ENGINEERING POLICY 305 - FACILITIES CONNECTION REQUIREMENTS APPLICABLE STANDARD(S)
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ENGINEERING
POLICY 305 - FACILITIES CONNECTION REQUIREMENTS
APPLICABLE STANDARD(S): NERC FAC-001-0
DOCUMENT OWNER: TOM KING
APPROVED BY: DAN WILKINSON
TITLE: MANAGER OF ENGINEERING
APPROVED BY: DANNY JANWAY
TITLE: VP OF ENGINEERING & OPERATIONS
Version Number: 5.0
Page 1Table of Contents
1. DEFINITIONS ..............................................................................................................................6
2. INTRODUCTION ..........................................................................................................................7
3. MISO’S FEASIBILITY STUDY .....................................................................................................8
4. SYSTEM IMPACT STUDIES .......................................................................................................8
5. GENERATION CONNECTIONS REQUIREMENTS ..................................................................10
5.1 General Requirements .............................................................................. 10
5.1.1 Backfeed ............................................................................................. 10
5.1.2 Generator Frequency .......................................................................... 10
5.1.3 Interrupting Device .............................................................................. 10
5.1.4 System Protection ............................................................................... 11
5.1.5 Synchronizing ..................................................................................... 11
5.1.6 System Grounding .............................................................................. 11
5.1.7 Voice Communication Circuit .............................................................. 11
5.1.8 Disconnecting Devices........................................................................ 12
5.1.9 Disturbance Monitoring ....................................................................... 12
5.1.10 Transient Stability Performance ........................................................ 12
5.1.11 Excitation Control .............................................................................. 12
5.1.12 Speed Governing .............................................................................. 13
5.1.13 Dynamic Performance Data .............................................................. 13
5.1.14 Automatic Generation Control (AGC)................................................ 13
5.1.15 Black Start Capability ........................................................................ 13
5.1.16 Sub-Synchronous Torsional Interactions or Resonances ................. 13
5.1.17 Unbalanced Electric Conditions ........................................................ 14
5.1.18 Harmonics and Flicker ...................................................................... 14
5.2 Operating Requirements ........................................................................... 14
5.2.1 Synchronization .................................................................................. 15
5.2.2 Generator Step-up and Auxiliary Transformer Tap Settings ............... 15
5.2.3 Voltage Schedule/Power Factor ......................................................... 15
5.2.4 Voltage Range .................................................................................... 16
5.2.5 Frequency Range ............................................................................... 16
5.2.6 Net Demonstrated Real and Reactive Capabilities ............................. 16
5.2.7 Other Applicable Operating Requirements ......................................... 16
5.2.8 Operating Restrictions ........................................................................ 17
Version Number: 5.0
Page 25.3 Relay Protection Requirements ................................................................. 17
5.3.1 Customer Facilities ............................................................................. 17
5.3.2 WPSC Facilities .................................................................................. 18
5.4 Other Protection Requirements ................................................................. 19
5.4.1 Generator Control ............................................................................... 19
5.4.2 Transformer Surge Protection (Lightning Arresters) ........................... 19
5.4.3 Breakers ............................................................................................. 19
5.4.4 Equipment Basic Insulation Levels ..................................................... 19
5.4.5 Insulators for Station ........................................................................... 19
5.5 Costs Incurred ........................................................................................... 19
5.6 Design Review .......................................................................................... 20
5.7 Facility Data............................................................................................... 20
5.7.1 Data on Equipment to be Installed ...................................................... 20
5.7.2 Generator Data ................................................................................... 21
5.8 Final Documentation ................................................................................. 21
5.9 Approval .................................................................................................... 21
6 WPSC NON GENERATION CONNECTIONS TECHNICAL REQUIREMENTS ........................22
6.1 Distribution Interconnection Guidelines ..................................................... 22
6.1.1 Procedure for Distribution Interconnections ........................................ 22
6.1.2 Distribution Interconnection Configuration .......................................... 23
6.1.3 Extraordinary Services Requests ........................................................ 24
6.1.4 Extension of WPSC System to Remote Locations .............................. 25
6.1.5 Facility Ownership .............................................................................. 25
6.2 Tap Connection Definition and Requirements ........................................... 25
6.3 Looped Connection Definition and Requirements ..................................... 26
6.4 Network Connection Definition and Requirements .................................... 26
6.5 Voltage Levels ........................................................................................... 26
6.6 Power Factor Requirements ...................................................................... 26
6.7 Frequency Range ...................................................................................... 27
6.8 Power Quality ............................................................................................ 27
