New Mexico Register / Volume XXXVII,
Issue 21 / November 3, 2026
TITLE 17 PUBLIC UTILITIES AND UTILITY
SERVICES
CHAPTER 9 ELECTRIC SERVICES
PART 575 INTERCONNECTION OF GENERATING
FACILITIES WITH A NAMEPLATE RATING UP TO AND INCLUDING 10 MW CONNECTING TO A RURAL
ELECTRIC COOPERATIVE’S SYSTEM
17.9.575.1 ISSUING AGENCY: New Mexico public regulation
commission.
[17.9.575.1 NMAC - N, 11/3/2026]
17.9.575.2 SCOPE:
A. This
rule, and the definitions, standards, procedures and screening processes
described herein apply to rural electric cooperatives operating within the
state of New Mexico that are subject to the jurisdiction of the New Mexico
public regulation commission. These
standards and procedures apply to both qualifying and non-qualifying
facilities.
B. The
standards and procedures described in this rule (17.9.575 NMAC) apply only to
the interconnection of generating facilities with a nameplate rated capacity up
to and including 10 MW. The standards
and procedures described in 17.9.569 NMAC apply to the interconnection of
generating facilities with a rated capacity greater than 10 MW and are
unchanged by this rule.
C. Interconnection requests are
reviewed based on the combined nameplate ratings of systems accounting for
their export capacity and energy storage operating mode. For purposes of review screens, only the
capacity that is designed to inject electricity to the utility’s distribution
or transmission system, other than inadvertent exports and fault contribution,
will be used.
D. All
interconnection contracts between a utility and an interconnection customer
existing at the time 17.9.575 NMAC is revised and adopted shall automatically
continue in full force and effect. Material
modifications to existing facilities or operations require a new
interconnection application and agreement and will be subject to review under
the current conditions of the electric power system. Any changes made to existing interconnection agreements
shall conform to the provisions of 17.9.575 NMAC in effect at the time
modification is executed.
[17.9.575.2 NMAC - N, 11/3/2026]
17.9.575.3 STATUTORY AUTHORITY: This rule is adopted
under the authority vested in this commission by the New Mexico Public
Regulation Commission Act, Section 62-19-1 et seq. NMSA 1978, the Public
Utility Act, Section 62-3-1 et seq. NMSA 1978; the Rural Electric
Cooperative Act, Section 62-15-1 et seq., the Energy Transition Act,
62-18-1 et seq. NMSA 1978; the Grid Modernization Act, Section 62-8-13
NMSA 1978; and the Community Solar Act, Section 62-16B-1 NMSA 1978.
[17.9.575.3 NMAC - Rp,
17.9.575.3 NMAC, 02/14/2023]
17.9.575.4 DURATION:
Permanent.
[17.9.575.4 NMAC - N, 11/3/2026]
17.9.575.5 EFFECTIVE DATE: November 3, 2026, unless
a later date is cited at the end of a section.
[17.9.575.5 NMAC - N, 11/3/2026]
17.9.575.6 OBJECTIVE: The purpose of this
rule is to set forth common interconnection requirements and a common
interconnection process based on a standard screening process for utilities and
interconnection customers to expeditiously interconnect generating facilities
with a rated capacity up to and including 10 MW in a safe and reliable manner.
[17.9.575.6 NMAC - N, 11/3/2026]
17.9.575.7 DEFINITIONS: Terms used in rule
17.9.575 NMAC shall have the following meanings:
A. Definitions beginning with “A”:
(1) Applicant means a person or an entity
that has filed an application to interconnect a generating facility to an
electric power system. An applicant may include:
(a) A customer who applies for
interconnection of a generating facility that will offset part or all of the
load of a utility customer, the applicant is that customer, whether the
customer owns the generating facility or a third party owns the generating
facility.
(b) An owner of a generating facility that
applies for interconnection of a generating facility that sells electric power
to a utility.
(c) A subscriber organization as defined
by the Community Solar Act, Subsection M. of Section 62-16B-2 NMSA 1978.
(2) Area network means a section of an
electric power system served by multiple transformers interconnected in an
electrical network circuit, generally used in large, densely populated
metropolitan areas, to provide high reliability of service. Area network has the same meaning as the term “grid network” as
defined in IEEE Std 1547.6™. An area network is also referred to as a grid
network or a street network.
(3) Auxiliary load means electrical
power consumed by any equipment necessary to operate the generator or energy
storage system. This is intended for in-front-of-the-meter systems.
B. Definitions beginning
with “B”: Business day means Monday through Friday, excluding holidays observed by
the utility.
C. Definitions
beginning with “C”:
(1) Certified means equipment has been
tested in accordance with the applicable requirements of IEEE Std 1547™-2018
and IEEE Std 1547.1™-2020 by any nationally recognized testing laboratory
(NRTL) recognized by the United States occupational safety and health
administration to test and certify equipment pursuant to the applicable
standard and the equipment has been labeled and is publicly listed by such NRTL
at the time of the interconnection application. Equipment installed prior to March 28,
2023 will also be considered certified if it has been tested in accordance with
IEEE Std 1547™-2003 and 1547.1™-2005.
(2) Customer options meeting means a meeting designed to review the status of the interconnection application
initial review results, or to determine next steps needed to permit safe and
reliable interconnection.
D. Definitions beginning with “D”:
(1) Detailed study process means the
procedure for evaluating an interconnection application that may include a
scoping meeting, feasibility study, system impact study, or facilities study as
described in Appendix A-1.
(2) Distributed energy resource (DER) means the
equipment used by an interconnection customer to generate or store electricity
that operates in parallel with the electric distribution system. DER may include, but is not limited to: an
electric generator or energy storage system, a prime mover, or combination of
technologies capable of injecting power and energy into the electric
distribution system, which also includes the interconnection equipment
necessary to safely interconnect with the distribution system. DER may not always be interconnected with the
bulk power system. DERs may include
distributed generation (DG) resources, distributed energy storage, demand
response energy efficiency, and electric vehicles and chargers that are
connected to the electric distribution power grid. DERs may be capable of exporting active power
to an electric power system (EPS). The DER includes the customer’s interconnection
facilities but shall not include the area EPS operator’s interconnection facilities.
(3) Distribution service means
delivering energy over the electric power system pursuant to the approved
tariffs of the utility other than services directly related to the
interconnection of a generating facility under these interconnection
procedures.
(4) Distribution
system means the utility's facilities and
equipment used to transmit electricity to ultimate usage points, known as
premises, directly from nearby generators or from interchanges with higher
voltage transmission networks which transport bulk power over longer
distances. The voltage levels at which
distribution systems operate differ among areas.
