's electric output if:
(a)
			 The small generator facility has a nameplate rating greater than or equal to 3
			 megawatts; or
(b) The small
			 generator facility meets the criteria in OAR 860-082-0055(1)  for Tier 3
			 interconnection review and the aggregated nameplate rating on the circuit
			 exceeds 50 percent of the line section annual peak load.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 82 - SMALL GENERATOR INTERCONNECTION RULES › Section 860-082-0075 - Temporary Disconnection

Current through Register Vol. 63, No. 7, July 1, 2024
(1)
			 Under emergency conditions, a public utility or an interconnection customer may
			 suspend interconnection service and temporarily disconnect a small generator
			 facility from the public utility's transmission or distribution system at any
			 time and for as long as reasonably necessary.
(a) A public utility must notify an
			 interconnection customer immediately after becoming aware of an emergency
			 condition that may reasonably be expected to affect a small generator
			 facility's operation. To the extent possible, the notice must describe the
			 emergency condition, the extent of the damage or deficiency, the expected
			 effect on the small generator facility, the anticipated duration of the
			 condition, and the necessary corrective action.
(b) An interconnection customer must notify
			 the public utility immediately after becoming aware of an emergency condition
			 that may reasonably be expected to affect the public utility's transmission or
			 distribution system. To the extent possible, the notice must describe the
			 emergency condition, the extent of the damage or deficiency, the expected
			 effect on the public utility's transmission or distribution system, the
			 anticipated duration of the condition, and the necessary corrective
			 action.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 82 - SMALL GENERATOR INTERCONNECTION RULES › Section 860-082-0080 - Arbitration of Disputes

Current through Register Vol. 63, No. 7, July 1, 2024
(1) An
			 interconnecting public utility or an interconnection applicant may petition the
			 Commission for arbitration of disputes arising during review of an application
			 to interconnect a small generator facility or during negotiation of an
			 interconnection agreement. If the public utility or the applicant petitions the
			 Commission to arbitrate their dispute, then the Commission will use an
			 administrative law judge (ALJ) as arbitrator unless workload constraints
			 necessitate the use of an outside arbitrator.
(2) A petition for arbitration of an
			 interconnection agreement must contain:
(a) A
			 statement of all unresolved issues;
(b) A description of each party's position on
			 the unresolved issues; and
(c) A
			 proposed agreement addressing all issues, including those on which the parties
			 have reached agreement and those that are in dispute.
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 83 - RENEWABLE PORTFOLIO STANDARDS › Section 860-083-0005 - Scope and Applicability of Renewable Portfolio Standards Rules

Current through Register Vol. 63, No. 7, July 1, 2024
(1) OAR
			 860-083-0005  through 860-083-0500  (the "Renewable Portfolio Standards rules")
			 establish rules governing implementation of Renewable Portfolio Standards for
			 electric companies and electricity service suppliers provided under ORS
			 469A.005 through
			 469A.210.
(2) Upon request or its own motion, the
			 Commission may waive any of the Division 083 rules for good cause shown. A
			 request for waiver must be made in writing, unless otherwise allowed by the
			 Commission.
Stat. Auth.: ORS
				  756.040,
				  757.659,
				  469A.065
Stats. Implemented:
				  469A.065
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 83 - RENEWABLE PORTFOLIO STANDARDS › Section 860-083-0050 - Renewable Energy Certificates Eligible for Compliance With a Renewable Portfolio Standard

Current through Register Vol. 63, No. 7, July 1, 2024
An electric company or an electricity service supplier may use
				a renewable energy certificate to comply with a renewable portfolio standard
				contained in ORS 469A.052,
				469A.055, or
				469A.065 in a calendar year as
				follows:
(1) The electric company or
			 electricity service supplier has not previously used, sold or otherwise
			 transferred the renewable energy certificate;
(2) The electric company has not previously
			 used the renewable energy certificate to comply with requirements set forth in
			 its own tariff that is in effect in Oregon or in another state, that are not
			 related to an ORS 469A renewable portfolio standard or similar standard in
			 another state;
(3) A renewable
			 energy certificate that has been traded, sold or otherwise transferred is not
			 eligible to become a banked renewable energy certificate; and
(4) The renewable energy certificate complies
			 with OAR 330-160-0005  through 330-160-0030  (effective September 3,
			 2008).
Stat. Auth.: ORS
				  756.040,
				  757.659,
				  469A.065,
				  469A.150 &
				  469A.170
Stats. Implemented: ORS
				  469A.005,
				  469A.050 -
				  469A.055,
				  469A.065 -
				  469A.070 &
				  469A.130 -
				  469A.170
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 83 - RENEWABLE PORTFOLIO STANDARDS › Section 860-083-0100 - Incremental Costs

