customer guide for the interconnection of distributed

customer guide for the interconnection of distributed
CUSTOMER GUIDE
FOR THE
INTERCONNECTION
OF
DISTRIBUTED RESOURCES
TO THE
AMERICAN ELECTRIC POWER
DISTRIBUTION SYSTEM
, | 3 OHIO
A unit of American Electric Power
September 11, 2014
Table of Contents
Introduction
Applicability
Definitions
Overview of the Interconnection Process
Technical Requirements for Interconnection
Evaluation of System Impact
Appendix 1 - Technical Requirements
Appendix 2 — Potential System Impacts
Appendix 3 — AEP Guide for Testing and
Reporting per IEEE 1547.1
Minimum Requirements for Interconnection
Interconnection Agreement (sample)
Application for Interconnection (Standard < 20 MW)
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Introduction
This Customer Guide to the Interconnection of Distributed Resources to the American
Electric Power (AEP) Distribution System
o Explains the basic process used to interconnect Distributed Resources.
o Provides information on the technical requirements for Distributed Resources and
the potential system impact a Distributed Resource may have when
interconnecting to the AEP Distribution System.
Company approval of connecting a generator to its distribution system is required. The
information in this document will guide a customer on the requirements and process to
safely interconnect it to the AEP Distribution System. AEP Ohio’s Minimum
Requirements for Distribution System Interconnection begin on page 18 and are based on
Chapter 4901:1-22 Interconnection Services in the Ohio Administrative Code (OAC),
which governs the requirements for the investor-owned electric utilities in Ohio. The
Technical Requirements for Interconnection, which begins on page 7, provides additional
details.
The electric power distribution systems operating today were not designed to
accommodate the interconnection of Distributed Resources. The voltage regulation
practices, overcurrent protection approaches, switching techniques and maintenance and
power restoration practices used for distribution systems have been based on the
fundamental assumption that there are no generation sources on the distribution system.
Generation sources on the distribution system can create operating conditions that cannot
be managed in conventional ways and may require special equipment, changes to the
protection and control provisions, and other system modifications to operate safely and
effectively without adversely affecting system performance.
The Distributed Resources Interconnection Process is intended to efficiently:
1) determine if the proposed Distributed Resource is compatible with the electric power
system at the proposed interconnection point, and
2) identify and make any additions or modifications to the electric power system or
modifications to the proposed Distributed Resource installation necessary for
compatibility.
Applicability
This document provides guidance on the interconnection of Distributed Resources to the
AEP Distribution System. Distributed Resources includes both generators and energy
storage technologies.
For further information on the specific rules and tariffs covering the use of Distributed
Resources or other generators please contact:
AEP Ohio
Attn: DG Coordinator
850 Tech Center Drive
Gahanna, Ohio 43230
Phone: 614-883-6775
E-mail: decoordinator-ohio Q aep.com
A generator used in an automatic or manual transfer scheme in which electrical load is
transferred between the AEP Distribution System and the generator, but never paralleled
with the AEP Distribution System is not considered to be a Distributed Resource. Such a
generator should have an approved double-throw double-pole transfer switch installed by
a qualified electrician so that the generator and AEP’s service conductors cannot be
paralleled.
A generator using a make-before-break transfer scheme where the generator is paralleled
less than 100 milliseconds with the AEP Distribution System does not fall under the
interconnection rules for Distributed Resources. However, proposed make-before-break
transfer scheme generator equipment packages must be reviewed and approved by AEP.
The package must meet the requirements of Underwriters Laboratories Standard 1003
and be listed by a nationally recognized testing laboratory."
This guide covers the issues directly relating to the interconnection of a Distributed
Resource. It does not cover other issues a customer will need to consider when planning
to install a Distributed Resource, such as the terms and conditions relating to any
purchase or sale of electric energy, environmental permitting, local ordinances, and fuel
supply. Arrangements for purchase or sale of electric energy are handled separately from
interconnection. The interconnection process only provides for the safe interconnection
of the proposed Distributed Resource without degradation in the power quality or
reliability of the AEP Distribution System. Interconnection with the AEP Distribution
System does not provide an Interconnection Customer any rights to utilize AEP's
Distribution System for the transmission, distribution or wheeling of electric power, nor
does it limit those rights.
This guide does not cover self-protection of the Distributed Resource or all operating
requirements for the Distributed Resource. AEP’s review and authorization for parallel
operation shall not be construed as confirming or endorsing the Interconnection
Customer's design or as warranting the Distributed Resource and interconnection
systems’ safety, durability or reliability. AEP shall not, by reason of such review or lack
of review, be responsible for the strength, adequacy or capacity of such equipment.
' UL publications are available from Underwriters Laboratories, Inc. (http:/www.ul.com/)
2
Definitions
AEP Distribution System — Facilities owned, leased or controlled by AEP that deliver
electric power at primary voltages ranging from 4 to 34.5 kV three phase and at
secondary voltages ranging from 120/240 volts single phase to 277/480 volts three phase
to retail and wholesale customers.
Distributed Resources — Sources of electric power including both generators and energy
storage technologies operated in parallel with the power system and not directly
connected to a bulk power transmission system.
Distributed Generation — Electric power generators operated in parallel with the power
system and not directly connected to a bulk power transmission system. Distributed
Generation 1s a subset of Distributed Resources.
Interconnection — The result of adding a Distributed Resource to the AEP Distribution or
Transmission System so the Distributed Resource can operate in parallel.
Interconnection Agreement — An agreement between AEP and the owner of a Distributed
Resource covering the terms and conditions under which the owner’s Distributed
Resource can be installed and operated in parallel with the AEP System.
Point of Common Coupling — The point at which the distributed generation facility is
connected to the shared portion of the utility system or where an electrical system
connects to the AEP System.
Pre-certified — A Distributed Resource equipment package, submitted by a manufacturer
or an entity that assembles an equipment package, tested as per IEEE 1547 Clause 5 by a
nationally recognized testing laboratory and found after testing to be in compliance with
the requirements of IEEE 1547 Clause 4.
Queue — The time ordered collection of pending valid interconnection requests
maintained to assure that interconnection requests are processed on a first-in first-out
basis.
Screening Criteria — A set of technical criterion used to evaluate Distributed Resource
interconnection requests in order to determine if a request can be approved for
interconnection with no further study or if the request requires more study to determine
its system impact.
System Impact — Negative effects due to technical or operational limits on conductors or
equipment being exceeded that may compromise the safety, reliability or power quality
of the electric system.
Technical Requirements — The specific criteria and specifications relevant to the
performance, operation, testing, safety considerations, and maintenance of the
interconnection of Distributed Resources with the AEP Distribution System. A
Distributed Resource may comply with all of the Technical Requirements and still have
significant System Impact.
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Overview of the Interconnection Process
AEP is committed to providing safe reliable service to our customers at the lowest
practical cost. This means that AEP will perform as efficiently as practical the work
necessary and appropriate to assure the continued safety of its employees and the public
and continued reliable electric service to our customers.
Improper connection and operation of any source of electrical power, such as a
Distributed Resource, in parallel with the AEP Distribution System could jeopardize the
safety of AEP employees and the public and could degrade the reliability and quality of
the electric service provided to our customers. Therefore, no source of electrical power
shall be operated in parallel with the AEP Distribution System without the express
written approval of AEP.
Customers may obtain AEP approval to operate a Distributed Resource in parallel with
its system by applying for interconnection and following the appropriate interconnection
process. The specific application form and interconnection process to be followed is
dictated by Chapter 4901:1-22 Interconnection Services of the Ohio Administrative Code
(OAC). AEP desires to minimize the time and expense involved with the interconnection
process consistent with maintenance of system safety and reliability, in addition to
compliance with the applicable regulatory requirements and customer satisfaction.
An overview of the general interconnection process is outlined below.
Step 1: The customer contacts AEP.
The customer contacts AEP by telephone, e-mail or U.S. mail. Based upon the
customer’s request and preliminary plans, AEP sends the customer the
interconnection application form and provides information on the required
interconnection process. The correct application form to use depends upon the
location, type, size and proposed use of the planned Distributed Resource.
Customers who plan to sell electricity produced by their planned electrical
generating facility at wholesale in interstate commerce may need to use an
application form approved for use as part of a Federal Energy Regulatory
Commission (FERC) approved Open Access Transmission Tariff. Customers
whose planned Distributed Resource does not fall under FERC jurisdiction must
use the application form provided, based upon the location, type, size and
proposed use of the Distributed Resource.
Step 2: Customer submits a completed application.
Any customer who proposes to operate any type of Distributed Resource in
parallel with the AEP Distribution System must first submit a completed
application to request review and approval of the proposed Distributed Resource
interconnection. For the application to be considered complete, the request must
be submitted on the proper application form and must include all information
requested and payment of monies due at the time of application.
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Step 3: AEP reviews the application form for completeness.
In order for AEP to process a customer request for Distributed Resource
interconnection, the submitted application form must be complete. Upon receipt
of an application form, AEP will review the application for completeness. If AEP
determines the application form is incorrect and/or is incomplete, AEP will notify
the customer and provide the correct form and/or a description of the information
needed to complete the application form. The interconnection request will be
placed in Queue based upon the date and time of receipt of the completed
application form.