6.8.1 Harmonics and Flicker ........................................................................ 27
6.8.2 Sensitive Electrical Equipment............................................................ 27
6.8.3 Transformer Protective Devices .......................................................... 28
6.9 Unbalanced Electric Conditions................................................................. 28
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Page 36.9.1 Voltage Balance .................................................................................. 28
6.9.2 Current Balance .................................................................................. 28
6.10 Subsynchronous Torsional Interaction .................................................... 28
6.11 Information Required ............................................................................... 29
6.12 Other Design Criteria ............................................................................... 31
6.12.1 Equipment Basic Insulation Levels ................................................... 31
6.12.2 Transformer Surge Protection (Lightning Arresters) ......................... 31
6.12.3 Ratings of Current Carrying Equipment ............................................ 31
6.12.4 Electrical Clearances (Outdoor) ........................................................ 32
6.12.5 Insulators for Station ......................................................................... 32
6.12.6 Air Break Switch(es) and Disconnect Switch(es) .............................. 32
6.12.7 Facility Fence Safety Clearances ..................................................... 33
6.12.8 Ground System Resistance .............................................................. 33
6.12.9 Breaker Duty ..................................................................................... 33
6.13 System Protection ................................................................................... 33
6.13.1 Transmission Protection ................................................................... 33
6.13.2 End-User Protection.......................................................................... 33
6.14 Automatic Under-frequency Load Shedding ............................................ 33
6.15 Remote Relay Access ............................................................................. 34
6.15.1 Loop or Network Connected Facilities .............................................. 34
7 METERING AND TELEMETRY ..................................................................................................34
7.1 Metering .................................................................................................... 34
7.2 Telemetry .................................................................................................. 35
8 VOICE COMMUNICATIONS.......................................................................................................36
8.1 Normal ....................................................................................................... 36
8.2 Emergency ................................................................................................ 36
8.2.1 Generation Owner .............................................................................. 36
8.2.2 Transmission/End-User ...................................................................... 36
8.2.3 Interruptible Contracts......................................................................... 37
8.3 Communication Protocol ........................................................................... 37
9 INSPECTION REQUIREMENTS ................................................................................................37
10 TESTING AND MAINTENANCE REQUIREMENTS ................................................................37
10.1 Generation Owners ................................................................................. 37
10.2 Transmission/End Users ......................................................................... 38
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Page 410.3 Maintenance and Testing Schedule ........................................................ 38
10.3.1 Transmission Substation Protective Relaying Testing ...................... 38
10.3.2 Generation Protective Relay Testing ................................................ 38
10.3.4 Breaker and Transmission Substation Functional Testing ................ 39
10.3.5 Inspection and Testing of Distribution Substations ........................... 39
11 SPECIAL PROVISIONS............................................................................................................39
12 COORDINATION WITH OTHER CODES, STANDARDS, AND AGENCIES ..........................39
13 INDEMNIFICATION ..................................................................................................................40
APPENDIX A ..................................................................................................................................41
Version Number: 5.0
Page 51. Definitions
1.1. Customer shall mean the person or entity requesting an interconnection with
the Wolverine transmission grid.
1.2. WPSC stands for Wolverine Power Supply Cooperative, Inc. and is synonymous
with the Transmission Owner (TO) for this document.
1.3. LGIA or “Interconnection Agreement” shall mean that Large Generator
Interconnection Agreement between the Transmission Provider, the
Transmission Owner, and the Interconnection Customer and filed with and
approved or accepted by FERC.
1.4. Loss shall mean any and all losses relating to injury to or death of any person or
damage to property, demand, suits, recoveries, costs and expenses, court
costs, attorney fees, and all other obligations by or to third parties, arising out of
or resulting from the other Party’s performance, or non-performance of its
obligations under this Agreement.
1.5. NERC shall mean the North American Electric Reliability Council, or its
successor agency assuming or charged with similar responsibilities related to
the operation and reliability of the North American electric interconnected
transmission grid.
1.6. Network Upgrade shall mean the necessary upgrades to the Transmission
Owner Transmission System that would not have been required but for the
interconnection of the Facility to the WPSC transmission system, including
(i) upgrades necessary to remove overloads and voltage criteria violations and
(ii) upgrades necessary to remedy short circuit and/or stability problems
resulting from the interconnection of the Facility to the WPSC transmission
system.
1.7. RFC stands for ReliabilityFirst Corporation. ReliabilityFirst is a not-for-profit
company incorporated in the State of Delaware whose goal is to preserve and
enhance electric service reliability and security for the interconnected electric
systems within its territory. ReliabilityFirst was approved by the NERC to
become one of eight Regional Reliability Councils in North America and began
operations on January 1, 2006.