(5) Distribution upgrade means the
additions, modifications, and upgrades to the utility's distribution system at
or beyond the point of common coupling to facilitate interconnection of the
generating facility and render the service necessary to effect the
interconnection customer's operation of on-site generation. Distribution
upgrades do not include interconnection facilities.
E. Definitions beginning with “E”:
(1) Electric power system (EPS) means the
equipment operated and maintained by a utility (may include: independent system
operators, transmission owner/operator, vertically integrated utilities,
electric cooperatives, municipals, and distribution companies) to deliver
electric service to end-users, including transmission and distribution lines,
substations, transformers, spot networks and area networks.
(2) Energy
storage system (ESS) means any commercially available,
customer-sited system or utility-sited system, including batteries and
batteries paired with on-site generation, that is capable of retaining,
storing, and delivering electrical energy by chemical, thermal, mechanical, or
other means. For the purposes of this
rule, an energy storage system can be considered part of a DER or a DER in
whole that operates in parallel with the distribution system.
(3) Export capacity means the amount
of power that can be transferred from the generating facility to the
distribution system. Export capacity is either
the nameplate rating, or a lower amount if limited using and acceptable means
identified in 17.9.575.12 NMAC.
F. Definitions beginning
with “F”:
(1) Facilities study means a study
that specifies and estimates the cost of the equipment, engineering,
procurement, and construction work needed to implement the conclusions of the
system impact study.
(2) Fast
Track means the process for evaluating an interconnection application utilizing
established screens as described in Appendix A-1.
(3) Fault current means the current
produced during a short circuit on the electric power system measured in
amperes.
(4) Feasibility
study means a preliminary technical
assessment of the proposed interconnection that identifies any potential
adverse system impacts that would result from the interconnection of the
generating facility.
G. Definitions beginning with “G”:
(1) Generating
facility means the equipment used by an
interconnection customer to generate, store, manage, interconnect and monitor
electricity. A generating facility includes the interconnection equipment
required to safely interconnect the facility with the distribution system. DERs
are generating facilities.
(2) Grid network means area network or
street network. For definition, refer to area network
H. Definitions beginning with “H”: Host load means the
electrical power, less the DER auxiliary load, consumed by the customer at the
location where the generating facility is connected.
I. Definitions beginning with “I”:
(1) IEEE means the institute of electrical and
electronic engineers.
(2) IEEE standards means the standards
published by the IEEE, often in collaboration with American National Standards
Institute (ANSI), National Institute of Standards and Technology (NIST), UL,
International Electrotechnical Commission (IEC), CIGRE, and National Fire
Protection Institute (NFPA), available at www.ieee.org.
(3) Inadvertent
export means the unscheduled export of active power from a
generating facility, exceeding a specified magnitude and for a limited duration
generally due to fluctuations in load-following behavior.
(4) Interconnection agreement means a standard
form agreement between an interconnection customer and a utility that governs the
interconnection of a generating facility to a utility’s electric delivery
system, as well as the ongoing operation of the generating facility after it is
interconnected.
(5) Interconnection
application means the request by an
interconnection customer to interconnect a new generating facility, increase
the capacity or make a material modification to the operating characteristics
of an existing generating facility that is interconnected with the utility’s electric
power system.
(6) Interconnection customer means any
person who proposes to interconnect a generating facility with the utility's
system.
(7) Interconnection facilities means
the utility's interconnection facilities and the interconnection customer's
interconnection facilities.
Collectively, interconnection facilities include all facilities and
equipment between the generating facility and the point of common coupling,
including any modification, additions or upgrades that are necessary to
physically and electrically interconnect the generating facility to the
utility's electric power system in a safe and reliable manner. Interconnection facilities are sole use
facilities and shall not include distribution upgrades.
(8) Interconnection upgrade cost
sharing
means the allocation of distribution upgrade costs among multiple generator
facility projects that utilize the hosting capacity created by a distribution
upgrade.
(9) Interconnection procedures means
the procedures specified in 17.9.575.12 NMAC through 17.9.575.20 NMAC.
J. Definitions beginning with “J”: [RESERVED]
K. Definitions beginning with “K”: [RESERVED]
L. Definitions beginning with “L”:
(1) Limited export means the
exporting capability of a DER whose generating capacity is limited by the use
of any configuration or operating mode described in 17.9.575.12 NMAC.
(2) Line section means that
portion of a utility’s electric power system connected to a customer that is bounded
by automatic sectionalizing devices or the end of the distribution line.
M. Definitions beginning with “M”:
(1) Material
modification means a modification to machine data, equipment
configuration or to the interconnection site of the DER at any time after
receiving notification by the utility of a complete interconnection application
that has a material impact on the cost, timing, or design of any
interconnection facilities or distribution upgrades, or a material impact on
the cost, timing, or design of any interconnection application with a later
queue priority date or material impact on the safety or reliability of the
electric power system. A change to the
point of interconnection would require either a new interconnection application
or a change in queue position. A material
modification does not include, for example;
(a) a change of ownership of a generating
facility:
(b) a change or replacement of generating
equipment that is a like-kind substitution in size, ratings, impedances,
efficiencies, or capabilities of the equipment specified in the original interconnection
application; or
(c) a reduction in the output of the
generating facility of ten percent or less.
Replacement of existing inverters with new inverters that conform to new
standards after March 28, 2023, will not be considered a material modification,
so long as the generating facilities output or export status does not change as
a result.
(2) Minimum load means the lowest
measured circuit/substation load regardless of time of day.
(3) Minor modification means any modification
to a utility’s electric power system that involves limited work or low costs.
Minor modifications include, but are not limited to, activities like changing
the fuse in a fuse holder cut-out or changing the settings on a circuit
recloser.
N. Definitions beginning with “N”:
(1) Nameplate rating means the sum
total of maximum rated power output of a DER’s constituent generating units or
ESS, as identified on the manufacturer’s nameplate, regardless of whether it is
limited by any approved means.
(2) Network
system means a collection of secondary
networks, or combinations of such networks on a primary network feeder or
primary network feeders that supply them.
This may also consist of primary feeders networked to supply connected
loads.
(3) Network transformer means a
transformer designed for use in a vault to feed a variable capacity system of
interconnected secondaries.
(4) Non-export or non-exporting means when the DER
is sized and designed using any of the methods described in 17.9.575.12 NMAC, such
that the output is used for host load only and no electrical energy (except for
any inadvertent export) is transferred from the generating facility to the distribution
system.