Step 4: AEP performs a limited study to determine compliance with the Technical
Requirements and the potential system impact of the Distributed Resource.
Based upon an interconnection request’s position in the Queue and the applicable
time limits established by the OAC, AEP will perform a limited engineering study
to determine compliance with the Technical Requirements and to evaluate the
System Impact of the proposed Distributed Resource.
The study time limits and study scope vary depending upon the rules established
by the OAC and may vary by the type, size and proposed use of the Distributed
Resource. Specific screening criteria are utilized to minimize the time and
expense involved to evaluate pre-certified Distributed Resources. Additional time
is generally required to evaluate Distributed Resources that are not pre-certified to
determine if they meet the Technical Requirements.
Step 5: AEP informs the customer of the results of the limited study.
The results of the limited study are provided to the customer within the applicable
time limits established by the OAC.
AEP will first determine if the proposed Distributed Resource meets the
Technical Requirements. If it is determined that the proposed Distributed
Resource does not meet the Technical Requirements, AEP will notify the
customer and provide a list of specific changes necessary for the proposed
Distributed Resource to meet the Technical Requirements. If the customer
decides to make the necessary changes to comply with the Technical
Requirements, AEP will complete the limited study.
If the limited study shows that the proposed Distributed Resource meets the
Technical Requirements and that interconnection of the proposed Distributed
Resource will not cause System Impact, AEP will notify the customer of the study
results and provide the customer with a proposed interconnection agreement.
If the limited study shows that the proposed Distributed Resource meets the
Technical Requirements but that interconnection of the proposed Distributed
Resource will cause System Impact and it is determined that changes in the
customer’s proposed generating facilities or minor AEP system modifications can
be made to accommodate the proposed Distributed Resource, AEP will notify the
5
customer of these study results. If the customer then elects to make the necessary
changes and/or pay for minor AEP system modifications, AEP will provide the
customer with a proposed interconnection agreement.
If the limited study shows that the proposed Distributed Resource meets the
Technical Requirements and additional study is required to determine if
interconnection of the proposed Distributed Resource will cause System Impact,
AEP will provide the customer with the results of the limited study and provide an
estimate of the cost of the additional study required to determine the System
Impact of the proposed Distributed Resource. If the customer then elects to pay
for the additional study and subsequently agrees to pay for any necessary changes,
minor system modifications and/or system upgrades determined necessary by the
additional study, AEP will provide the customer with a proposed interconnection
agreement.
Step 6: The customer signs and returns the proposed interconnection agreement
and any necessary study and facility changes are completed.
The customer signs and returns the proposed interconnection agreement. Upon
receipt of the customer’s payment and completion of any necessary study, minor
system modifications and system upgrades by AEP and the completion of
customer facility changes necessary to accommodate the customer’s Distributed
Resource, the customer can proceed to complete their Distributed Resource
installation in preparation for final checkout and commissioning tests.
Step 7: The customer notifies AEP of final checkout schedule, performs the final
Checkout, successfully completes all commissioning tests and sets up
periodic interconnection test procedures.
The customer completes their Distributed Resource installation and notifies AEP
of their schedule for final checkout and the plan for commissioning tests. AEP
may inspect the customer’s Distributed Resource installation and observe the
customer performing the required commissioning tests. Upon successful
completion of the commissioning tests, the customer will give or send AEP a
copy of their final inspection checkout and the results of the commissioning tests
and the written periodic interconnection test procedures proposed by the
customer.
Step 8: AEP authorizes operation of the proposed Distributed Resource in parallel
with the AEP Distribution System.
Based upon its review of the customer’s proposed Distributed Resource facility,
the final inspection checkout and the results of the commissioning tests, AEP
notifies the customer in writing of its authorization for the customer to operate the
generating facility in parallel with the AEP Distribution system under the terms of
its interconnection agreement.
If AEP identifies problems with the inspection, if the commissioning test results
are unsatisfactory, or if AEP does not agree with the customer’s periodic test
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procedures, AEP will notify the customer in writing with the deficiencies clearly
identified. AEP may withhold authorization for parallel operation until such
deficiencies have been properly corrected.
For specific interconnection process requirements, please refer to the tariffs or
rules governing interconnection within a given jurisdiction (Federal or State)
based upon the location, type, size and intended use of the proposed Distributed
Resource.
Technical Requirements for Interconnection
IEEE Standard 1547 “Standard for Interconnecting Distributed Resources with Electric
Power Systems” (IEEE 1547)" is the basis for interconnection Technical Requirements
for most jurisdictions. These Technical Requirements apply to all Distributed Resource
technologies including synchronous machines, induction machines, or static power
inverters/converters.
The interconnection system hardware and software used by a Distributed Resource to
meet these Technical Requirements do not have to be located at the Point of Common
Coupling. However, the Technical Requirements shall be met at the Point of Common
Coupling.
A table summarizing the Distributed Resource Technical Requirements is attached as
Appendix 1. The pertinent IEEE 1547 clause number(s) are shown in this table.
Basic Technical Requirements - The Technical Requirements in IEEE 1547 cover the
following areas, Voltage Regulation, Voltage Disturbances, Harmonic Current Injection,
Direct Current Injection, Grounding Scheme Compatibility, Inadvertent Energizing,
Monitoring Operation, Isolation Device, Withstand Performance, Paralleling Device,
Response to Area EPS Faults, Reclosing Coordination, Unintentional Islanding, Voltage
and Frequency Detection, Abnormal Voltage or Frequency, Reconnection Following a
Disturbance, Secondary Grid and Spot Network Systems, and Testing and Maintenance.
Testing — A Distributed Resource proposing to interconnect with the AEP Distribution
System must be tested as per IEEE 1547 Clause 5 to demonstrate that the interconnection
system meets the requirements of IEEE 1547 Clause 4. Documentation of the results of
the Design Test and Production Tests shall be provided to AEP at the time of application
unless such tests are to be conducted as part of the Commissioning Tests.
When the interconnection system of the Distributed Resource uses an assembly of
discrete components, documentation of testing must be provided to AEP at the time of
application to confirm the compatibility of the discrete components to properly function
together. Otherwise AEP may require the Design Test to be conducted as part of the
Commissioning Tests.
* IEEE publications are available from the Institute of Electrical and Electronics Engineers, 443
Hoes Lane, P.O. Box 1331, Piscataway, NJ 08855-1331 (http://standards.ieee.org/).
7
Written test procedures shall be approved by AEP for all tests to be performed as
Commissioning Tests. To avoid delay, these test procedures should be submitted to AEP
well in advance of the scheduled date of the Commissioning Tests.
A suggested format for test proposal submission and test result reporting can be found in
Appendix 3 — AEP Guide for Testing and Reporting per IEEE 1547.1.
Additional Technical Requirements:
Circuit Breaker - If a main circuit breaker (or circuit switcher) between the
interconnection transformer and the Distribution System is required, the device must
comply with the applicable current ANSI Standard from the C37 series of standards that
specifies the requirements for circuit breakers, reclosers and interrupting switches.
Main Disconnect Switch (Voltages exceeding 480 volts) — A gang operated
disconnecting device must be located at the Point of Common Coupling for all three
phase interconnections. In all cases the disconnecting device must be clearly labeled,
accessible to AEP personnel, must be suitable for use by AEP personnel at all times and
must be suitable for use by AEP as a protective tagging location. The disconnecting
device shall have a visible open gap when in the open position and be capable of being
locked in the open position.
The disconnecting device must have a ground grid designed in accordance with
specifications to be provided by AEP. Operation of the device must be restricted to AEP
personnel and properly trained operators designated by the interconnection customer.
The disconnecting device must comply with the applicable current ANSI Standard from
the C37 series of standards that specifies the requirements for circuit breakers, reclosers
and interrupting switches.
Terminating Structure — When a new interconnection line is required, the interconnection
customer shall provide a suitable structure to terminate the interconnection line. The
customer is responsible for ensuring that terminating structure or substation structural
material strengths are adequate for all requirements, incorporating appropriate safety
factors. AEP will provide line tension information for maximum dead-end. The
structure must be designed for the maximum line tension along with an adequate margin
of safety.
Substation electrical clearances shall meet or exceed the requirements of the National
Electrical Safety Code. Installation of disconnect switches, bus support insulators and
other equipment shall comply with accepted industry practices.
Surge arresters shall be selected to coordinate with the BIL rating of major equipment
components and shall comply with recommendations set forth in the applicable current
ANSI Standard C62.2 that specifies the requirements for surge arresters and other surge
protection devices.
Momentary Paralleling — For situations where the proposed Distributed Resource will
only be operated in parallel with the AEP system for a short duration (less than 100
milliseconds), as in a make-before-break automatic transfer scheme, the requirements of
IEEE 1547 do not apply except as noted in Clause 4.1.4. All make-before-break
8
automatic transfer switch systems proposed by the interconnection customer must comply
with UL 1008 and be listed by a nationally recognized testing laboratory.
Voltage Unbalance — The interconnection customer 1s responsible for operating the
proposed Distributed Resource such that the voltage unbalance attributable to the
Distributed Resource does not exceed 2.5% at the Point of Common Coupling.