Current through Register Vol. 63, No. 7, July 1, 2024
(1)
(a) For amortization and levelization
			 calculations, an electric company must use the discount rate used in its most
			 recently filed or updated integrated resource plan, unless otherwise specified
			 by the Commission.
(b) For
			 amortization and levelization calculations, an electricity service supplier
			 must use the discount rate applicable to the electric company in whose service
			 area it made the most retail sales in megawatt-hours over the five calendar
			 years preceding the compliance year.
(c) The incremental cost under ORS
			 469A.100(4) for
			 long-term qualifying electricity is the difference between the levelized annual
			 cost of qualifying electricity delivered in a compliance year and the levelized
			 annual cost of an equivalent amount of electricity delivered from the
			 corresponding proxy plant.
(d) The
			 time horizon for long-term qualifying electricity and for the corresponding
			 proxy plant must be no longer than the amortization period of the qualifying
			 electricity and must be at least as long as the lesser of:
(A) The amortization period of the qualifying
			 electricity; or
(B) The period from
			 the beginning year of the amortization period of the qualifying electricity
			 until 20 years after the current compliance year.
(e) The incremental cost under ORS
			 469A.100(4) for
			 short-term qualifying electricity is the difference between the levelized
			 annual cost of qualifying electricity delivered in a compliance year and the
			 levelized annual cost of an equivalent amount of delivered market purchases
			 with a consistent term that is not qualifying electricity. The cost of
			 non-qualifying electricity must be based on published prices for a nearby
			 electricity trading hub. When choosing among nearby hubs, the one with
			 transmission costs most similar to the short-term qualifying electricity must
			 be used. Specific costs must be adjusted to account for the differences in all
			 transmission-associated costs.
(f)
			 Levelized annual delivered costs for qualifying electricity and non-qualifying
			 electricity are specific costs plus applicable shares of aggregate
			 costs.
(g) Aggregate and specific
			 costs for interstate electric companies must reflect interstate allocations of
			 costs.
(h) Incremental cost
			 estimates for an electric company must be based on the likely impacts on the
			 rates of its Oregon retail electricity consumers.
(i) Incremental costs are deemed to be zero
			 for qualifying electricity from generating facilities or contracts that became
			 operational before June 6, 2007 and for certified low-impact hydroelectric
			 facilities under ORS 469A.025(5).
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 83 - RENEWABLE PORTFOLIO STANDARDS › Section 860-083-0200 - Electric Company Revenue Requirements

Current through Register Vol. 63, No. 7, July 1, 2024
(1) For the purposes of division 083, annual
			 revenue requirement is the amount produced from the following calculations:
(a) If the electric company is involved in a
			 general rate proceeding using a test year that is reasonably representative of
			 the compliance year and that results in the Commission issuing a final order no
			 later than January 1 of the compliance year, annual revenue requirement is the
			 total revenue the Commission authorizes an electric company the opportunity to
			 recover in Oregon rates before the application of credits resulting from  16 U.S.C. sec. 839(c)  (2008) (commonly known as the "Bonneville Power
			 Administration Residential Exchange") adjusted for amounts and costs as needed
			 in accordance with ORS
			 469A.100(3);
			 or
(b) For a compliance year not
			 involving a general rate proceeding under subsection (1)(a) of this rule,
			 annual revenue requirement is the amount produced by the following calculation:
(A) Calculate the operating revenues related
			 to net power costs, the renewable adjustment clause, updates for base rate
			 changes relating to automatic adjustment clauses, and other adjustments
			 authorized by the Commission subsequent to the most recent general rate
			 proceeding and adjusted for electric company load changes as needed;
			 and
(B) To the amount calculated
			 under paragraph (1)(b)(A) of this rule, add the product of:
(i) The total operating revenues authorized
			 in the most recent general rate proceeding, reduced by the amount of operating
			 revenues related to energy efficiency programs, low income energy assistance,
			 the incremental cost of compliance, unbundled renewable energy certificates,
			 alternative compliance payments, and net power costs in the general rate
			 proceeding, and increased by credits resulting from  16 U.S.C. sec. 839(c) (2008); and
(ii) The ratio of the
			 compliance year forecasted load to the load from the most recent general rate
			 proceeding; and
(C) In
			 the sum calculated under subsection (1)(b) of this rule, adjust for the amounts
			 and costs as needed in accordance with ORS
			 469A.100(3).
Oregon Administrative Rules › Chapter 860 - PUBLIC UTILITY COMMISSION › Division 83 - RENEWABLE PORTFOLIO STANDARDS › Section 860-083-0300 - Compliance Standards

Current through Register Vol. 63, No. 7, July 1, 2024
(1) Each
			 electricity service supplier subject to ORS
			 469A.065 must meet the requirements of 469A.052 unless a limit specified in section (2)
			 or section (3) of this rule applies.
(2)
(a) The
			 cost limit under ORS
			 469A.100(6)
			 for an electricity service supplier means four percent of the weighted average
			 of the average retail revenues per megawatt-hour of the electric companies
			 subject to 469A.052 in whose service areas the electricity service supplier
			 sells electricity. The weights are the retail sales in megawatt-hours by the
			 electricity service supplier in the service areas of electric companies subject
			 to 469A.052 for a compliance year.
(b) If the average cost of compliance per
			 megawatt-hour for an electricity service supplier subject to ORS
			 469A.065 exceeds the cost limit for a compliance year, the electricity service supplier
			 is not required to incur additional costs to meet section (1) of this
			 rule.