O. Definitions beginning with “O”: Operating mode means the mode of
DER operational characteristics that determines the performance during normal
and abnormal conditions. For example, an
operating modes can include “export only,” “import only,” and “no exchange.”
P. Definitions beginning with “P”:
(1) Parallel operation means the simultaneous operation of a generating facility
with power delivered or received by the electric power system while
interconnected. Parallel operation
includes only those generating facilities that are interconnected with the
electric power system for more than 60 cycles (one second).
(2) Parties means the applicant and
the utility in a particular interconnection agreement. “Either party” refers to
either the applicant or the utility.
(3) Person means, for purposes of this rule, an individual, firm,
partnership, company, rural electric cooperative organized under Laws 1937,
Chapter 100 or the rural electric cooperative act, corporation or lessee,
trustee or receiver appointed by any court.
(4) Point of interconnection means the
point where the interconnection facilities connect with the electric
distribution system. Point of
interconnection has the same meaning as the term “point of common coupling” as
defined in IEEE 1547-2018.
(5) Power control system (PCS) means
systems or devices which electronically limit or control steady state currents
to a programmable limit.
(6) Primary
network feeder means a feeder that supplies energy
to a network system or the combination of a network system and other radial
loads. Dedicated primary network feeders
are feeders that supply only network transformers for the secondary network.
(7) Power conversion unit (PCU) means
an inverter or AC generator, not including the energy source.
(8) Premise means a piece of land
or real estate including buildings and other appurtenances thereon.
(9) Protective function means the
equipment, hardware, or software in a generating facility (whether discrete or
integrated with other functions) for the purpose of protecting against
conditions that, if left uncorrected, could result in harm to personnel, damage
to equipment, loss of safety or reliability, or operation outside
pre-established parameters required by the interconnection agreement.
Q. Definitions beginning with “Q”: [RESERVED]
R. Definitions beginning with “R”:
(1) Rated capacity means the total AC nameplate
rating of the power conversion unit(s) at the point of common coupling.
(2) Reference point of applicability (RPA)
means the
location where the interconnection and interoperability performance
requirements, as specified by IEEE 1547-2018, apply.
(3) Relevant minimum load means the lowest measured circuit
or substation load coincident with the generating facility’s production. For solar-only facilities this shall be the
daytime minimum load.
S. Definitions beginning with “S”:
(1) Secondary network means an AC
distribution system where the secondaries of the distribution transformers are
connected to a common network for supplying electricity directly to consumers.
(2) Simplified process means the
procedure for evaluating an interconnection application for a small certified
inverter-based DER described in Appendix A-1.
(3) Small utility means a utility
that serves fewer than 50,000 customers.
(4) Supplemental review means
additional engineering evaluation to determine if a generating facility can be
interconnected following the (simplified or fast track) process without the
need for detailed study as described in Appendix A-1.
(5) System emergency means a condition
on a utility system that is likely to result in imminent significant disruption
of service to customers or is imminently likely to endanger life or property.
(6) System impact study
means a study that identifies and details the electric system impacts that
would result if the proposed generating facility were interconnected without
project modifications or electric system modifications, focusing on the adverse
system impacts preliminarily identified in the feasibility study (if conducted),
or to study potential impacts, including but not limited to those identified in
the scoping meeting. A system impact
study shall evaluate the impact of the proposed interconnection on the safety
and reliability of the electric power system.
T. Definitions beginning with “T”: Technical interconnection and interoperability
requirements (TIIR) documents
are public documents, often utility specific, which include requirements for
interconnection, interoperability, capabilities, and their utilization
(settings), and grid integration (e.g., protection coordination, telemetry).
U. Definitions beginning with “U”:
(1) UL means the company
by that name which has established technical standards for safe operations of
electrical devices, previously known as underwriter’s laboratory.
(2) UL 1741 CRD for PCS means the certification
requirement decision for power control systems for the standard titled "inverters,
converters, controllers and interconnection system equipment for use with
distributed energy resources”. (March 8, 2019), Underwriters Laboratories Inc.,
333 Pfingsten Road, Northbrook IL 60062-2096.
(3) Unintentional island means an unplanned island per IEEE
1547-2018.
(4) Utility
means a rural electric cooperative, as that term is used in the Rural Electric Cooperative
Act, NMSA 1978, §§ 62-15-1 et seq.
V. Definitions beginning with “V”: [RESERVED]
W. Definitions beginning with “W”: [RESERVED]
X. Definitions beginning with “X”: [RESERVED]
Y. Definitions beginning with “Y”: [RESERVED]
Z. Definitions beginning with “Z”: [RESERVED]
[17.9.575.7 NMAC - N, 11/3/2026]
17.9.575.8 APPLICABILITY: All generating
facilities that operate in parallel with the utility electric power system are
required to have an interconnection review and an interconnection agreement to
ensure safety, system reliability, and operational compatibility. These interconnection procedures are
applicable to all state-jurisdictional interconnections of generating
facilities with a rated capacity up to and including 10 megawatts (MW).
Generating facilities with a rated capacity greater than 10 megawatts (MW) shall
be conducted pursuant to 17.9.569 NMAC. Neither
these procedures nor the requirements included hereunder apply to generating
facilities interconnected or approved for interconnection prior to the
effective date of these procedures.
[17.9.575.8 NMAC - N,
11/3/2026]
17.9.575.9 LIBERAL
CONSTRUCTION: If any part or application of this rule is held invalid, the
remainder of its parts and any other applications of the rule shall not be
affected.
[17.9.575.9 NMAC - N, 11/3/2026]
17.9.575.10 APPLICABLE CODES AND STANDARDS:
A. The
interconnection customer shall install, operate, and maintain the generating
facility and the interconnection equipment in a safe manner in accordance with
the rules for safety and reliability set forth in the latest editions of the
national electrical code, other applicable local, state, and federal electrical
codes, and prudent electrical practices.