Power Factor - Each Distributed Resource shall be capable of operating at some point
within a power factor range from 0.9 leading to 0.9 lagging. Operation outside this range
1s acceptable provided the reactive power of the Distributed Resource is used to meet the
reactive power needs of the electrical loads within the interconnection customer’s facility
or that reactive power is otherwise provided under tariff by AEP. The interconnection
customer shall notify AEP if it is using the Distributed Resource for power factor
correction.
System Stability — AEP may require a stability study for Distributed Resources if the
aggregate generation is greater than 10 MW and in an area where there are known or
posted stability limitations to generation located in the general electrical vicinity (e.g.,
three or four Transmission voltage level busses from the Transmission voltage bus
serving the distribution circuit where the Distributed Resource proposes to interconnect.
Maintenance and Testing — The interconnection customer is responsible for the periodic
scheduled maintenance on the interconnection system of the Distributed Resource
(relays, interrupting devices, control schemes, and batteries that involve the protection of
the AEP system). Unless the equipment manufacturer provides study results that
demonstrate the need for less frequency, interconnection systems that depend upon a
battery for proper function shall be checked and logged once per month for proper
voltage. At least once every four years, the battery must be either replaced or a discharge
test performed.
A periodic maintenance program is to be established in accordance with the requirements
of IEEE 1547. AEP may examine copies of the periodic test reports or inspection logs
associated with the periodic maintenance program. Upon request, AEP shall be informed
of the next scheduled maintenance and be able to witness the maintenance performed and
any associated testing.
Monitoring — AEP reserves the right, at AEP’s initial expense, to install special test
equipment as may be required to perform a disturbance analysis and monitor the
operation and control of the Distributed Resource to evaluate the quality of power
produced by the Distributed Resource.
Evaluation of System Impact
A Distributed Resource proposing to interconnect to the AEP Distribution System may
have significant impact on the safety and reliability of one or more of the following
portions of the electrical power system; the AEP Distribution System, the AEP
Transmission System, the Distribution or Transmission System of a third party (called an
Affected System) and the electrical system where the Distributed Resource is to be
connected. AEP shall not be responsible for the evaluation of the safety and reliability
9
impacts on the electrical system where the Distributed Resource is to be connected. AEP
approval of a Distributed Resource interconnection should not be construed as an
endorsement, confirmation, warranty, guarantee, or representation concerning the safety,
operating characteristics, durability, or reliability of the Distributed Resource facility and
the electrical system where it is connected.
Distribution System Impact —
AEP Distribution 1s responsible for evaluating the system impact of a proposed
Distributed Resource interconnection based upon the information provided in the
interconnection application once the application is considered complete.
A study to determine system impact will be performed based upon the interconnection
request’s position in the Queue and the applicable time limits established by the
regulatory authority having jurisdiction. The study time limits and study scope vary
depending upon the regulatory authority and the type, size and proposed use of the
Distributed Resource.
AEP supports limited study and the use of a screening process to expeditiously identify
and approve Distributed Resources that can be interconnected without significant system
impact. AEP screening criteria is based on the OAC.
Additional study time 1s generally required to evaluate Distributed Resources that are not
pre-certified. The exception may be for Distributed Resources that have been evaluated
previously by AEP and were found to meet the Technical Requirements including the
necessary testing.
The possible outcomes of the system impact study could include the following:
1) The proposed Distributed Resource interconnection meets the Technical Requirements
and there are no system impacts that would require modification or upgrade to either AEP
facilities or the Distributed Resource installation;
2) The proposed Distributed Resource interconnection does not meet the Technical
Requirements and modifications or changes are required to either AEP facilities or the
Distributed Resource installation;
3) The proposed Distributed Resource interconnection would result in negative system
impact and modifications or changes are required to either AEP facilities or the
Distributed Resource installation;
4) The proposed Distributed Resource interconnection requires new AEP facilities.
The potential Distribution system impacts listed in Appendix 2 may need to be examined
as part of the impact study.
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Transmission System Impact —
The AEP Transmission organization is informed of requests for interconnection to the
AEP Distribution System. The Transmission organization reviews a request and
determines if there may be a Transmission System impact (including any system stability
impact) or an impact to a third party’s system.
If the request needs to be studied to determine if there is significant Transmission System
impact, the Transmission organization will notify the Distribution organization
accordingly. The Distribution organization will coordinate the processing of the
interconnection request to help assure that the proper process is followed and all required
milestones are met.
Affected System Impact —
The Distribution organization will review each request for interconnection to the AEP
Distribution System to determine if the potential exists for impact to a third party’s
system. For example, the distribution systems of several Rural Electric Cooperatives
(REC's) are interconnected to AEP Distribution feeders. The interconnection of a
Distributed Resource to an AEP Distribution feeder with an REC interconnection could
result in significant impact to the REC system.
If the potential exists for impact, the AEP Distribution organization will notify the third
party of the proposed interconnection request and coordinate the processing of the
interconnection request to help assure that the proper process is followed and all required
milestones are met.
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Appendix 1
Distributed Resource Technical Requirements
Attribute
Requirement
Voltage Regulation
IEEE 1547 - Clause 4.1.1
Voltage Disturbances
IEEE 1547 - Clause 4.3.2
Harmonic Current Injection
IEEE 1547 - Clause 4.3.3
Direct Current Injection
IEEE 1547 - Clause 4.3.1
Grounding Scheme
Compatibility
IEEE 1547 - Clause 4.1.2
Inadvertent Energization
IEEE 1547 - Clause 4.1.5
Monitoring Provisions
IEEE 1547 - Clause 4.1.6
Isolation Device
IEEE 1547 - Clause 4.1.7
Withstand Performance
IEEE 1547 - Clause 4.1.8.1 and Clause 4.1.8.2
Paralleling Device
IEEE 1547 - Clause 4.1.8.3
Response to Area EPS Faults
IEEE 1547 - Clause 4.2.1
Reclosing Coordination
IEEE 1547 - Clause 4.2.2
Unintentional Islanding
IEEE 1547 - Clause 4.4.1
Abnormal Voltage
IEEE 1547 - Clause 4.2.3
Abnormal Frequency
IEEE 1547 - Clause 4.2.4
Reconnection Following a
Disturbance
IEEE 1547 - Clause 4.2.6
Secondary Grid and Spot IEEE 1547 - Clause 4.1.4
Network Systems
Testing IEEE 1547 - Clause 5
Periodic Interconnection Tests | IEEE 1547 - Clause 5.5
Circuit Breaker Meet appropriate ANSI C37 standard
Disconnect Switch
Three phase unit gang operated at Point of Common
Coupling
Terminating Structure
Adequate structural material strength suitable to
terminate line
Surge Arresters
Meet applicable ANSI C62.2 standard
Momentary Paralleling
Comply with Underwriter’s Laboratories Standard
1008 and IEEE 1547 — Clause 1.3
Voltage Unbalance
Unbalance attributable to Distributed Resource 2.5% or
less
System Stability
Study required for units greater than 10 MW when
limitations exist
12
Appendix 2
Potential Distribution System Impacts
Voltage Regulation - With the addition of the Distributed Resource, the voltage level on
both the primary and secondary must be maintained within acceptable limits for both on
peak and off peak conditions.
1) Reverse power flow through voltage regulators or load tap changers may cause
the regulator or load tap changer to incorrectly regulate the voltage.
2) Improper settings of the Distributed Resource controls may result in the steady
state voltage straying outside the + or - 5% limits at the point of common
coupling on a 120 volt basis.
3) Low voltage may be experienced after a temporary fault or when restoring
service after a permanent fault if the presence of the Distributed Resource 1s
essential to the maintenance of adequate voltage.
4) The loss of Distributed Resource synchronous machine exciters may cause
excessive reactive power losses and low voltages on a circuit.
5) The presence of Distributed Resources with varying output (e.g. wind turbines,
photovoltaic cells, etc.) may cause excessive switching of capacitor banks and/or
an excessive number of regulator or load tap changer operations.
6) When line drop compensators are used on a circuit, the presence of Distributed
Resources may significantly alter the intended regulation scheme.
7) The presence of Distributed Resources on a secondary system may cause the
off peak voltage level to exceed its upper limit.
8) The Distributed Resource owner could experience periods when his unit(s)
trips off line from overvoltage due to system voltage excursions.
Voltage Flicker - Several Distributed Resource technologies have the potential for
creating objectionable voltage flicker. In extreme cases the size of the Distributed
Resource may need to be limited to prevent objectionable flicker or system improvements
may be necessary to limit the voltage flicker. Possible flicker sources include:
1) Wind turbines may produce rapidly varying output due to changes in wind
speed, wind turbulence, intensity, tower shadowing effects and blade pitching.
2) Photovoltaic (PV) installations may produce rapidly varying output due to
intermittent cloud cover over the cells.
13
Appendix 2
3) Reciprocating engine Distributed Resources may be produce rapid output
fluctuations caused by engine misfiring due to low quality fuel.
4) Induction machine Distributed Resources may produce voltage flicker due to
current inrush when they are connected.
5) Synchronous machine Distributed Resources may produce voltage flicker due
to poor voltage matching and phase angle synchronization at contact closure.
6) Power inverter based Distributed Resources may not have soft start technology
to limit the rate of change of power output at starting.
