Current through Register Vol. 30, No. 38, September 20, 2024
A. If a Utility
determines that an Application for Interconnection cannot be approved without
conducting a Supplemental Review, or if requested by the Applicant:
1. The Utility shall, within seven calendar
days of making the determination or receiving the request, provide the
Applicant a good faith estimate of the cost of the Supplemental Review and a
written agreement setting forth the terms of the Supplemental Review;
and
2. If the Customer desires to
proceed with the Application, the Customer shall, within 14 calendar days of
receipt of the good faith estimate and written agreement, sign the written
agreement and submit to the Utility a deposit for the full estimated cost of
the Supplemental Review.
B. The Applicant may specify the order in
which the Utility will complete the screens in subsection (E).
C. The Applicant shall be responsible for the
Utility's actual costs for conducting a Supplemental Review and must pay any
review costs exceeding the deposit amount within 30 calendar days of receipt of
an invoice for the balance, or resolution of any dispute as to those costs. If
the deposit amount exceeds the actual costs of the Supplemental Review, the
Utility shall return such excess to the Customer, without interest, within 30
calendar days of completing the Supplemental Review.
D. Within 21 calendar days following receipt
of the deposit for a Supplemental Review, the Utility shall:
1. Perform a Supplemental Review by
determining compliance with the screens in subsections (E)(1), (2), and
(3);
2. Unless the Applicant has
previously provided instructions for how to respond to the Generating
Facility's failure to meet any of the Supplemental Review screens:
a. Notify the Applicant following the failure
of any of the screens; and
b. If
the Utility is unable to determine compliance with the screen in subsection
(E)(1), notify the Applicant within two calendar days of making such
determination and request the Applicant's permission to:
i. Continue evaluating the Interconnection
under subsection (E);
ii. Terminate
the Supplemental Review and continue evaluating the Generating Facility under
R14-2-2619; or
iii. Terminate the
Supplemental Review upon withdrawal of the Interconnection request by the
Applicant; and
3. Notify the Applicant of the results of the
Supplemental Review along with copies of the analysis and data underlying the
Utility's determinations of compliance with the screens.
E. A Utility shall apply the following
screens in its Supplemental Review:
1. A
minimum load screen:
a. If 12 months of line
section minimum load data (including onsite load but not station service load
served by the Generating Facility) are available, can be calculated, can be
estimated from existing data, or can be determined from a power flow model, the
aggregate Generating Facility Maximum Capacity on the line section shall be
less than 100% of the minimum load for all line sections bounded by automatic
sectionalizing devices upstream of the Generating Facility.
b. If 12 months of line section minimum load
data are not available, or cannot be calculated, estimated, or determined, the
Utility shall include in its Supplemental Review results notification under
subsection (D) each reason that it is unable to calculate, estimate, or
determine minimum load.
c. In
making its determination of compliance with subsections (E)(1)(a) and (b), the
Utility shall:
i. Consider the type of
generation used by the Generating Facility when calculating, estimating, or
determining the circuit or line section minimum load, using daytime minimum
load for solar photovoltaic generation systems with no battery storage (i.e.,
10 a.m. to 4 p.m. for fixed panel systems and 8 a.m. to 6 p.m. for solar
photovoltaic generation systems utilizing tracking systems), and using absolute
minimum load for all other generation;
ii. For a Generating Facility that serves
some station service load, consider only the net injection into the Utility's
electric system as part of the aggregate generation; and
iii. Not consider as part of the aggregate
generation Generating Facility capacity known to be reflected already in the
minimum load data.
2. A voltage and power quality screen: In
aggregate with existing Maximum Capacity on the line section:
a. Voltage regulation on the line section
shall be maintained in compliance with relevant requirements under all system
conditions;
b. Voltage fluctuation
shall be within acceptable limits as defined by IEEE 1453, IEEE Recommended
Practice for the Analysis of Fluctuating Installations on Power Systems
(October 30, 2015), with no future editions or amendments, which is
incorporated by reference; on file with the Commission; and published by and
available from IEEE, 3 Park Avenue, 17th Floor, New York, New York 10016, and
through
http://ieeexplore.ieee.org;
and
c. Harmonic levels shall meet
IEEE 519 limits, IEEE Recommended Practice and Requirements for Harmonic
Control in Electric Power Systems (June 11, 2014), with no future editions or
amendments, which is incorporated by reference; on file with the Commission;
and published by and available from IEEE, 3 Park Avenue, 17th Floor, New York,
New York 10016, and through
http://ieeexplore.ieee.org.
3. A safety and reliability
screen: The location of the Generating Facility and the aggregate Maximum
Capacity on the line section shall not create impacts to safety or reliability
that cannot be adequately addressed without application of the Interconnection
Study process. In making this determination regarding potential impacts to
safety and reliability, the Utility shall give due consideration to the
following, and any other relevant factors:
a.
Whether the line section has significant minimum loading levels dominated by a
small number of customers (e.g., several large commercial customers);
b. Whether the loading along the line section
is uniform or even;
c. Whether the
Generating Facility is located in close proximity to the substation (i.e.,
within less than 2.5 electrical circuit miles);
d. Whether the line section from the
substation to the Point of Interconnection is a main feeder line section rated
for normal and emergency ampacity;
e. Whether the Generating Facility
incorporates a time delay function to prevent reconnection of the generator to
the system until system voltage and frequency are within normal limits for a
prescribed time;
f. Whether
operational flexibility is reduced by the Generating Facility, such that
transfer of the line section(s) of the Generating Facility to a neighboring
distribution circuit/substation may trigger overloads or voltage issues;
and
g. Whether the Generating
Facility employs equipment or systems certified by a recognized standards
organization to address technical issues such as, but not limited to,
Islanding, reverse power flow, or voltage quality.
F. If the Interconnection
satisfies subsection (E), the Application shall be approved for
Interconnection, and the Utility shall provide the Applicant notice of the
Supplemental Review results.
G. If
Interconnection Facilities or minor modifications to the Utility's system are
required for the Interconnection to meet the screens in subsection (E), the
Utility shall notify the Applicant and request for the Applicant to pay for the
modifications. If the Applicant agrees to pay for the modifications to the
Utility's electric system, the Utility shall provide an Interconnection
Agreement, along with a non-binding good faith estimate of the cost for the
Interconnection Facilities and minor modifications, to the Applicant within
seven calendar days after the Applicant agrees to pay for the
modifications.
H. If more than
Interconnection Facilities or minor modifications to the Utility's system would
be required for the Interconnection to meet the screens in subsection (E), the
Utility shall notify the Applicant, at the same time it notifies the Applicant
of the Supplemental Review results, that the Interconnection request shall be
evaluated under R14-2-2619, unless the Applicant withdraws its
Application.
I. If the
Interconnection fails any of the screens in subsection (E), and the Applicant
does not withdraw its Application, the Utility shall continue to evaluate the
Application under R14-2-2619.