B. In
order to qualify for any interconnection procedures, each generating facility
generator shall be in conformance with the following codes and standards (or
their successors) as applicable, unless otherwise provided by law:
(1) IEEE Std 1547™, IEEE standard for interconnection
and interoperability of distributed energy resources with associated electric power
systems interfaces, as amended by IEEE 1547a™-2020, including use of IEEE
1547.1™-2020 testing protocols to establish conformity;
(2) IEEE Std 1547.1™-.2020™, standard conformance
test procedures for equipment interconnecting distributed energy resources with
electric power systems and associated interfaces;
(3) ANSI C84.1-2020, electric power systems
and equipment - voltage ratings (60 Hertz);
(4) IEEE Std 1547.2™-2008™, application
guide for IEEE 1547 standard for interconnecting distributed resources with electric
power systems;
(5) IEEE Std 1547.6™-2011™, IEEE recommended
practice for interconnecting distributed resources with electric power systems distribution
secondary networks;
(6) IEEE Std 1547.7™-2013™, IEEE guide
for conducting distribution impact studies for distributed resource interconnection;
(7) IEEE
C62,92.6™-2017 IEEE Guide for Application of Neutral Grounding in Electrical
Utility Systems, Part VI - Systems Supplied by Current Regulated Sources;
(8) UL 1741, Edition 3, September 28, 2021
Inverters, Converters, Controllers and Interconnection System Equipment for Use
with Distributed Energy Resources;
(9) NFPA 70, current version, National
Electrical Code, including any NM or local modifications;
(10) IEEE C2, current version, National
Electrical Safety Code, including any NM or local modifications;
(11) UL 1741 Certification Requirement
Decision for Power Control Systems, March 8, 2019, Inverters, Converters,
Controllers and Interconnection System Equipment for Use With Distributed
Energy Resources.
C. The
interconnection equipment shall be considered certified for interconnected
operation if the equipment package has been tested and listed by a nationally
recognized testing and certification laboratory (NRTL) for continuous
interactive operation with a utility grid.
[17.9.575.10 NMAC - N, 11/3/2026]
17.9.575.11 IEEE
1547-2018 ADOPTION:
A. Beginning on March 28, 2023 (or another date set by commission
order), generating facilities shall be required to comply with IEEE 1547-2018,
and shall conform with the following minimum requirements.
(1) Abnormal performance requirements: Category III ride through capabilities
must be supported for inverter-based generating facilities. Rotating generating facilities must meet
category I ride-through capabilities.
(2) Normal performance requirements: Inverter-based generating facilities shall
meet reactive power requirements with category B. Rotating generating facilities must meet
category A.
B. Each utility shall post its preferred default settings in
their public facing Technical Interconnection and Interoperability Requirements
(TIIR) document. As applicable the
following shall be identified in the TIIR documents:
(1) voltage and frequency trip settings;
(2) frequency droop settings;
(3) activated reactive power control
function and default settings;
(4) voltage active power (volt-watt) mode
activation and default settings;
(5) communication protocols and ports
requirements.
[17.9.575.11 NMAC - N, 11/3/2026]
17.9.575.12 DETERMINATION OF EXPORT CAPACITY
STATUS:
A. Export
controls: If a DER uses any configuration or operating mode in subsection C to
limit the export of electrical power across the point of interconnection, then
the export capacity shall be only the amount of power capable of being exported
(not including any inadvertent export). To prevent impacts on system safety and
reliability, any inadvertent export from a DER must comply with the limits
identified in this section. The export capacity
specified by the interconnection customer in the interconnection application
will be documented as the maximum allowed export capacity of the DER in the
interconnection agreement.
B. An interconnection application
proposing to use a configuration or operating mode to limit the export of
electrical power across the point of interconnection shall include proposed
control or protection settings.
C. Acceptable export control methods:
(1) Export control methods for non-exporting
DER:
(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 shall be one tenth percent (export)
of the service transformer's nominal base nameplate rating, with a maximum two
second time delay to limit inadvertent export.
(b) Minimum power protection (Device
32F): To limit export of power across the point of interconnection, a minimum
import protective function is implemented utilizing a utility grade protective
relay. The default setting for this
protective function shall be five percent (import) of the generating unit's
total nameplate capacity, with a maximum two second time delay to limit
inadvertent export.
(c) Relative distributed energy resource
rating: This option requires the DER facility's nameplate capacity to be no
greater than fifty percent of the interconnection customer's verifiable minimum
host load during DER operating hours over the past 12 months. This option is not available for
interconnections to area networks or spot networks.
(2) Export control methods for limited export
DER:
(a) Directional power protection
(Device 32): To limit export of power
across the point of interconnection, a directional power protective function is
implemented using a utility grade protective relay. The default setting for this protective
function shall be the export capacity value, with a maximum 2.0 second time
delay to limit inadvertent export.
(b) Configured power rating: A reduced output power rating utilizing the
power rating configuration setting may be used to ensure the DER does not
generate power beyond a certain value lower than the nameplate capacity. The configuration
setting corresponds to the active or apparent power ratings in Table 28 of IEEE
Std 1547-2018, as described in subclause 10.4. A local DER communication interface is not
required to utilize the configuration setting if it can be set by other certified
means. The reduced power rating may be
indicated by means of a nameplate rating replacement or, a supplemental
adhesive de-rating tag to indicate the reduced power output capacity. The customer must also provide a signed
attestation confirming the reduced power output capacity. This method must be
certified to IEEE 1547.1-2020. Use of a
configured power rating not applied to individual power conversion unit(s)
shall require evaluation under mutually agreed-upon means.
(3) Export control methods for non-exporting
DER or limited export DER:
(a) Certified power control systems: DER facilities may use certified power control
systems to limit export. DER facilities
utilizing this option must use a power control system and inverter certified
per UL 1741 by a nationally recognized testing laboratory (NRTL) with a maximum
open loop response time of no more than 30 seconds. NRTL testing to the UL power control system
certification requirements decision shall be accepted until similar test
procedures for power control systems are included in a standard. This option is not available for
interconnections to area networks or spot networks.
(b) Agreed-upon means: DER facilities may
be designed with other control systems or protective functions to limit export
and inadvertent export if mutual agreement is reached with the distribution provider.
The limits may be based on technical
limitations of the interconnection customer's equipment or the electric
distribution system equipment. To ensure
inadvertent export remains within mutually agreed-upon limits, the
interconnection customer may use an uncertified power control system, an
internal transfer relay, energy management system, or other customer facility
hardware or software if approved by the distribution provider.
[17.9.575.12 NMAC - N, 11/3/2026]
17.9.575.13 INTERCONNECTION APPLICATION: An interconnection customer shall submit its interconnection application to the utility
using Appendix B-1 or B-2 as applicable, together with the fees specified in
17.9.575.19 NMAC.
A. The
utility shall record the date and time on the face of the
interconnection application upon receipt by the utility. The original date and time recorded by the
utility on the interconnection application at the time of its original
submission shall be accepted as the date and time on which the interconnection application
was received for the purposes of any timetable established in this rule or in
Appendix A-1. Following submission of the interconnection application, the
parties will follow the procedures and time requirements described in Appendix
A-1.