1.8. MISO stands for the Midwest Independent Transmission System
Operators. As a fully integrated regional transmission organization, the non-
profit Midwest ISO assures industry consumers of unbiased regional grid
management and open access to the transmission facilities under Midwest ISO's
functional supervision. Midwest ISO optimizes the efficiency of the
interconnected system, provides regional solutions to regional planning needs
and continually minimizes any risk to reliability.
Version Number: 5.0
Page 62. Introduction
This document provides minimum connection requirements for all entities seeking facility
connections to WPSC’s system. It is the intent of this document to satisfy the NERC
Planning Standard FAC-001 by identifying requirements for connections. Although
NERC and RFC requirements refer to the Bulk Transmission System and voltages of
100 kV and above, this document also applies to connections to WPSC’s systems rated
lower than 100 kV. This document does not address how or what entity will pay for
studies and system upgrades.
Transmission Interconnections refer to transmission connections between WPSC and
other utilities. Connections other than generation are considered End-Users or Load
Serving Entities (LSE). Requests for connections to WPSC’s system will follow the
procedures outlined by MISO and, in general, will require an application, Feasibility
Study, System Impact Study (SIS), and a Facility Study or Generator Interconnection
Study. All expenses associated with these studies are the responsibility of the party
requesting the interconnection. These studies will be performed to determine the
detailed impact on WPSC’s system. These studies are directed by the MISO and
required to meet their format. More details of MISO’s requirements to initiate a study
can be obtained by contacting MISO. Any upgrades, additions, enhancements, or
changes of any kind to an existing connected facility are subject to WPSC and MISO’s
review to ensure continued compliance with these requirements
WPSC operates its transmission system in compliance with NERC Reliability Standards,
RFC standards, and WPSC’s own planning criteria and facility connection requirements.
All facilities involved in the generation, transmission, and distribution of electricity must
be properly connected to the interconnected transmission system to avoid degrading its
reliability and ensure continued compliance to the applicable reliability standards. The
procedures outlined by MISO and described above are meant to ensure WPSC’s
transmission system continues to meet these reliability standards.
The scope of this document is limited to the technical requirements for connected facility
design and operation and does not address transmission service. Parties requiring
transmission service should refer to the WPSC Open Access Transmission Tariff.
The objective of this document is to:
Satisfy compliance with NERC Planning Standard FAC-001 pertaining to
documentation of facility connection requirements by those entities responsible for
system reliability.
Inform those entities seeking facility connections to the WPSC System of the various
requirements for system reliability, personnel and equipment safety, and quality of
service.
Ensure consistent requirements are imposed on the various entities seeking to
connect facilities to the network.
Maintain system reliability, personnel and equipment safety, and quality of service as
new facilities are added to the network and existing facilities are modified.
Ensure continued compliance with NERC Reliability Standards, RFC standards,
MISO standards, and WPSC’s own planning criteria and facility connection
requirements.
Version Number: 5.0
Page 7 Provide uniform equipment specifications, designs, engineering, and installation
practices to promote safety and uniformity of service.
3. MISO’s Feasibility Study
Any entity proposing new or materially changed generation or load serving connection
points for transmission service from WPSC’s system must initiate a Feasibility Study.
The Feasibility Study is initiated through MISO and is performed or supervised by
WPSC. The Feasibility Study is performed to determine and evaluate the electrical
configuration and physical connections/locations between the transmission system and a
proposed connected facility. The electrical configuration determines the connection
equipment including transformers, switchgear and other station equipment, and required
transmission line sections. The MISO will notify any interconnected utility that could be
impacted by the proposed facility and coordinate the studies to determine their impact as
necessary.
For the proposed interconnection modeled, the Study shall determine:
1) The cause of any electric system capability and reliability limitations;
2) A list of electric system components that must either be upgraded or
constructed to accommodate the proposed interconnection;
3) The amount of generation/load that can be accommodated without
violating facility ratings and/or reliability standards if the full
generator/load cannot be accommodated without exceeding such
facility ratings and/or reliability standards.
The Study shall consider the locational effects of the generator/load. This analysis shall
be a quick screening process used to identify required interconnection upgrades. This
study is just meant to identify local constraints on the neighboring transmission system
and is not a delivery study.
