Iowa Admin. Code r. 199-45.9 - Level 2 expedited review
A utility shall use the Level 2 review procedure for interconnection requests that meet the Level 2 criteria in subrule 45.7(2). A utility may not impose additional requirements for Level 2 reviews that are not specifically authorized under this rule or rule 199-45.3 (476) or subrule 45.5(9) unless the applicant agrees.
(1) The utility shall evaluate the potential
for adverse system impacts using the following screens, which shall be
satisfied:
a. For interconnection of a
proposed distributed generation facility to a radial distribution circuit, the
total distributed generation connected to the distribution circuit, including
the proposed distributed generation facility, may not exceed 15 percent of the
maximum normal load normally supplied by the distribution circuit.
b. For interconnection of a proposed
distributed generation facility within a spot network, the proposed distributed
generation facility must be inverter-based and use a minimum import relay or
other protective scheme that will ensure that power imported from the utility
to the network will, during normal utility operations, remain above 1 percent
of the network's maximum load over the past year, or will remain above a point
reasonably set by the utility in good faith. At the utility's discretion, the
requirement for minimum import relays or other protective schemes may be waived
and alternative screening criteria may be applied.
c. The proposed distributed generation
facility, in aggregation with other generation on the distribution circuit, may
not contribute more than 10 percent to the distribution circuit's maximum fault
current at the point on the primary line nearest the point of
interconnection.
d. Any proposed
distributed generation facility, in aggregate with other generation on the
distribution circuit, shall not cause any electric utility distribution devices
to be exposed to fault currents exceeding 90 percent of their short-circuit
interrupting capability. Interconnection of a non-inverter-based distributed
generation facility may not occur under Level 2 if equipment on the utility's
distribution circuit is already exposed to fault currents of between 90 and 100
percent of the utility's equipment short-circuit interrupting capability.
However, if fault currents exceed 100 percent of the utility's equipment
short-circuit interrupting capability even without the distributed generation
being interconnected, the utility shall replace the equipment at its own
expense, and interconnection may proceed under Level 2.
e. When a customer-generator facility is to
be connected to 3-phase, 3-wire primary utility distribution lines, a 3-phase
or single-phase generator shall be connected phase-to-phase.
f. When a customer-generator facility is to
be connected to 3-phase, 4-wire primary utility distribution lines, a 3-phase
or single-phase generator shall be connected line-to-neutral and shall be
grounded.
g. When the proposed
distributed generation facility is to be interconnected on a single-phase
shared secondary line, the aggregate generation capacity on the shared
secondary line, including the proposed distributed generation facility, may not
exceed 20 kVA.
h. When a proposed
distributed generation facility is single-phase and is to be interconnected on
a center tap neutral of a 240-volt service, its addition may not create an
imbalance between the two sides of the 240-volt service of more than 20 percent
of the nameplate rating of the service transformer.
i. A distributed generation facility, in
aggregate with other generation interconnected to the distribution side of a
substation transformer feeding the circuit where the distributed generation
facility proposes to interconnect, may not exceed 10 MVA in an area where there
are transient stability limitations to generating units located in the general
electrical vicinity, as publicly posted by the Midwest Reliability Organization
(MRO), the SERC Reliability Corporation (SERC), the Midcontinent Independent
System Operator, Inc. (MISO) or the Southwest Power Pool (SPP).
j. Except as permitted by additional review
in subrule 45.9(6), the utility shall not be required to construct any
facilities on its own system to accommodate the distributed generation
facility's interconnection.
(2) The Level 2 interconnection shall use the
following procedures:
a. The applicant submits
an interconnection request using the Levels 2 to 4 Interconnection Request
Application form along with the Level 2 application fee.
b. Within ten business days after receiving
the interconnection request, the utility shall inform the applicant as to
whether the interconnection request is complete. If the request is incomplete,
the utility shall specify what materials are missing and the applicant has ten
business days to provide the missing information or the interconnection request
shall be deemed withdrawn.
c. After
an interconnection request is deemed complete, the utility shall assign a
review order position based upon the date that the interconnection request is
determined to be complete. The utility shall then inform the applicant of its
review order position.
d. If, after
determining that the interconnection request is complete, the utility
determines that it needs additional information to evaluate the distributed
generation facility's adverse system impact, it shall request this information.