7) Interaction of Distributed Resources with other devices such as voltage
regulators, load tap changers and switched capacitor banks may produce
objectionable voltage flicker.
Overcurrent Protection and Protective Device Coordination - With the addition of a
Distributed Resource on a circuit, another source of fault current is introduced. The
available fault current at any location on the feeder will depend upon the type of fault
(e.g. line-to-ground, three phase, double-line-to-ground, etc.), the fault impedance, and
the status of the Distributed Resource on the feeder (i.e. on or off line). Each Distributed
Resource technology has its own unique fault current characteristics.
The presence of Distributed Resources may create several problems with overcurrent
protection and the coordination of protective devices. Some of the problems include:
1) The “reach” of overcurrent protective devices may be reduced due to a
reduction in the fault current contribution from the station source with Distributed
Resources on a feeder. For faults located downstream from a Distributed
Resource, the fault current contribution from the station source will be reduced
when the Distributed Resource unit is on line.
2) Recloser to fuse coordination may no longer exist with the introduction of a
Distributed Resource on the feeder so fuses may blow for temporary faults.
3) Sectionalizers may misoperate if the Distributed Resource maintains voltage
when the sectionalizer should be "counting" an operation.
4) Nuisance tripping of a circuit recloser or station breaker may occur from a fault
located on an adjacent feeder due to the fault current contribution from the
Distributed Resource.
5) The presence of an interconnection transformer with a primary voltage wye
grounded winding connection and a secondary voltage delta connection at the
Distributed Resource can desensitize ground fault relays and the ground fault
settings on recloser controls.
14
Appendix 2
6) The introduction of Distributed Resource to a secondary spot or grid network
system can cause nuisance trips of protectors and protector cycling and may lead
to out of phase protector closing resulting in equipment damage.
7) The presence of a Distributed Resource may exacerbate cold load pickup
problems following a feeder outage.
8) The addition of a Distributed Resource may increase the available fault current
to the point where utility system or customer owned protective device fault
interrupting ratings are exceeded.
9) If the Distributed Resource remains on the feeder after a protective device
opens for any reason, then the protective device may reclose with the system
voltage and the Distributed Resource voltage out of synchronism.
10) Distribution automation schemes may be adversely affected by the
introduction of Distributed Resources.
11) System under frequency conditions may result in feeder or transformer
overload conditions.
Harmonic Current Injection - Several Distributed Resource technologies have the
potential for introducing harmonic distortion. Possible harmonic issues include:
1) Rotating machines produce 3rd harmonic distortion. Machines having a pitch
of either 5/6 and 11/16 introduce the most distortion with 2/3 pitch being the
preferred pitch to minimize distortion.
2) Inverter based Distributed Resources may inject harmonic voltages and
currents into the utility grid or may serve as a system sink for harmonics.
3) Wye-wye transformer connected Distributed Resources and single phase
Distributed Resources have the potential for being the worst harmonic sources.
Other Issues - Several other issues relating to the interconnection of Distributed
Resources need to be considered. Potential problems to look for include:
1) Voltage on unfaulted phases may approach 1.73 times nominal during single
line to ground faults when delta-wye or delta-delta connected transformer banks
are used for the Distributed Resource transformation.
2) Resonant overvoltages can occur if a synchronous or induction generator
Distributed Resource is isolated with capacitors during line to ground faults.
3) Single phase switching of a delta connected Distributed Resource transformer
bank may create ferroresonant overvoltage conditions.
15
Appendix 2
4) Distributed Resources may present utility worker and public safety concerns by
inadvertently re-energizing the electric power system during abnormal system
conditions.
5) The addition of Distributed Resource may overload conductors or equipment.
6) The presence of a Distributed Resource may defeat attempts to clear fault
conditions by continuing to energize the feeder during fault events.
7) Induction and synchronous machine Distributed Resources may be over excited
by the presence of a capacitor bank in an unintentional islanding situation and
produce high voltages in the island.
8) Inverter based Distributed Resources may inject direct current onto the feeder
causing transformer saturation.
9) When a grounded-wye high-side/delta low-side connected transformer bank is
used to connect a Distributed Resource, circulating current in the delta winding
may result in transformer overloading. This transformer connection allows zero
sequence current to circulate in the delta winding.
10) When feeders are switched from their normal configuration to effect load
transfers or to restore power to customers during outage situations, the presence
of a Distributed Resource may create voltage regulation problems, objectionable
voltage flicker, improper protective device operation and coordination or other
problems.
16
Appendix 3
AEP Guide for Testing and Reporting per IEEE 1547.1
The purpose of this guide is to provide a suggested simplified format for test proposal
submission and test result reporting. It will provide direction for and set AEP
expectations of the generator/customer for the testing and reporting per IEEE 1547.1.
IEEE 1547.1 specifies the type, production, and commissioning tests that shall be
performed to demonstrate that the interconnection functions and equipment of the
distributed resources conform to IEEE standard 1547. AEP recognizes the detail of IEEE
1547.1 can be intimidating at first glance. Once the document structure is understood, the
generator/customer task becomes nothing more than a series of items for which to test
and report results or report manufacturer test results. This guide does not remove the
generator/customer’s responsibility for reading, understanding, and complying with all of
the IEEE 1547.1 contents, as well as any applicable local codes, standards, legislation, or
commission order.
When an AEP Distribution System Planner (DSP) performs an impact study in response
to an application for interconnection of generation equipment 20 megawatts or less
(standard form application) the generator/customer may need to test the interconnection
system (ICS) to assure IEEE 1547 compliance. It 1s the generator/customer’s
responsibility to clearly communicate its testing proposal and test result report to AEP.
The contents of this guide will help the generator/customer navigate IEEE 1547.1 when
ICS testing is necessary.
IEEE 1547.1 is organized into 8 distinct articles. While the entire document 1s important,
there are specific articles and sub-articles that warrant highlighting. They are:
1. Sub-article 4.3, Measurement accuracy and calibration of the testing equipment
a. When the generator/customer provides measurement equipment
calibration traceability, place this documentation at the front of the test
report.
2. Sub-article 4.4, Product information
a. This sub-article describes when special testing parameters or criteria are
to be noted in the test report.
3. Sub-article 4.5, Test reports
a. In the test report AEP expects to see a given section containing test
results titled with the IEEE 1547.1 sub-article number of the test. This
practice will keep the test report clear and unambiguous. For example:
i. An Over-voltage Magnitude Type test result would be titled with
5.2.1.2 Over-voltage Magnitude test results. (See example in
Appendix D)
17
Appendix 3
ii. An Over-voltage Timing Type test would be titled with 5.2.1.3
Overvoltage Timing test results. (See example in Appendix D)
iii. A Synchronization Production test result would be titled with
6.3 Synchronization test results. (follow same format as
Appendix D)
iv. A Revised settings Commissioning test result would be titled
with 7.6 Revised Settings test results. (follow same format as
Appendix D)
b. Unless the test purpose or procedure outlined in each sub-article 15
modified, the test report need only include test results including unit
measured. Test reports containing dimensionless results will be
returned as unacceptable. It will be understood that any and all test
related purpose, procedure, requirement, and criteria will be contained
within the identified IEEE 1547.1 sub-article and does not bear
repeating in the generator/customer submitted test report. (See example
in Appendix B)
4. Highlighting of IEEE 1547.1 articles 5, 6, and 7 responsibilities of the
generator owner/third party testing entity.
5. Article 5, Type tests
a. It is the responsibility of the generator/customer to determine if any of
the Type tests have been addressed by the manufacturer.
b. Type tests performed by the manufacturer shall be clearly identified by
indicating on the manufacturer literature which Type test is addressed
using the Type test number as described above. (See example in
Appendix C)
6. Article 6, Production tests
a. It is the responsibility of the generator/customer to determine if any of
the Production tests have been addressed by the manufacturer.
b. Production tests performed by the manufacturer shall be clearly
identified by indicating on the manufacturer literature which Production
test is addressed using the Production test number as described above.
(See example in Appendix C)
7. Article 7, Commissioning tests
a. Sub-article 7.1.2 indicates what test procedures must be submitted to
AEP for approval prior to testing
i. The submitted generator/customer test procedure can simply be a
list of the sub-article numbers of the Type, Production, and
18
Appendix 3
Commissioning tests that will be conducted by the
generator/customer. It will be understood that any and all test
related purpose, procedure, requirement, and criteria will be
contained within the identified IEEE 1547.1 sub-article and does
not bear repeating in the generator/customer submitted test
procedure. (See example in Appendix B)
b. Any Type or Production sub-article number test not appearing in the list
from item 7.a.1 of this document must appear as satisfied per item 5.b or
6.b. (See example in Appendix C)
8. Article 8, Periodic interconnection tests
a. The periodic test schedule shall be included in the test results report.
Appendices follow. Appendix A is a suggested cover sheet format for the customer’s
IEEE 1547.1 test results report package.