B. The utility shall place interconnection applications
in the order they are received. The
order of each interconnection application will be used to determine the cost
responsibility for the upgrades necessary to accommodate the interconnection. At the utility’s option, interconnection applications may be studied serially or in
clusters for the purpose of the system impact study.
[17.9.575.13 NMAC - N, 11/3/2026]
17.9.575.14 INTERCONNECTION AGREEMENT:
A. For simplified
process interconnection projects, the applicant will sign a form interconnection
agreement at the time it submits its interconnection application, and the
utility will return a counter-signed interconnection agreement.
B. For fast track and
detailed study interconnection projects: after receiving an interconnection
agreement from the utility, the applicant shall have 30 business days or
another mutually agreeable timeframe to sign and return the interconnection
agreement. If the applicant does not
sign the interconnection agreement within 30 business days, the interconnection
application shall be deemed withdrawn. After
the interconnection agreement is signed by the parties, the interconnection of
the generating facility shall proceed under the provisions of the
interconnection agreement.
C. Nothing in this rule shall
preclude a utility from establishing reasonable operational requirements for
DER interconnection, including limitations on export capability, through the
interconnection agreement process, provided such requirements are applied on a
non-discriminatory basis to all functionally equivalent DER technologies.
[17.9.575.14 NMAC - N,
11/3/2026]
17.9.575.15 OPTIONAL
PRE-APPLICATION REPORT: Potential applicants may request this optional report for a
specific site to get information about system conditions at their proposed
point of interconnection without submitting a full interconnection application.
A. Costs of
pre-application reports: The utility
may collect from the applicant the reasonable cost incurred to perform or
obtain necessary expertise from consultants to produce a pre-application
report. The utility shall provide a good
faith estimate of the costs of such consultants to an applicant within 10
business days of the date the interconnection applicant submits their request
for a pre-application report.
B. Time
frames for pre-application reports: Pre-application
reports should be completed in 20 business days for system sizes up to one MW,
and 30 business days for system sizes greater than one MW, from the receipt of
the completed request form and payment of the fee. If it can be documented that a utility cannot
meet this deadline due to circumstances beyond their control, then the utility
will be given more time but must notify the applicant.
C. Length of
time for accuracy of information: Due
to the dynamic nature of the electric power system, accuracy cannot be
guaranteed past the time of completion of a report. The pre-application report shall be
non-binding on the utility and shall not confer any rights to the
interconnection customer. The provided
information does not guarantee that an interconnection may be completed.
D. Potential
applicants shall provide the following information to the utility to expedite
its pre-application review:
(1) project
contact information including name, address, phone number, and email address;
(2) project
location (street address with nearby cross streets, and town/city);
(3) meter number,
pole number, or other equivalent information (such as latitude and longitude
coordinates) identifying the potential point of interconnection, if available;
(4) generator
type (i.e., solar, wind, combined heat and power) and whether energy storage
will be collocated with the generation;
(5) nameplate
capacity (in alternating current kW);
(6) single or
three phase generator configuration;
(7) stand-alone
generator with no on-site load (yes or no?); and
(8) whether new
service is requested. If there is existing service, include the customer
account number, site minimum and maximum existing or proposed maximum loads in
kW and specify if the amount of any anticipated additional load is expected to
change.
E. The
pre-application report shall be completed by the utility per the schedule in
Subsection B of this section and include the following information, if
available:
(1) Total
capacity (MW) of substation/area bus or bank and circuit likely to serve
proposed site. If substation or circuit planned capacity limits are less than
the total capacity the utility shall indicate the planned capacity limits.
(2) Aggregate
existing export capacity (MW) interconnected to the substation/area bus or bank
and circuit likely to serve proposed site.
(3) Aggregate
queued export capacity (MW) proposing to interconnect to the substation/area
bus or bank and circuit likely to serve proposed site.
(4) Available
capacity (MW) of substation/area bus or bank and circuit likely to serve
proposed site. Available capacity is the total capacity less the sum of
existing and queued export capacity, accounting for all load served by existing
and queued generators.
(5) Whether the
proposed generating facility is located on an area, spot or radial network.
(6) Nominal
distribution circuit voltage at the proposed site.
(7) Approximate
circuit distance between the proposed site and the substation.
(8) Relevant line
section(s) and substation actual or estimated peak load and minimum load data,
when available.
(9) Manufacturer
model number/type and rating of protective devices and number and type of
voltage regulating devices between the proposed site and the substation/area.
(10) Whether or not
three-phase power is available at the site or distance from three-phase
service.
(11) Limiting
conductor rating from proposed point of interconnection to distribution
substation.
(12) Based on
proposed point of interconnection, existing or known constraints such as, but
not limited to, electrical dependencies at that location, short circuit
interrupting capacity issues, power quality or stability issues on the circuit,
capacity constraints, or secondary networks.
(13) Any other
information the utility deems relevant to the interconnection application.
F. The
pre-application report need only include pre-existing data. A pre-application report request does not
obligate the utility to conduct a study or other analysis of the proposed
project if that data is not available. If the utility cannot complete all or
some of a pre-application report due to lack of available data, the utility
will provide the potential applicant with a pre-application report that
includes the information that is available and identify the information that is
unavailable.
G. Notwithstanding
any of the provisions of this section, the utility shall, in good faith,
provide pre-application report data that represents the best available
information at the time of reporting.
[17.9.575.15 NMAC - N, 11/3/2026]
17.9.575.16 PERMISSION TO OPERATE:
A. The interconnection
customer may not commence operations until its interconnection application is
deemed complete and the utility has issued a permission to operate (PTO). The interconnection customer shall provide the utility with at
least 10 business days’ notice of the anticipated start date of the generating
facility. Within 10 business days of
receiving the notice of the anticipated start date of the generating facility,
the utility may conduct an inspection of the generating facility at a time
mutually agreeable to the parties. The
inspection may include verification that the facility complies with applicable
codes and standards, the terms of the interconnection agreement, and may
include a witness test. The utility may
also schedule appropriate metering replacement or programming if necessary. If the generating facility passes the
inspection, the utility shall provide written notice of the passage within
three business days. If a Generating
Facility initially fails a utility inspection, the utility shall offer to redo
the inspection at the applicant’s expense at a time mutually agreeable to the
parties. If the utility determines that
the generating facility fails the inspection, the utility must provide the
applicant with a written explanation detailing the reasons for the failure and
any standards violated. If the utility
determines no inspection is necessary, it shall notify the applicant within
three business days of receiving the notice of the anticipated start date. For simplified
process and fast track generating facilities, utility approval for interconnection
(i.e. permission to operate) shall normally be processed not later than 10 business
days following the utility’s receipt of:
(1) a
completed net energy metering interconnection application, if appropriate,
including all supporting documents and required payments;
(2) a
completed signed interconnection agreement, if appropriate; and
(3) evidence
of the applicant’s final electric inspection clearance from the governmental authority
having jurisdiction over the generating facility. If the 10-day period cannot be met, the utility
shall notify the applicant.