The utility may not restart the review process or alter the applicant's review
order position because it requires the additional information. The utility can
extend the time to finish its evaluation only to the extent of the delay
required for receipt of the additional information. If the additional
information is not provided by the applicant within 15 business days, the
interconnection request shall be deemed withdrawn.
e. Within 20 business days after the utility
notifies the applicant it has received a completed interconnection request, the
utility shall:
(1) Evaluate the
interconnection request using the Level 2 screening criteria; and
(2) Provide the applicant with the utility's
evaluation, including a written technical explanation. If a utility does not
have a record of receipt of the interconnection request and the applicant can
demonstrate that the original interconnection request was delivered, the
utility shall complete the evaluation of the interconnection request within 20
business days after applicant's demonstration.
(3) When a utility determines that the
interconnection request passes the Level 2 screening criteria, or the utility
determines that the distributed generation facility can be interconnected
safely and will not cause adverse system impacts, even if the facility fails
one or more of the Level 2 screening criteria, the utility shall provide the
applicant with the Levels 2 to 4 Distributed Generation Interconnection
Agreement within three business days of the date the utility makes its
determination.
(4) Within 30
business days after issuance by the utility of the Levels 2 to 4 Distributed
Generation Interconnection Agreement, the applicant shall sign and return the
agreement to the utility. If the applicant does not sign and return the
agreement within 30 business days, the interconnection request shall be deemed
withdrawn unless the applicant requests a 15-business-day extension in writing
before the end of the 30-day period. The initial request for extension may not
be denied by the utility. When the utility conducts an additional review under
the provisions of subrule 45.9(6), the interconnection of the distributed
generation facility shall proceed according to milestones agreed to by the
parties in the Levels 2 to 4 Distributed Generation Interconnection
Agreement.
(5) The Levels 2 to 4
Distributed Generation Interconnection Agreement is not final until:
a. All requirements in the agreement are
satisfied;
b. The distributed
generation facility is approved by the electric code officials with
jurisdiction over the interconnection;
c. The applicant provides the Certificate of
Completion form to the utility. Completion of local inspections may be
designated on inspection forms used by local inspecting authorities;
and
d. The witness test has either
been successfully completed or waived by the utility in accordance with Article
2.1.1 of the Levels 2 to 4 Distributed Generation Interconnection
Agreement.
(6)
Supplemental review may be appropriate when a distributed generation facility
fails to meet one or more of the Level 2 screens. The utility shall offer to
perform a supplemental review to determine whether there are minor
modifications to the distributed generation facility or electric distribution
system that would enable the interconnection to be made safely without causing
adverse system impacts. To accept the offer of a supplemental review, the
applicant shall agree in writing and submit a deposit for the estimated costs
of the supplemental review in the amount of the utility's good-faith nonbinding
estimate of the costs for such review, both within 15 business days of the
offer. If the written agreement and deposit have not been received by the
utility within that time frame, the interconnection request shall continue to
be evaluated under the applicable study process unless it is withdrawn by the
applicant.
a. The applicant may specify the
order in which the utility will complete the screens described in paragraph
45.9(6) "d."
b.
The applicant shall be responsible for the utility's actual costs for
conducting the supplemental review. The applicant must pay any review costs
that exceed the deposit within 20 business days of receipt of the invoice or
resolution of any dispute. If the deposit exceeds the invoiced costs, the
utility will return such excess within 20 business days of the date of the
invoice without interest.
c. Within
30 business days following receipt of the deposit for a supplemental review,
the utility shall:
(1) Perform a supplemental
review using the screens set forth below;
(2) Notify the applicant in writing of the
results; and
(3) Include with the
notification copies of the analysis and data underlying the utility's
determinations based on the screens.
d. Unless the applicant provided instructions
on how to respond to the failure of any of the supplemental review screens
identified below at the time the applicant accepted the offer of a supplemental
review, the utility shall notify the applicant following the failure of any of
the screens; or if the utility is unable to perform the screen described in
subparagraph 45.9(6)"d"(1) within 2 business days of making
such determination, the utility shall obtain the applicant's permission to:
(a) continue evaluating the proposed
interconnection under this subparagraph;
(b) terminate the supplemental review and
continue evaluating the small generating facility; or
(c) terminate the supplemental review upon
withdrawal of the interconnection request by the applicant.