Appendix A
Testing Documentation
Document
Brand XYZ, Model 123 Converter Test (IEC XXXXX-XX)
Brand ABC, Model 456 Turbine Type Test — Design Evaluation
Brand ABC, Model 456 Turbine Type Test — Annex to Design
Brand XYZ, Model 123 Converter Test (UL XXXX)
Brand DEF Relay Manufacturer Specification
Brand DEF Relay Test Report
Brand ABC Turbine Technical Specifications
Previous Transformer Inrush Test Result
-Imla|molw> |
Brand GHI Breaker Specifications
Line Testing Notes
1 | All field tests shall be conducted per IEEE 1547.1 procedures in referenced section
General requirements contained in IEEE 1547.1, Section 4 apply to field tests
2
3 | Field tests conducted on complete commissioned facility to Area EPS
4 | All field test data recording and instrumentation shall be controlled by the testing
entity
5 | Facility technicians will operate facility for purpose of field tests
6 | More notes
7 | More notes
8 | More notes
9 | And more notes
10
11
12
19
Appendix 3
Appendix B
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20
Appendix 3
Appendix C
LAL LF LU ast unRpaiicy Cr ECHIJEI ALAS ESTA VO $
Type Tests
$, 2 —> Electromagnetic Compatibility Immunity
Conducted RP Immunity EC 60755-23-6 2001
Severity Level 10 Vrms
Digital Radio Telephone ENV 50204 1995
RE Immunity Severity Level 10 Vim at 500 MHz and
1 85 GHz
Flectrosaue Discharee 1EC 60255-22-2 1996
Immumly Seventy Level 2, 4,6, 8 AV contact
2,4, 8, 15 КУ ам
1ЕС 61000-4-2 1995
Severily Level 2, 4, 6, 8 hv contac,
2,4. 8, 15 Ку ан
fax Transient/Burst IEC 60255-22-4 1992
Immunity Severity Level 4 KV a12 5 kHz and
5 kHz
IEC 61000-4-4 1995
Severity Level 4 AV, 2 5 LH2 on poser
supply, 2 KY, 5 kHz on 1 O signal data,
and control lines
{EC 801-4 1988
Severity Level 4 (4 LV on power supply,
2kV on! O)
Power Supply Immunity — 1EC 60255-11 1979
Radiated Radio Frequency ENV 50140 1994
Immunily Severity Level 10 Ут
IEC 60255-22 3 1989
Severity Level 10 Vım
Exception 4322 Frequency sweep
approximated with 200 frequency steps
I octave
IEC 801-3 1984
Severity Level 10 Y т
Exceptions 9 1 Frequency sweep
approximated with 200 Frequency sieps
per octave
TEC 60255-22-5 2002
Sevesity Level 1 LV Line to Line,
2 KW Line to Earth
IEC 60255-22-1 1988
Severity Level 2 5 LV peak common
mode, | 0 AV peak differential mode
IEEE C37 90 1 1989
Seventy Level 30 kV oscillatory,
5 LV fast transicnt
Sunge Immunity
Surge Withstand
5.5.4 2: Capability Immunity
Instantaneous/Definite-Time Overcurrent Elements (50)
(Definite-Time Elements not in SEL-3514-1)
Current Pichup (A Secondary }
5 A Nomina! Phase 025 [00 00 A,0.01 À steps
Channels {phase & negative-sequence)
100 17000 A,0.01 À steps
(phase-to-phas)
0050-100 000 A, 0010 A steps (ressdual
ground)
| A Nominal Phase 005-2000 A,00! A steps
Channels (phase € negative-scquence)
G 20 34 00 A, 0 01 À sicps
{phase-to-phase)
0010-20 000 Л, 0.002 А steps
(residual ground)
5 A Noomind IN 0250 100 020 A, 0 001 A steps
Channel (neutral ground)
{ A Nomina IN 0050-20 000 А, 0.001 A steps
Channel (neviral ground)
02 A Nominal IN 0 005-2 500 A, 000-1 A steps
Channel (neutral ground)
21
inputs. 3100 Vdc an power supply Type
lested for | minure
Impulse JEC 60255-5 1977
Scverity Level 05 Joulc, SAV
Certifications
150 Relay is designed and manufactured to an 150-9001 certified
quality program
UL TSA UL hsted tv the requirements of 1// -S08, CS4 C21 7, N°13
Jor Industrial Control Equipment
CE CE Mark
Processing Specifications
AC Voltage and Current Inputs
16 samples per power system cycle, 3 dB low-pass filters cul-ofl
frequency of 560 Hz
Digital Filtering
One-cycle full cosine after low-pass anslog filtenny Net Miltenng
(analog plus digital) rejects de and af) harmonics greater than the
fundamental
Protection and Control Processing
Four times per power system cycle
Relay Element Pickup Ranges and Accuracies
Synchronism Check Elements (25) (Not in SEL-351A-1)
Shp Frequency
Pickup Range 0003-0 500 Hz, 0 001 Hz steps
Shp Frequency
Pickup Accuracy +0 003 Hz
Phase Angle Range 0-80, 1“ steps
Phase Angle Accuracy £4
Timing £1 50 cycles, 24% between? and 30
multiples of pickup
= 3.50 cycles, +4% benween 2 and 30
multiples of pickup
Under- (27)/0vervoitage (59) Elements
005 A IN Model
Pickup Ranges 0 90-300 00 Y, 0 01 Y steps
(most elements)
Steady-State
Pickup Accuracy +05 Ма 1% Го! 12 5 30000 V
Transient Overreach >
o. NX Under-/Overf Elements (B
nder-/Overfrequency Elements (81)
40 1 6500 Hz 001 Hz steps
200 16,000 00 cycles, 0 25-cycle steps
1025 cycle, £0 1%
Frequency
Time Delays
Tuner Accuracy
Steady-State plus
Transient Overshoot 1001 Hz
Undenoltage Frequency
Element Block Range 25 00 300 00 У
Appendix 3
Appendix D
IEEE 1547.1 Testing Results Summary
The tables below summarize the results obtained from testing. Nominal/Actual may be
rounded. Deviation is absolute.
5.2.1.2 Over-voltage Magnitude
A-Phase Over-Voltage Low Setting
Trial Nominal (V) Actual V Deviation (mV)
1 121 121.1 50
2 121 121.0 25
3 121 121.2 150
4 121 121.0 40
5 121 121.0 35
B-Phase Over-Voltage Low Setting
Trial Nominal (V) Actual V Deviation (mV)
1 121 121.1 50
2 121 121.1 50
3 121 121.0 25
4 121 121.0 -45
5 121 121.0 30
C-Phase Over-Voltage Low Setting
Trial Nominal (V) Actual V Deviation (mV)
1 121 121.0 5
2 121 121.0 15
3 121 121.0 -5
4 121 121.0 20
5 121 121.0 15
3-Phase Over-Voltage Low Setting
Trial Nominal (V) Actual V Deviation (mV)
1 121 121.1 70
2 121 121.0 25
3 121 121.1 90
4 121 121.0 40
5 121 121.0 35
5.2.1.2 Over-voltage Magnitude
A-Phase Over-Voltage Mid Setting
Trial Nominal (V) Actual V Deviation (mV)
1 138.5 138.6 55
2 138.5 138.5 15
3 138.5 138.5 10
4 138.5 138.5 30
5 138.5 138.5 45
22
Appendix 3
B-Phase Over-Voltage Mid Setting
Trial Nominal (V) Actual V Deviation (mV)
1 138.5 138.5 20
2 138.5 138.5 30
3 138.5 138.5 10
4 138.5 138.6 80
5 138.5 138.6 70
C-Phase Over-Voltage Mid Setting
Trial Nominal (V) Actual V Deviation (mV)
1 138.5 138.5 20
2 138.5 138.6 55
3 138.5 138.5 40
4 138.5 138.5 10
5 138.5 138.6 50
3-Phase Over-Voltage Mid Setting
Trial Nominal (V) Actual V Deviation (mV)
1 138.5 138.6 70
2 138.5 138.5 25
3 138.5 138.6 90
4 138.5 138.5 40
5 138.5 138.5 35
5.2.1.2 Over-voltage Magnitude
A-Phase Over-Voltage High Setting
Trial Nominal (V) Actual V Deviation (mV)
1 156 156.0 15
2 156 156.1 55
3 156 156.1 60
4 156 156.1 50
5 156 156.1 75
B-Phase Over-Voltage High Setting
Trial Nominal (V) Actual V Deviation (mV)
1 156 156.0 20
2 156 156.0 30
3 156 156.0 10
4 156 156.0 40
5 156 156.0 45
C-Phase Over-Voltage High Setting
Trial Nominal (V) Actual V Deviation (mV)
1 156 156.1 65
2 156 156.0 20
23
Appendix 3
3 156 156.0 40
4 156 156.0 10
5 156 156.0 30
3-Phase Over-Voltage High Setting
Trial Nominal (V) Actual V Deviation (mV)
1 156 156.1 80
2 156 156.1 75
3 156 156.1 60
4 156 156.1 90
5 156 156.1 55
5.2.1.3 Over-voltage Timing
Low Time Delay
Trial Nominal (ms) Actual (ms) Deviation (ms)
1 20 16.7 -3.3
2 20 18 -2.0
3 20 17 -3.0
4 20 16.8 -3.2
5 20 17.2 -2.8
Mid Time Delay
Trial Nominal (s) Actual (s) Deviation (ms)
1 1.52 1.525 4.8
2 1.52 1.525 4.6
3 1552 1.525 5.1
4 1.52 1.525 5.3
5 1.52 1.525 4.9
High Time Delay
Trial Nominal (s) Actual (s) Deviation (ms)
1 3.020 3.025 4.6
2 3.020 3.025 5.2
3 3.020 3.025 4.7
4 3.020 3.025 4.6
5 3.020 3.025 54
24
MINIMUM REQUIREMENTS FOR DISTRIBUTION SYSTEM INTERCONNECTION
Applicability
This schedule is applicable to any customer with cogeneration, small power production
facilities, and/or other on-site facilities producing electrical energy who wishes to operate
such facilities in parallel with the Company's distribution system at voltages up to 35 kV. This
schedule is not applicable to the interconnection and parallel operation of facilities which the
Federal Energy Regulatory Commission has determined to be subject to its jurisdiction. A
customer who has a facility that does not qualify for simplified interconnection pursuant to the
PUCO's distribution interconnection rules (O.A.C. § 4901:1-22) (Commission Rules) and the
Companys technical requirements for interconnection (Technical Requirements),
incorporated herein by reference, may negotiate a separate interconnection agreement with
the Company and the terms and conditions of this schedule shall apply to such customers to
the extent that the negotiated interconnection agreement does not conflict with this schedule.