B. A generating facility that has
not been approved for parallel operation within one year of execution of the
interconnection agreement is subject to withdrawal by utility; however, the
utility may not deem the interconnection application withdrawn if:
(1) applicant provides reasonable evidence
that the interconnection application is still active; or
(2) the delay is at no fault of applicant.
[17.9.575.16 NMAC - N,
11/3/2026]
17.9.575.17 APPLICATION
REVIEW PROCESS: The
utility shall utilize the interconnection screening process and the screen
criteria described in Appendix A-1.
A. There are four
interconnection review paths:
(1) Simplified
interconnection: For certified
inverter-based generating facilities with a power rating of 25 kilowatts (kW)
or less on radial or network systems under certain conditions.
(2) Fast track with
or without supplemental review: For
certified generating facilities that pass certain specified screens and likely
would have a power rating of less than 1.0 megawatts (MW).
(3) Full
interconnection study: For
generating facilities that have a power rating of 1.0 megawatt (MW) or less
that do not qualify for the simplified or fast track processes.
(4) Case specific
review process: for generating facilities with a rated capacity greater
than 1.0 megawatt (MW), which shall be reviewed pursuant to the process set
forth in 17.9.569 NMAC for larger facilities.
B. Application
submittal: The interconnection
applicant shall submit an interconnection application (see Appendices B-1 or
B-2, as appropriate) to the utility, together with the applicable processing
fee identified in 17.9.575.20 NMAC. The application shall be date and
time-stamped upon receipt for the purposes of any timetable in these
procedures.
C. Completeness
review: Utility shall notify the
interconnection applicant, via email or other means, that the interconnection
application has been received within three business days of receipt of the
interconnection application. Within 10
business days of receipt, the utility shall notify the applicant whether the
interconnection application is deemed complete and valid. If the application is
incomplete, the utility shall provide the applicant with a list of all
information that the applicant must provide to complete the application. The applicant must provide the requested
information within 10 business days, or the application will be deemed
withdrawn.
D. Interconnection
queue position and posting: The utility shall assign the interconnection
application a queue position based on when it is received under Subsection A of
17.9.575.13 NMAC.
(1) The utility shall
maintain a single queue,
(2) The queue position
of each interconnection application will be used to determine the cost
responsibility for the upgrades necessary to accommodate the interconnection.
(3) The queue shall be
publicly available on the utility’s website and be updated at least monthly.
(4) If an application
fails the screening process under the simplified or fast track process, but the
applicant decides to continue with review (including supplemental review) under
another level, the applicant shall retain its original queue position.
(5) If an
interconnection application fails the screening process under the simplified or
fast track process, but the applicant decides to continue with review
(including supplemental review) under another level, the applicant shall retain
its original queue position.
E. Modifications to generating facility:
(1) At any time after an
interconnection application is deemed complete or an interconnection agreement
has been signed, if the applicant wishes to make modifications to the planned
generating facility it shall submit to the utility, in writing, all proposed
modifications to any information provided in the interconnection application or
in the interconnection agreement. Any modification to machine data, equipment
configuration, or to the interconnection site of the generating facility not
agreed to in writing by the utility and the interconnection customer may be
deemed a withdrawal of the interconnection application.
(2) Within 10 business
days of receipt of a proposed modification, the utility shall notify the
applicant whether a proposed modification to either an interconnection
application or an existing generating facility constitutes a material
modification.
(a) If the utility
determines the proposed modification is a material modification, then the
utility shall notify the interconnection customer in writing that the customer
may:
(i) withdraw the proposed modification; or
(ii) proceed with a new
interconnection application for such modification. The interconnection customer
shall provide its determination in writing to the utility within 10 business
days after being provided the material modification determination results. If the
interconnection customer does not provide its determination, the proposed
modification shall be deemed withdrawn.
(b) If the proposed
modification is determined not to be a material modification, then the utility
shall notify the interconnection customer in writing that the modification has
been accepted and that the customer shall retain its eligibility for
interconnection, including its place in the interconnection queue. Existing
generating facilities may make the modification without requiring a new
interconnection application.
(3) Any dispute as to
the utility’s determination that a modification constitutes a material
modification shall proceed in accordance with the dispute resolution provisions
in 17.9.575.26 NMAC.
(4) Any modification to
machine data, equipment configuration, or to the interconnection site of the
generating facility not agreed to in writing by the utility and the
interconnection customer may be deemed a withdrawal of the interconnection
application and may require submission of a new interconnection application,
unless proper notifications of each party by the other as described in
Paragraphs (1) and (2) of Subsection E of 17.9.575.13 NMAC.
F. Site Control: Documentation of site control must be
submitted with the interconnection request. Site control may be demonstrated
by:
(1) ownership of, or a
leasehold interest in, or a right to develop a site for the purpose of
constructing a generating facility;
(2) a fully executed
option to purchase or acquire a leasehold site for such purpose; or
(3) a fully executed
agreement demonstrating exclusivity or other business relationship between the
interconnection applicant and the entity having the authority to grant the
applicant the right to possess or occupy a site for such purpose.
[17.9.575.17 NMAC - N, 11/3/2026]
17.9.575.18 INTERCONNECTION APPLICATION REVIEW
FLOW CHART: [RESERVED]
[17.9.575.18 NMAC - N, 11/3/2026]
17.9.575.19 GENERAL PROVISIONS APPLICABLE TO
INTERCONNECTION APPLICATIONS:
A. An
applicant shall pay the following application fee to the utility at the time it
delivers its interconnection application to the utility:
(1) $150.00 if
the proposed generating facilities will have a nameplate rating less than or
equal to 25 kW;
(2) $300.00 if
the proposed generating facilities will have a nameplate rating greater than 25
kW and less than or equal to 100 kW; or
(3) $300.00 + $1.00
per kW if the proposed generating facilities will have a nameplate rating
greater than 100 kW;
(4) if the
proposed generating facility is non-export only, it shall pay $150.00, if it
has a nameplate rating below 100kW, or $300 if the nameplate rating is greater
than 100 kW.
B. In
addition to the fees authorized by this rule, a small utility may collect from
the applicant the reasonable costs incurred to obtain necessary expertise from
consultants to review interconnection applications for generating facilities
with rated capacities greater than 10 kW.