4. System Impact Studies
After the Feasibility Study a SIS must be performed, if the interconnection customer
chooses to continue with the process. The SIS is used to determine the proposed
connection facility’s impact on system reliability. The proposed generation will be tested
covering a range of probable operating conditions and system responses to probable
disturbances. The transient stability affect of the new generation/load on the existing
system and the behavior of the additional generation/load following system faults are
studied. For new generation, the ability to meet WPSC’s reactive power requirements
will be analyzed. The dynamic fault clearing simulation tests for connection to the Bulk
Electric System (BES) will include:
1. bolted 1-phase to ground faults at most critical location cleared by primary
relaying.
2. bolted 3-phase to ground faults at most critical location cleared by primary
relaying.
3. bolted 2-phase to ground faults at most critical location resulting with delayed
clearing due to a breaker failure.
4. bolted 3-phase to ground faults with critical element out-of-service prior to the
fault event cleared by primary relaying.
Version Number: 5.0
Page 8The dynamic fault clearing simulation tests for connection to the non-BES include:
1. bolted 1-phase to ground faults at most critical location cleared by primary
relaying.
2. bolted 3-phase to ground faults at most critical location cleared by primary
relaying.
3. bolted 2-phase to ground faults at most critical location resulting with delayed
clearing due to a breaker failure.
Total clearing time to be studied will be 4 cycles local and 34 cycles for faults cleared by
primary relaying and 19 cycles local and 49 cycles remote for breaker failure clearing.
This will be reviewed on a case-by-case basis prior to performing the study.
All requested study transfers will be analyzed without the proposed generation/load
interconnection and with the proposed generation/load interconnection to determine any
adverse impacts on the transfer capability caused by the proposed generation/load. The
Study shall identify any reductions in transfer capability and the associated system
conditions. No delivery rights will be granted based on this study.
The SIS will determine the impact of the proposed facility for a range of expected
seasonal loading and power transfer conditions on the transmission line and transformer
loading, voltage profiles and schedules, minimum reactive requirements, and power
quality. The effect of the proposed facility on short circuit duties is examined for all
proposed generation facilities and transmission connections. Stability performance is
also assessed for all proposed generation facilities. A multi-step approach to the
proposed facility may be considered when the impact of each step is assessed
separately.
The scope of the above SIS is determined by WPSC and/or MISO based on the type,
location, and power level of the proposed facility. WPSC or a consultant to WPSC will
perform the system impact studies at the expense of the requesting party. A report
documenting the assumptions, results, and conclusions of the SIS is made available to
the requesting party. WPSC must be notified in writing of new facilities, upgrades, or
additions. This includes an increase in load or added generating units to existing
facilities connected to the transmission system within the WPSC Control Area.
WPSC approval of a proposed facility or facility change is contingent upon a design
review of the proposed connected facility. Operation of a connected facility is also
subject to continuing compliance with all applicable construction, maintenance, testing,
protection, monitoring, and documentation requirements of WPSC, MISO, RFC and the
applicable NERC Planning Standards.
Version Number: 5.0
Page 95. Generation Connections Requirements
5.1 General Requirements
Applications for generator interconnection within WPSC's system should be
directed to the Midwest ISO. The request will be entered into the Midwest ISO's
study queue for generator interconnection. The Midwest ISO will contact WPSC
as the direct-connect Transmission Owner in order to inform WPSC that the
application has been received. An Ad Hoc Working Group will be formed
consisting of WPSC personnel, other affected transmission owners or parties and
Midwest ISO personnel. The Midwest ISO contact for generator interconnection
studies is as follows:
Mr. Diwakar Tewari
Midwest ISO
720 City Center Drive
Carmel, IN 46032
DTewari@midwestiso.org
(317) 249-5715
Attachment R to the tariff, Generator Interconnection Procedures and
Agreement, prescribes the procedures for small generators (defined as
generation interconnection requests equal to or less than 20 MW). Attachment X
to the tariff, Standard Large Generator Interconnection Procedures, prescribes
the procedures applicable to generating facilities that exceed 20 MW. The
attachments may all be found at www.midwestiso.org.
The customer must take responsibility to specify appropriate equipment and
ancillary operating facilities so that the parallel generation facility is compatible
with the WPSC transmission system. The applicant’s installation must conform
to National Electrical Safety Code (NESC) and National Electrical Code (NEC)
requirements.
5.1.1 Backfeed
A customer’s generation facility should not backfeed power into
the WPSC system unless a specific agreement has been made to
supply power to the WPSC system. Under no circumstances
should a customer energize a disconnected WPSC circuit.
5.1.2 Generator Frequency
All generation shall be nominal 60 Hz, balanced, positive
sequence, three-phase generation.
