Current through Register Vol. 63, No. 12, December 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within that timeframe, the Application will be deemed withdrawn unless the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.
(b) Voltage
and Power Quality Screen. In aggregate with existing generation on the line
section:
(A) The voltage regulation on the
line section can be maintained in compliance with relevant requirements under
all system conditions;
(B) The
voltage fluctuation is within acceptable limits as defined by IEEE Std
1547TM;
(C) The harmonic levels meet IEEE 1547 limits
at the Point of Interconnection; and
(D) Substation transformer backfeed screen.
Where existing protective devices and equipment cannot adequately support
backfeed, the aggregated export capacity on the substation transformer must be
less than 80 percent of the relevant minimum load for the substation
transformer.
(E) Supplemental
Grounding Screen: If the project failed the Line Configuration Screen, apply
the Supplemental Grounding Screen in paragraphs (F)-(H). If the project limits
export pursuant to OAR 860-082-0033, the export capacity must be included in
any analysis including power flow simulations.
(F) For projects with a rotating machine, if
effective grounding is maintained, the project passes the screen.
(G) For projects with a three-phase inverter,
apply one of the following screens:
(i) If the
line-to-neutral connected load on the feeder or line section is greater than 33
percent of peak load on the feeder or line-section, the project passes the
screen.
(ii) If using a
supplemental grounding software tool:
(I) If
the tool determines that supplemental grounding is not required to maintain
effective grounding, the project passes this screen.
(II) If the tool determines that supplemental
grounding is required, the applicant must agree to modify the project to
include supplemental grounding. If the applicant does not agree to modify the
project, the project fails this screen.
(H) If using detailed hosting capacity
analysis that incorporates evaluation of temporary overvoltage risk for
inverters, the project passes the screen if the nameplate rating of the project
is below the available hosting capacity at the Point of
Interconnection.
(c)
Safety and Reliability Screen. The location of the proposed small generator
facility and the aggregate export capacity on the line section do not create
impacts to safety or reliability that cannot be adequately addressed without
application of the study process. If the project limits export pursuant to OAR
860-082-0033, the export capacity must be included in any analysis, including
power flow simulations, except when assessing fault current contribution. To
assess fault current contribution, the analysis must use the rated fault
current; for example, the applicant may provide manufacturer test data
(pursuant to the fault current test described in IEEE 1547.1-2020 clause 5.18)
showing that the fault current is independent of the nameplate rating. The
interconnecting public utility may consider the following factors and others in
determining potential impacts to safety and reliability in applying this
screen:
(A) Whether the line section has
significant minimum loading levels dominated by a small number of customers
(i.e., several large commercial customers).
(B) Whether the loading along the line
section is uniform or even.
(C)
Whether the project is located in close proximity to the substation (i.e., less
than 2.5 electrical circuit miles), and whether the line section from the
substation to the Point of Interconnection is a Mainline rated for normal and
emergency ampacity.
(D) Whether the
project incorporates an adjustable 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.
(E) Whether operational flexibility is
reduced by the project, such that transfer of the line section(s) of the
Project to a neighboring distribution circuit/substation may trigger overloads
or voltage issues.
(F) Whether the
project 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.
(3) If the proposed
interconnection passes the supplemental screens, the Application must be
approved, and the public utility will provide the applicant an executed
Interconnection Agreement pursuant to the procedure set forth in OAR
860-082-0025(7)(e).
(4) After
receiving an Interconnection Agreement executed by the public utility, the
applicant must proceed under the terms of the applicable level of review under
which the Application was initially studied.
(5) Applicants undergoing Supplemental Review
will be able to access, review, and verify minimum load calculations except in
cases where the minimum load data contain identifiable individual customer
data.