A small utility shall provide a good faith estimate of the costs of such
consultants to an applicant within 10 business days of the date the
interconnection application is delivered to the utility.
C. Commissioning
tests of the interconnection customer's installed equipment shall be performed
pursuant to applicable codes and standards, including IEEE 1547.1 “IEEE
standard conformance test procedures for equipment interconnecting distributed
energy resources with electric power systems.”
A utility must be given at least five business days written notice of
the tests, or as otherwise mutually agreed to by the parties, and may be
present to witness the commissioning tests.
An interconnection customer shall reimburse a utility for its costs
associated with witnessing commissioning tests performed except that a utility
may not charge a fee in addition to the interconnection application fee for the
cost of witnessing commissioning tests for inverter-based generating facilities
that have nameplate capacities that are less than or equal to 25 kW.
D. If
an interconnection customer requests an increase in capacity for an existing
generating facility, the interconnection application shall be evaluated on the
basis of the new total capacity of the generating facility. If an interconnection customer requests
interconnection of a generating facility that includes multiple energy
production devices at a site for which the interconnection customer seeks a
single point of common coupling, the interconnection application shall be
evaluated on the basis of the aggregate capacity of the multiple devices.
E. Confidential
information shall remain confidential unless otherwise ordered by the
commission. Confidential information
shall mean any confidential and proprietary information provided by one party
to the other party that is clearly marked or otherwise designated
“confidential”.
[17.9.575.19 NMAC - N,
11/3/2026]
17.9.575.20 GENERAL PROVISIONS APPLICABLE TO
UTILITIES:
A. A
utility shall interconnect any interconnection customer that meets the
interconnection criteria set forth in this rule. A utility shall make reasonable efforts to
keep the applicant informed of the status and progress.
B. Utilities
shall reasonably endeavor to aid and assist interconnection customers to ensure
that a proposed generating facility's interconnection design, operation, and
maintenance are appropriate for connection to the utility’s system. This may include consultations with the applicant
and its engineer and other representatives.
C. Utilities
shall make reasonable efforts to meet all time frames provided for in this rule
unless a utility and an applicant agree to a different schedule. If a utility cannot meet a deadline provided
herein, it shall notify the applicant in writing within one business day,
explain the reason for its inability to meet the deadline, and provide an
estimated time by which it will complete its activity. The utility shall keep the applicant updated
of any changes in the expected completion date.
D. Utilities
shall use the same reasonable efforts in processing and analyzing
interconnection applications from all interconnection customers, whether the
generating facility is owned or operated by the utility, its subsidiaries or
affiliates, or others.
E. Utilities
shall maintain records for three years of each interconnection application
received, the times required to complete each interconnection application
approval or disapproval, and justification for the utility’s disapproval of any
interconnection application. Other reporting requirements are specified in
17.9.575.23 NMAC.
F. Utilities
shall maintain current, clear, and concise information regarding this rule
including the name, telephone number, and email address of contact
persons. The information shall be easily
accessible on the utility’s website beginning within one month of the effective
date of this rule, or the information may be provided in bill inserts or
separate mailings sent no later than one month after the effective date of this
rule and no less often than once each year thereafter. Each utility shall maintain a copy of this
rule at its principal office and make the same available for public inspection
and copying during regular business hours.
G. A
small utility that uses a consultant to review a proposal to interconnect a
generating facility with the small utility's system may extend each of the time
deadlines for review of the fast track process by a period not to exceed 20
business days provided that the small utility shall make a good faith effort to
complete the review sooner.
H. Compliance
with this interconnection process does not constitute a request for, nor
provision of any transmission delivery service, or any local distribution
delivery service. Interconnection under
this rule does not constitute an agreement by the utility to purchase or pay
for any energy, inadvertently or intentionally exported.
[17.9.575.20 NMAC - N,
11/3/2026]
17.9.575.21 GENERAL PROVISIONS APPLICABLE TO
INTERCONNECTION CUSTOMERS:
A. The
cost of utility system modifications shall be borne by the interconnection
customer unless otherwise agreed by the parties.
B. An interconnection customer shall
have thirty (30) business days (or other mutually agreeable period) following
receipt of an interconnection agreement to execute the agreement and return it
to the utility. If the interconnection
customer does not execute the interconnection agreement and return it to the
utility within the applicable period, the interconnection application shall be
deemed withdrawn. After all parties
execute an interconnection agreement, interconnection of the generating
facility shall proceed
C. An interconnection customer is
responsible for the prudent maintenance and upkeep of its interconnection
equipment.
D. Upon the petition of a utility, for
good cause shown, the commission may require a customer with a generating
facility with a rated capacity of 250 kW or less to obtain general liability
insurance prior to connecting with a public utility. A utility may require that an applicant proposing
to connect a generating facility with a rated capacity greater than 250 kW
provide proof of insurance with reasonable limits not to exceed $1,000,000.00
or other reasonable evidence of financial responsibility.
[17.9.575.21 NMAC - N,
11/3/2026]
17.9.575.22 EXTENSIONS:
A. The applicant may
request in writing the extension of one timeline set by these rules. The requested extension may be for up to
one-half of the time originally allotted (e.g., a 10-business-day extension for
a 20-business-day timeframe). The
utility shall not unreasonably refuse this request.
B. If further timeline
extensions are necessary, the applicant may request an extension, and the
utility shall grant the extension so long as it does not unreasonably delay the
processing of later queued interconnection applications.
[17.9.575.22 NMAC - N,
11/3/2026]
17.9.575.23 DISPUTE
RESOLUTION:
A. Each
party agrees to attempt to resolve all disputes arising hereunder promptly,
equitably and in a good faith manner.
B. In
the event of a dispute, either party shall provide the other party with a
written notice of dispute. Such notice shall describe in detail the nature of
the dispute. The non-disputing party
shall acknowledge the notice within three business days of its receipt and
identify a representative with the authority to make decisions for the
non-disputing party with respect to the dispute.
C. If
the dispute has not been resolved in eight business days for timeline related
disputes or 20 business days for all other disputes after the receipt of the
notice, the parties may, upon mutual agreement:
(1) continue negotiations for an
additional 10 business days; or
(2) seek resolution through the assistance
of a dispute resolution service. The
dispute resolution service will assist the parties in either resolving the
dispute or in selecting an appropriate dispute resolution venue (e.g.,
mediation, settlement judge, early neutral evaluation, or qualified technical
expert(s)) to assist the parties in resolving their dispute. Each party will be responsible for one-half of
any costs paid to neutral third-parties.