Purpose
The purpose of this schedule is to implement Ohio Revised Code Section 4928.11, which
calls for uniform interconnection standards that are not unduly burdensome or expensive and
also ensure safety and reliability, to the extent governing authority is not preempted by
federal law. This schedule states the terms and conditions that govern the interconnection
and parallel operation of a customer's facility with the Company's distribution system.
Customer Request for Interconnection
Any customer seeking to physically connect facilities to the Company's distribution system,
which facilities may be used in parallel operation with the Company's distribution system,
shall file an interconnection application and sign an interconnection agreement with the
Company. For facilities for which the referenced Technical Requirements are applicable, the
customer and Company shall execute a simplified interconnection agreement. For all other
facilities, the customer and the Company shall execute an interconnection agreement which
may be different from the simplified agreement, but which shall conform with the provisions of
this schedule, to the extent applicable. Copies of all applicable forms and the Company's
Technical Requirements are available upon request.
To the extent possible, interconnection to the Company's distribution system shall take place
within the following time frames:
1. A customer can make an informal request to discuss a proposed interconnection at a
specific location and the qualifications under the Company's review procedures. In
addition, the customer may submit a formal request with a non-refundable processing
fee of $300 for a pre-application report containing the information specified in the
Commission Rules. The report will be provided to the customer within ten business
days of receipt of the written request and payment of the $300 processing fee.
2. Where no construction is required by the Company and the facility qualifies for
simplified interconnection pursuant to the review procedure contained in the
Commission Rules, interconnection shall be permitted within twenty business days of
the Company's receipt of a completed interconnection application in compliance with
the terms and conditions of this schedule. Prior to actual interconnection, the
customer must execute the interconnection agreement and receive a letter of
authorization from the Company to operate their facility.
3. Where construction or system upgrades of the Company's distribution system are
required, the Company shall provide the customer, in a timely fashion, an estimate of
the schedule and the customer's cost for the construction or upgrades. All
construction or distribution system upgrade costs shall be the responsibility of the
customer. All construction and system upgrade cost estimates and invoices shall be
itemized and clearly explained. If the customer desires to proceed with the
construction or upgrades, the customer and the Company shall enter into a contract.
25
MINIMUM REQUIREMENTS FOR DISTRIBUTION SYSTEM INTERCONNECTION
The contract shall contain a construction schedule listing target commencement and
completion dates, and an estimate of the customer's costs for construction or
upgrades. Assuming the customer is ready; the interconnection shall take place no
later than two weeks following the completion of such construction or upgrades,
provided the customer has signed the interconnection agreement and received a
letter of authorization from the Company to operate the facility. The Company shall
employ best reasonable efforts to complete such system construction or upgrades in
the shortest time reasonably practical.
4, All interconnection applications shall be processed by the Company in a
nondiscriminatory manner. The Company shall provide the customer a written notice
of the Company's receipt of the completed application via the U.S. Mail or Email
within ten business days after the application has been received by the Company's
personnel designated on the application form. The Company shall provide the
customer with a copy of the review procedure and a target date for processing the
application. If the application is viewed as incomplete, the Company will provide a
written notice within ten business days of receipt of the application by the Company's
personnel designated on the application form that the application is not complete
together with a description of the information needed to complete the application and
a statement that processing of the application cannot begin until the information is
received. Upon receiving any necessary application materials missing from the
original application, the Company will provide the customer with a second written or
email notice establishing a target date for processing the application. The Company's
target date shall permit interconnection in a timely manner pursuant to the
requirements of the Commission Rules. Interconnection applications will be
processed in the order that they are received. It is recognized that certain
interconnection applications may require minor modifications while they are being
reviewed by the Company. Such minor modifications to a pending application shall
not require that it be considered incomplete and treated as a new or separate
application. Minor modifications would not include at least the following: changes in
facility size or location; any change requiring a new impact study; or any other
substantive change.
5. If the Company determines that it cannot connect the customer's facility within the
time frames required by the Commission Rules, the Company will notify the customer
in writing of that fact within ten business days of receiving the completed application.
The notification will identify the reason or reasons the interconnection could not be
completed within the time frames stated, and provide an estimated date for
completion. This section shall not limit the rights of a customer for relief under Ohio
Revised Code Chapter 4905.
Technical Requirements
The Company shall maintain a copy of the Technical Requirements at its business office
such that the Technical Requirements are readily available to the public. The Company shall
provide the Commission Staff with a copy of the Technical Requirements. Standards adopted
by IEEE shall supersede the applicable provisions of the Company's Technical Requirements
effective the date that IEEE adopts such standards. However, any interconnection made or
initiated prior to the adoption of any national standard promulgated by IEEE shall not be
subject to that standard. Regarding any [EEE minimum standard, or any guideline that the
IEEE may promulgate, the Company may amend the Technical Requirements to the
minimum extent required to address unique local conditions, and shall provide such
amendments to the Staff and make such amendments available to customers. All Technical
Requirements, including superseding standards adopted by IEEE, are incorporated herein by
reference.
26
MINIMUM REQUIREMENTS FOR DISTRIBUTION SYSTEM INTERCONNECTION
Metering
Any metering installation, testing, or recalibration required by the installation of the
customer's generation facilities shall be provided consistent with the Electric Service and
Safety Standards pursuant to Ohio Revised Code Chapter 4928, and specifically O.A.C. §
4901:1-10-05 (Metering) and, as applicable, § 4901:1-10-28 (C) (Net Metering).
Liability Insurance
Prior to interconnection with the Company, the customer must provide the Company with
proof of insurance or other suitable financial instrument sufficient to meet its construction,
operating and liability responsibilities pursuant to this schedule. At no time shall the Company
require that the applicant negotiate any policy or renew any policy covering any liability
through a particular insurance company, agent, solicitor, or broker. The Company's receipt of
evidence of liability insurance does not imply an endorsement of the terms and conditions of
the coverage.
Feasibility, System Impact and Facilities Studies
For those facilities that do not qualify for simplified interconnection pursuant to the review
procedures included in the Commission Rules, the Company may require a supplemental
review, feasibility study, system impact study or facilities study prior to interconnection. In
instances where such studies are required, the scope of such studies shall be based on the
characteristics of the particular generation facility to be interconnected and the Company's
system at the specific proposed location. By agreement between the Company and the
customer, studies related to interconnection of the generation facility may be conducted by a
qualified third party. The cost of any study performed by the Company shall be included in the
costs set forth in the Interconnection Fees section of this schedule. The Company shall
provide the customer with a target date for completion of any required study. Any such study
conducted by the Company shall be shared with the customer.
Interconnection Fees
The Company shall not charge any fees for interconnection other than those authorized by
this schedule. Fees contained herein apply to each installation at the Company's distribution
voltages up to 35 kV.
The Company shall charge each customer that applies for interconnection service an
application fee as set forth in the Commission Rules. The fee for customer applications for
interconnection that meet the qualifications for level 1 simplified review procedures will be
$50.00. Customer applications for interconnection that meet the qualifications for level 2
expedited review will be subject to an application fee of $50.00, plus one dollar per kilowatt of
the applicant's system nameplate capacity rating. Interconnection customers whose facilities
qualify for level 3 standard review procedures shall pay an application fee of $100.00, plus
two dollars per kilowatt of the applicant's system nameplate capacity rating.
Level 2 and level 3 interconnection review processes may require that one or more
interconnection studies be performed to determine the feasibility, system impact, and cost of
safely connecting the customer's generation facilities to the Company's distribution system.
As specified in the Commission Rules, the cost of engineering work done as part of any
feasibility, system impact or facilities study shall be billed to the customer at the Company's
actual cost of performing such study.
During the Level 2 review the Company may offer to perform a supplemental review if the
Company concludes a supplemental review might determine the proposed generation facility
could continue to qualify for interconnection pursuant to the expedited review. If the
customer requests that the Company perform a supplemental review, the customer shall
agree in writing within fifteen business days of the offer and submit a $2,500 supplemental
review deposit that will be adjusted following completion of the study to reflect the cost of
engineering work at actual costs.