(1) Minimum Load Screen: Where 12 months of
line section minimum load data (including onsite load but not station service
load served by the proposed small 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 capacity on the line
section must be less than 100 percent of the minimum load for all line sections
bounded by automatic sectionalizing devices upstream of the proposed small
generating facility. If minimum load data is not available, or cannot be
calculated, estimated or determined, the utility shall include the reason(s)
that it is unable to calculate, estimate or determine minimum load in its
supplemental review results notification under paragraph
45.9(6)"c" above.
1. The type
of generation used by the proposed small generating facility will be taken into
account when calculating, estimating, or determining circuit or line section
minimum load relevant for the application of screen. Solar photovoltaic (PV)
generation systems with no battery storage use daytime minimum load (i.e., 10
a.m. to 4 p.m. for fixed panel systems and 8 a.m. to 6 p.m. for PV systems
utilizing tracking systems), while all other types of generation use absolute
minimum load.
2. When this screen
is being applied to a small generating facility that serves some station
service load, only the net injection into the utility's electric system will be
considered as part of the aggregate generation.
3. Utility will not consider generating
facility capacity known to be already reflected in the minimum load data as
part of the aggregate generation for purposes of this screen.
(2) Voltage and Power Quality
Screen: In aggregate with existing generation on the line section:
(1) the voltage regulation on the line
section can be maintained in compliance with relevant requirements under all
system conditions;
(2) the voltage
fluctuation is within acceptable limits as defined by the Institute of
Electrical and Electronics Engineers (IEEE) Standard 1453, or utility practice
similar to IEEE Standard 1453; and
(3) the harmonic levels meet IEEE Standard
519 limits.
(3) Safety
and Reliability Screen: The location of the proposed small generating facility
and the aggregate generation capacity on the line section do not create impacts
to safety or reliability that cannot be adequately addressed without
application of the study process. The utility shall give due consideration to
the following and other factors in determining potential impacts to safety and
reliability in applying this screen.
1.
Whether the line section has significant minimum load levels dominated by a
small number of customers (e.g., several large commercial customers).
2. Whether the load along the line section is
uniform or even.
3. Whether the
proposed small generating facility 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.
4. Whether the proposed small 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.
5.
Whether operational flexibility is reduced by the proposed small generating
facility, such that transfer of the line section(s) of the small generating
facility to a neighboring distribution circuit/substation may trigger overloads
or voltage issues.
6. Whether the
proposed small 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.
e. If the
proposed interconnection passes the supplemental screens described in
subparagraphs 45.9(6)"d"(1), (2), and (3), the interconnection
request shall be approved and the utility will provide the applicant with an
executable interconnection agreement within the time frames established in
paragraphs 45.9(6)"f" and "g." If the
proposed interconnection fails any of the supplemental review screens and the
applicant does not withdraw its interconnection request, it shall continue to
be evaluated under the Level 4 study process consistent with rule
199-45.11(476).
f. If the proposed
interconnection passes the supplemental screens described in subparagraphs
45.9(6)"d"(1), (2), and (3) and does not require construction
of facilities by the utility on its own system, the interconnection agreement
shall be provided within 10 business days after the notification of the
supplemental review results.
g. If
interconnection facilities or minor modifications to the utility's system are
required for the proposed interconnection to pass the supplemental screens
described in subparagraphs 45.9(6)"d"(1), (2), and (3) and the
applicant agrees to pay for the modifications to the utility's electric system,
the interconnection agreement, along with a nonbinding good-faith estimate for
the interconnection facilities or minor modifications or both, shall be
provided to the applicant within 15 business days after receiving written
notification of the supplemental review results.
h. If the proposed interconnection would
require more than interconnection facilities or minor modifications to the
utility's system to pass the supplemental screens described in subparagraphs
45.9(6)"d"(1), (2), and (3), the utility shall notify the
applicant at the same time it notifies the applicant with the supplemental
review results, that the interconnection request shall be evaluated under the
Level 4 study process unless the applicant withdraws its small generating
facility.
(7) If the
distributed generation facility is not approved under a Level 2 review, the
utility shall provide the applicant with written notification explaining its
reasons for denying the interconnection request. The applicant may submit a new
interconnection request for consideration under a Level 4 interconnection
review. The review order position assigned to the Level 2 interconnection
request shall be retained, provided that the request is made by the applicant
within 15 business days after notification that the current interconnection
request is denied.
Notes
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