D. For
any technical disputes, both parties shall have a qualified technical
representative present in the attempts to resolve the dispute.
E. If
the dispute remains unresolved after 30 business days, either party may
petition the commission to handle the dispute as a formal complaint or may
exercise whatever rights and remedies it may have in equity or law.
F. If
the dispute remains unresolved after 90 business days, a formal complaint to
the commission has not been submitted, and the dispute is causing delays to
other projects in the queue, the utility may adjust the queue position of the
disputing project. The disputing party shall be responsible for any additional
study costs that may result from the change in queue position.
[17.9.575.23 NMAC - N,
11/3/2026]
17.9.575.24 NON-REPORTING REQUIREMENTS: For each request for a pre-application report or interconnection
application received, the utility shall collect and retain the following
data, at a minimum, consistent with their data records and retention practices:
A. facility
capacity;
B. DER
type (technology);
C. number of pre-application reports
requested and processed;
D. date
of interconnection application submittal;
E. date
interconnection application deemed complete;
F. interconnection
fees and study costs assessed to the customer;
G. interconnection facility and distribution upgrade
costs assessed to the customer;
H. number of times outside consultants were utilized
and the range of fees assessed to the customer for the consultant’s services.
[17.9.575.24 NMAC - N,
11/3/2026]
17.9.575.25 SAFETY PROVISIONS:
A. A
DER project that operates outside of its approved export status or operational
limits may be disconnected by the utility following notification of violation
and a 30-day cure period.
B. An interconnection customer shall
separate from the utility system in the event of any one or more of the
following conditions:
(1) a fault on the generating facility's
system; or
(2) a generating facility contribution to
a utility system emergency; or
(3) abnormal frequency or voltage
conditions on the utility’s system; or
(4) any occurrence or condition that will
endanger utility employees or customers; or
(5) a generating facility condition that
would otherwise interfere with a utility’s ability to provide safe and reliable
electric service to other customers; or
(6) the sudden loss of the system power.
C. The
utility may temporarily disconnect the generating facility upon the following
conditions:
(1) for scheduled outages per notice requirements in the
utility’s tariff or commission rules;
(2) for unscheduled outages or emergency conditions
pursuant to Subsection B of 17.9.575.29 NMAC;
(3) if the generating facility does not operate in the
manner consistent with these terms and conditions;
(4) the utility shall inform the customer in advance of
any scheduled disconnection, or as is reasonable after an unscheduled
disconnection.
D. A visible-open, load break disconnect
switch between the generating facility and the utility system that is visibly
marked "generating facility generation disconnect" and is accessible
to and lockable by the utility is required for all generating facilities except
for those generating facilities with a maximum capacity rating of 10 kW or less
that use a certified inverter including a self-contained renewable energy
certificate (REC) meter and either:
(1) a utility accessible AC load break disconnect; or
(2) a utility accessible DC load break disconnect where there is no other
source of generated or stored energy connected to the system.
E. Interconnection
customers shall post a permanent and weatherproof one-line electrical diagram
of the generating facility located at the point of service connection to the
utility. Generating facilities where the
disconnect switch is not located in close proximity to the utility meter must
post a permanent and weatherproof map showing the location of all major
equipment including the utility meter point, the generating facility generation
disconnect, and the generating facility generation breaker. Non-residential generating facilities larger
than 10 kW shall include with or attached to the map the names and current
telephone numbers of at least two persons authorized to provide access to the
generating facility and who have authority to make decisions regarding the
generating facility interconnection and operation.
F. If
the generating facility interconnection equipment package is not certified or
if a certified equipment package has been modified, the generating facility
interconnection equipment package shall be reviewed and approved by a
professional electrical engineer, registered in the state of New Mexico.
[17.9.575.25 NMAC - N,
11/3/2026]
17.9.575.26 COST SHARING FOR INTERCONNECTION
UPGRADES:
A. The cost of utility
system modifications required pursuant to the fast track process or the full
interconnection study process shall be borne by the applicant unless otherwise
agreed to by the parties or following a determination by the commission that some
or all of the costs constitute system benefits eligible for cost-sharing
options:
(1) The commission may determine on a case-by-case basis
whether the cost of distribution system upgrades necessary to interconnect one
or more generating facilities may be eligible for some form of cost sharing:
(a) among several developers using the
same distribution facilities;
(b) among all ratepayers of the
qualifying utility via rate base adjustments; or
(c) among ratepayers of the same rate
class as subscribers to the community solar facility via a rate rider for that
class.
(2) In
making such a determination that there are public benefits to such a
cost-sharing mechanism, the commission shall employ the same analysis as
provided for cost-sharing or rate basing grid modernization projects as defined
by Section 62-8-13 NMSA 1978 (Grid Modernization Act 2019, HB 233) to make a
finding that the approved expenditures are:
(a) reasonably expected to improve the
public utility’s electrical system efficiency, reliability, resilience and
security; maintain reasonable operations, maintenance and ratepayer costs; and
meet energy demands through a flexible, diversified and distributed energy
portfolio;
(b) reasonably expected to increase access
to, and use of, clean and renewable energy, with consideration given to
increasing access to low-income subscribers and subscribers in underserved
communities;
(c) designed to contribute to the
reduction of air pollution, including greenhouse gases;
(3) Expenditures approved for such cost sharing of necessary
interconnection upgrades shall not be considered a “subsidization” subject to
the three percent limitations spelled out in this rule or in the Community
Solar Act.
[17.9.575.26 NMAC - N, 11/3/2026]
17.9.575.27 VARIANCES: A party may file a
request for a variance from the requirements of this rule. Such application shall describe the reasons
for the variance; set out the effect of complying with this rule on the parties
and the utility’s customers if the variance is not granted; identify the
section(s) of this rule for which the variance is requested; describe the
expected result which the request will have if granted; and state how the
variance will aid in achieving the purposes of this rule. The commission may grant a request for a
procedural variance through an order issued by the chairman, a commissioner or
a designated hearing examiner. Other variances shall be presented to the
commission as a body for determination.
[17.9.575.27 NMAC - N,
11/3/2026]
17.9.575.28 APPENDICES:
A. Appendix A-1 - Interconnection Manual.
B. Interconnection Applications:
(1) Appendix B-1 - Simplified
Interconnection Application.
(2) Appendix B-2 - Standard
Interconnection Application.
C. Interconnection Agreements:
(1) Appendix C-1 - Simplified
Interconnection Agreement.
(2) Appendix C-2 - Standard
Interconnection Agreement.
[17.9.575.28 NMAC - N, 11/3/2026]
History of 17.9.575 NMAC:
[RESERVED]