27
MINIMUM REQUIREMENTS FOR DISTRIBUTION SYSTEM INTERCONNECTION
Additional Fees
The customer is responsible for all equipment and installation costs of the customer's facility.
The customer shall pay any additional charges, as determined by the Company, for
equipment, labor, metering, testing or inspections requested by the customer.
Construction or Upgrade Fees
If the interconnection requires construction or an upgrade of the Company's system which,
save for the generation facility would not be required, the Company will assess the customer
the actual cost including applicable taxes of such construction or upgrade. Payment terms for
such construction or upgrade will be agreed to and specified in the construction contract. The
Company and the customer may negotiate for alternatives in order to reduce any costs or
taxes applicable thereto.
Resolution of Disputes
The Company or the customer who is a non-mercantile, non-residential customer may seek
resolution of any disputes which may arise out of this schedule, including the interconnection
and the referenced Technical Requirements in accordance with the Commission Rules.
Special Terms and Conditions of Service
This schedule is subject to the Company's Terms and Conditions of Service and all
provisions of the standard service schedule under which the customer takes service. |
applicable, the customer shall also take the appropriate service under the provisions of
Schedule COGEN/SPP, Schedule SBS and/or Schedule NEMS.
28
INTERCONNECTION AGREEMENT
This interconnection agreement (“Agreement”) is made and entered into this day of
, 20___, by and between Ohio Power Company (dba AEP Ohio)
(“Company”), and (“Customer”). Company
and Customer are hereinafter sometimes referred to individually as “Party” or collectively as
“Parties”.
WITNESSETH:
WHEREAS, Customer is installing, or has installed, generation equipment, controls, and
protective relays and equipment (“Generation Facilities”) used to interconnect and operate in
parallel with Company's electric system, which Generation Facilities are more fuily described in
Exhibit A, attached hereto and incorporated herein by this Agreement, and as follows:
Location:
Generator Size and Type:
NOW, THEREFORE, in consideration thereof, Customer and Company agree as follows:
1. Application. It is understood and agreed that this Agreement applies only to the
operation of the Generation Facilities described above and on Exhibit A.
2. Interconnection. Company agrees to allow Customer to interconnect and operate the
Generation Facilities in parallel with Company's electric system in accordance with any operating
procedures or other conditions specified in Exhibit B. By this Agreement, or by inspection, if any,
or by non-rejection, or by approval, or in any other way, Company does not give any warranty,
express or implied, as to the adequacy, safety, compliance with applicable codes or
requirements, or as to any other characteristics, of the Generation Facilities. The Generation
Facilities installed and operated by or for Customer shall comply with, and Customer represents
and warrants their compliance with: (a) the National Electrical Code and the National Electrical
Safety Code, as each may be revised from time to time; (b) Company's rules and regulations,
including Company's Minimum Requirements For Distribution System Interconnection and
Company's Service Regulations as contained in Company's Retail Electric Tariff as each may be
revised from time to time with the approval of the Public Utilities Commission of Ohio
(“Commission”); (c) the rules and regulations of the Commission, including the provisions of
Chapter 4901:1-22, Ohio Administrative Code Uniform Electric Interconnection Standards, as
such rules and regulations may be revised from time to time by the Commission; and (d) all other
applicable local, state, and federal codes and laws, as the same may be in effect from time to
time.
Customer shall install, operate, and maintain, at Customer's sole cost and expense, the
Generation Facilities in accordance with IEEE 1547 “IEEE Standard for Interconnecting
Distributed Resources with Electric Power Systems.” (IEEE 1547) and the manufacturer's
suggested practices for safe, efficient and reliable operation of the Generation Facilities in parallel
with Company's electric system. Customer shall bear full responsibility for the installation,
maintenance and safe operation of the Generation Facilities. Upon request from the Company,
Customer shall supply copies of periodic test reports or inspection logs.
Customer shall be responsible for protecting, at Customer's sole cost and expense, the
Generation Facilities from any condition or disturbance on Company's electric system, including,
but not limited to, voltage sags or swells, system faults, outages, loss of a single phase of supply,
equipment failures, and lightning or switching surges.
Customer agrees that, without the prior written permission from Company, no changes shall be
made to the configuration of the Generation Facilities, as that configuration is described in Exhibit
A, and no relay or other control or protection settings specified in Exhibit A shall be set, reset,
adjusted or tampered with, except to the extent necessary to verify that the Generation Facilities
comply with Company approved settings.
29
3. Operation by Customer. Customer shall operate the Generation Facilities in such a
manner as not to cause undue fluctuations in voltage, intermittent load characteristics or
otherwise interfere with the operation of Company's electric system. At all times when the
Generation Facilities are being operated in parallel with Company's electric system, Customer
shall so operate the Generation Facilities in such a manner that no disturbance will be produced
thereby to the service rendered by Company to any of its other customers or to any electric
system interconnected with Company's electric system. Customer understands and agrees that
the interconnection and operation of the Generation Facilities pursuant to this Agreement is
secondary to, and shall not interfere with, Company's ability to meet its primary responsibility of
furnishing reasonably adequate service to its customers.
Customer's control equipment for the Generation Facilities shall immediately, completely, and
automatically disconnect and isolate the Generation Facilities from Company's electric system in
the event of a fault on Company's electric system, a fault on Customer's electric system, or loss
of a source or sources on Company's electric system. The automatic disconnecting device
included in such control equipment shall not be capable of reclosing until after service is restored
on Company's electric system. Additionally, if the fault is on Customer's electric system, such
automatic disconnecting device shall not be reclosed until after the fault is isolated from
Customer's electric system. Upon Company's request, Customer shall promptly notify Company
whenever such automatic disconnecting devices operate.
4. Access and Inspection by Company. Customer must provide ‚the Company
reasonable opportunity to inspect the Generation Facilities prior to operation and witness the
initial testing and commissioning of the Generation Facilities. Company may witness any
commissioning tests required by IEEE 1547. Following the initial testing and inspection of the
Generation Facilities and upon reasonable advance notice to Customer, Company shall have
access at reasonable times to the Generation Facilities to perform reasonable on-site inspections
to verify that the installation, maintenance and operation of the Generation Facilities comply with
the requirements of this Agreement... The Company's cost of such inspection(s) shall be at
Company's expense; however, Company shall not be responsible for any other cost Customer
may incur as a result of such inspection(s). Upon written request, Customer shall inform
Company of the next scheduled maintenance and allow Company to witness the maintenance
program and any associated testing. Company shall also have at all time's immediate access to
breakers or any other equipment that will isolate the Generation Facilities from Company's
electric system.
5. Disconnection of Generation Facilities. Company shall have the right and authority to
isolate the Generation Facilities at Company's sole discretion if Company believes that: (a)
continued interconnection and parallel operation of the Generation Facilities with Company's
electric system creates or contributes (or will create or contribute) to a system emergency on
either Company's or Customer's electric system; (b) the Generation Facilities are not in
compliance with the requirements of this Agreement, and the non-compliance adversely affects
the safety, reliability or power quality of Company's electric system; or (c) the Generation
Facilities interfere with the operation of Company's electric system. In non-emergency situations,
Company shall give Customer notice of noncompliance including a description of the specific
noncompliance condition and allow Customer a reasonable time to cure the noncompliance prior
to isolating the Generating Facilities.
The Customer retains the option to temporarily disconnect from the Company's system at any
time. Such temporary disconnection shall not be a termination of this Agreement unless the
Customer exercises its termination rights under Section 9.
Subject to Commission Rule, for routine maintenance and repairs on Company's utility system,
Company shall provide Interconnection Service Customer with seven business days’ notice of
service interruption.
6. Rates and Other Charges. This Agreement does not constitute an agreement by
Company to purchase or wheel power produced by the Generation Facilities, or to furnish any
backup, supplemental or other power or services associated with the Generation Facilities, and
30
this Agreement does not address any charges for facilities that may be installed by Company in
connection with interconnection of the Generation Facilities. It is understood that if Customer
desires an agreement whereby Company wheels power, or purchases energy and/or capacity,
produced by the Generation Facilities, or furnishes any backup, supplemental or other power or
services associated with the Generation Facilities, then Company and Customer may enter into
another mutually acceptable separate agreement detailing the charges, terms and conditions of
such purchase or wheeling, or such backup, supplemental or other power or services. lt is also
understood that if any such facilities are required, including any additional metering equipment, as
determined by Company, in order for the Generation Facilities to interconnect with and operate in
parallel with Company's electric system, then a separate agreement shall be executed by
Company and Customer detailing the charges and terms and conditions of payment.
7. Insurance. Customer shall maintain reasonable amounts of insurance coverage against
risks related to the Generation Facilities for which there is a reasonable likelihood of occurrence.
Customer shall agree to provide Company from time to time with proof of such insurance upon
Company's request.
8. Indemnification. Each Party (the “Indemnifying Party”) to the extent permitted by law
shall indemnify and hold harmless the other Party from and against all claims, liability, damages
and expenses, including attorney's fees, based on any injury to any person, including the loss of
life, or damage to any property, including the loss of use thereof, arising out of, resulting from, or
connected with, or that may be alleged to have arisen out of, resulted from, or connected with, an
act or omission by the Indemnifying Party, its employees, agents, representatives, successors or
assigns in the construction, ownership, operation or maintenance of the Indemnifying Party's
facilities used in connection with this Agreement. Upon written request of the Party seeking relief
under this Section 8, the Indemnifying Party shall defend any suit asserting a claim covered by
this Section 8. If a Party is required to bring an action to enforce its rights under this Section 8,
either as a separate action or in connection with another action, and said rights are upheld, the
Indemnifying Party shall reimburse such Party for all expenses, including attorney's fees, incurred
in connection with such action.
9. Effective Term and Termination Rights. This Agreement shall become effective when
executed by both Parties and shall continue in effect until terminated in accordance with the
provisions of this Agreement. This Agreement may be terminated for the following reasons: (a)
Customer may terminate this Agreement at any time by giving Company at least sixty (60) days’
prior written notice stating Customer's intent to terminate this Agreement at the expiration of such
notice period; (b) Company may terminate this Agreement at any time following Customer's
failure to generate energy from the Generation Facilities in parallel with Company's electric
system by the later of two years from the date of execution of this Agreement or twelve (12)
months after completion of the interconnection provided for by this Agreement; (c) either Party
may terminate this Agreement at any time by giving the other Party at least sixty (60) days’ prior
written notice that the other Party is in default of any of the material terms and conditions of this
Agreement, so long as the notice specifies the basis for termination and there is reasonable
opportunity for the Party in default to cure the default; or (d) Company may terminate this
Agreement at any time by giving Customer at least sixty (60) days’ prior written notice in the
event that there is a change in an applicable rule or statute affecting this Agreement.
Upon termination of this Agreement, Customer's Generation Facilities shall be disconnected from
the Company's system.
Termination of this Agreement shall not relieve either party of its liabilities and obligations, owed
or continuing at the time of the termination.
10. Termination of Any Applicable Existing Agreement. From and after the date when
service commences under this Agreement, this Agreement shall supersede any oral and/or
written agreement or understanding between Company and Customer concerning the service
covered by this Agreement and any such agreement or understanding shall be deemed to be
terminated as of the date service commences under this Agreement.
31
11. Force Majeure. For purposes of this Agreement, the term "Force Majeure” means any
cause or event not reasonably within the control of the Party claiming Force Majeure, including,
but not limited to, the following: acts of God, strikes, lockouts, or other industrial disturbances;
acts of public enemies; orders or permits or the absence of the necessary orders or permits of
any kind which have been properly applied for from the government of the United States, the
State of Ohio, any political subdivision or municipal subdivision or any of their departments,
agencies or officials, or any civil or military authority; unavailability of a fuel or resource used in
connection with the generation of electricity; extraordinary delay in transportation; unforeseen soil
conditions; equipment, material, supplies, labor or machinery shortages; epidemics; landslides;
lightning; earthquakes; fires; hurricanes; tornadoes; storms; floods; washouts; drought; arrest;
war; civil disturbances; explosions; breakage or accident to machinery, transmission lines, pipes
or canals; partial or entire failure of utilities; sabotage; injunction; blight; famine; blockade; or
quarantine.
If either Party is rendered wholly or partly unable to perform its obligations under this Agreement
because of Force Majeure, both Parties shall be excused from whatever obligations under this
Agreement are affected by the Force Majeure (other than the obligation to pay money) and shall
not be liable or responsible for any delay in the performance of, or the inability to perform, any
such obligations for so long as the Force Majeure continues. The Party suffering an occurrence
of Force Majeure shall, as soon as is reasonably possible after such occurrence, give the other
Party written notice describing the particulars of the occurrence and shall use commercially
reasonable efforts to remedy its inability to perform; provided, however, that the settlement of any
strike, walkout, lockout or other labor dispute shall be entirely within the discretion of the Party
involved in such labor dispute.
12. Dispute Resolution. In the event that Customer and Company are unable to agree on
matters relating to this Agreement, either Customer or Company may submit a complaint to the
Commission in accordance with the Commission's applicable rules.
The Company or the Customer who is a nonmercantile, nonresidential customer may seek
resolution of any disputes related to this Agreement in accordance with Chapter 4901:1-26, Ohio
Administrative Code Alternative Dispute Resolution.
13. Commission Jurisdiction. Both Company and this Agreement are subject to the
jurisdiction of the Commission. To the extent that Commission approval of this Agreement may
be required now or in the future, this Agreement and Company's commitments hereunder are
subject to such approval.
IN WITNESS WHEREOF, the Parties have executed this Agreement, effective as of the date first
above written.
Ohio Power Company dba AEP Ohio (Customer’s Name)
By: By:
Printed Name: Printed Name:
Title: Title:
32
Exhibit A — Generation Facilities
(Exhibit A will contain additional detailed information about the Customer Facilities such as an
electrical one-line diagram, relay settings and description of operation. The application would be
included here.
Exhibit B — Facilities Required for Interconnection
(Exhibit B will contain a listing of changes/additions to facilities and milestones (e.g. station,
metering, SCADA, etc). The system impact study would be included here. This study should
include the requirements for metering and SCADA.)
33
APPLICATION FOR INTERCONNECTION
AEP ‘ OF GENERATION EQUIPMENT
20 MEGAWATTS OR LESS
OHIO (Standard Form Application)
A unit of American Electric Power
A Short Form Application is available for inverter-based systems (25 kW or less).
An Application is a complete application when it provides all applicable and correct information required below.
Additional information to evaluate a request for interconnection may be required pursuant to the application
process after the Application is deemed complete.
Applications for Interconnection meeting Level 2 qualifying criteria are subject to an application fee of $50 +
$1/kW. Applications for Interconnection meeting Level 3 qualifying criteria are subject to an application fee of
$100 + $2/kW.
Customer
Legal Name:
Mailing Address:
City: State: Zip:
Phone: ( ) Phone: ( )
E-mail address:
Alternate Contact
Name:
Mailing Address:
City: State: Zip:
Phone: ( ) Phone: ( )
E-mail address:
Facility Location
Street Address:
City: Zip:
Service Information
Electric Service Account Number:
Existing Electric Service: Capacity: Amperes Voltage: Volts
Service Character: ( ) Single Phase () Three Phase
Site Maximum Demand: kW Annual Energy Consumption kWh
Requested Point of Interconnection:
Location of Utility Accessible Lockable Disconnect Switch:
(e.g. West wall next to utility meter)
Requested In-Service Date:
9/11/14 lof 3
Consulting Engineer or Contractor
Name:
Address:
City: State: Zip:
Phone: (___) Phone: (___) E-mail:
Generator Qualifications
Energy Source: () Solar () Wind () Hydro: type (e.g. run-of-river)
() Diesel () Natural Gas () Fuel Oil () Other: (specify)
Type of Generator: ( ) Inverter-Based () Synchronous = () Induction
Generator Nameplate Ratings: kW Volts Connected () Wye () Delta
Number of Generators: __ Service Character: () 1 Phase ()3 Phase Power Factor: %
Inverter AC Ratings: kW Volts Number of Inverters
Number of Solar PV Modules: DC Rating: watts
Maximum Net Export Capability: —_ kW Estimated Annual Energy Production: kWh
This Generating Equipment 1s intended to be used to:
() Emergency/Standby — Operated when AEP service is not available. Paralleling is for short durations.
() Peak Shaving — Operated during peak demand periods. Paralleling is for extended times.
() Base Load Power — Operated continuously at a pre-determined output. Paralleling is continuous.
() Cogeneration — Operated primarily to produce thermal energy. Paralleling is extended or continuous.
() Renewable non-dispatched — Operated in response to an available renewable resource. Paralleling is
for extended times.
() Other — Describe:
List components of the generation equipment that are currently certified by a nationally recognized testing
and certification laboratory (NRTL) and/or listed by the Underwriters Laboratory:
Equipment Type UL Listing or certifying NRTL Certification
А о ю
9/11/14 2 of 3
Generation Equipment Technical Information
Attach electrical one-line diagram showing the configuration of all generating facility equipment,
transformers, switchgear, switches, circuit breakers, fuses, current and potential transformers, and
protection and control schemes. (This diagram must be signed and stamped by a licensed Professional
Engineer if the facility is larger than 50kW).
Attach site documentation that indicates the precise physical location of the proposed generating facility
and location of protective interface equipment, disconnect switch, and utility electric meter (e.g. USGS
topographic map or other diagram or documentation).
Attach technical specifications literature for inverters, photovoltaic modules, wind turbines, other
generation equipment, battery systems, transformers, switches, or other interface devices and
documentation that describes and details the operation of all protection and control schemes.
Attach UL 174 1documentation or installation test procedures for all the tests required by IEEE
1547 and the periodic maintenance schedule recommended by the equipment manufacturer.
Attach “Certificate of Liability Insurance” or proof of insurance sufficient to meet construction,
operating and liability responsibilities.
I hereby certify that, to the best of my knowledge, all the information provided in the Interconnection
Application is true and correct.
CUSTOMER'S SIGNATURE:
TITLE:
DATE:
Return Completed Application to: AEP Ohio
Attn: DG Coordinator
850 Tech Center Dr
Gahanna, Ohio 43230-6605
614-883-6775
decoordinator-ohio Qaep.com
9/11/14 30f3
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