5.1.3 Interrupting Device
The customer must provide a three phase interrupting device to
isolate the generation from the WPSC system for any faults or
abnormal operating conditions. This device shall be capable of
interrupting the maximum available fault current at that location,
regardless of the source, and clear the fault in less than one cycle
once initiated. The three-phase device shall interrupt all three
Version Number: 5.0
Page 10phases simultaneously. The interruption control shall have
automatic (relay), WPSC SCADA, and manual initiation. The
tripping control of the circuit interrupting device shall be powered
by a battery backed DC source that is independent of the AC
source. This is required in order to ensure operation upon loss of
the WPSC transmission voltage source under abnormal or fault
conditions.
5.1.4 System Protection
The customer will have responsibility for providing adequate
system protection to WPSC facilities for the generation including
system protection for any WPSC operating conditions, whether or
not their generation is in operation. WPSC has standardized on
Schweitzer Engineering Laboratory (SEL) relays for its
transmission lines and requires these relays to be used to ensure
coordination. The Customer is responsible to provide Primary and
Backup relaying in sufficient quantity to produce a redundant trip
scheme capable of interrupting under all conditions listed above.
Short Circuit: phase-to-phase, phase-to-phase-to-ground,
three phase, three phase-to-ground, or phase-to-ground.
Abnormal voltage or frequency.
Lightning and switching surges.
Excessive harmonic voltages and/or currents.
Excessive negative sequence voltages.
Separation from WPSC.
5.1.5 Synchronizing
The customer shall assume all responsibility for synchronizing the
generator with the WPSC system. The initial synchronization of
the generator to WPSC’s system shall require monitoring to
ensure that all three phases are synchronized and have the
correct sequence. After the first successful synchronization, only
the A phase voltage is required to be synchronized before
connecting to the WPSC system. Upon loss of the WPSC supply,
the customer must immediately separate from the WPSC system.
5.1.6 System Grounding
Grounding requirements for connections to WPSC transmission
systems must meet all NESC and NEC requirements. WPSC will
review all interconnection grounding designs and reserves the
right to require the customer to add additional grounding.
5.1.7 Voice Communication Circuit
The customer will be required to establish a voice communication
circuit capable of reliably interfacing with WPSC’s Control Center.
The intent is to facilitate communication for maintenance and
system configuration modifications as required.
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Page 115.1.8 Disconnecting Devices
A three-phase air break switch or a three-pole single-throw
disconnect switch accessible at all times shall be installed on each
transmission line supply entrance to the connecting facility in
addition to the interrupting device described above. The
disconnecting device is to provide a visible isolation point between
the connecting facility and WPSC’s transmission system and shall
have a mechanical interlock in the open position suitable for a
WPSC padlock. The disconnecting device shall be identified with
a WPSC designated equipment number.
5.1.9 Disturbance Monitoring
The Customer’s system must have disturbance monitoring
equipment per PRC-002-RFC-01 (Found at www.RFirst.org).
5.1.10 Transient Stability Performance
Transient stability performance of the generator is the
responsibility of the Customer. Transient stability performance
should be in accordance with WPSC Transient Stability Criteria
and outlined in the SIS. WPSC will perform the necessary studies
to evaluate transient stability performance. The cost of these
studies will be the responsibility of the Customer as part of the
SIS.
5.1.11 Excitation Control
In addition to the normal excitation system and automatic voltage
regulation equipment, the following controls are also required for
each synchronous generator:
Reactive Compensation - Reactive line drop compensation
shall be provided in the automatic voltage regulator (AVR)
to permit the control of voltage beyond the generator
terminals. The point of control shall be adjustable over a
range of 0 to 0.15 per unit reactance (on the generator
base).
Over-current Limiter - The excitation system shall be
provided with a current limiting device that will supersede
or act in unison with the AVR to automatically reduce
excitation so the generator field current is maintained at
the allowable limit in the event of sustained under-voltages
on the transmission system. The over-current limiter
device must not prevent the exciter from going to and
remaining at the positive limit for 0.1 seconds following the
inception of a fault on the power system.
Under-excitation Limiter - An under-excitation limiter to
prevent instability resulting from generator under-excitation
is required.
Version Number: 5.0
Page 12Power System Stabilizer – Power System Stabilizers
(PSS) which is installed in the Automatic Voltage Regulator
of the generator can improve the power system stability.
Though the output power is determined by the generator
mechanical torque, a generator output value can also be
changed by changing excitation values transiently. A PSS
detects changing of the generator output power, controls
the excitation, and reduces the power swing. WPSC
studies may identify the need for the use of power system
stabilizers, depending on the plant size, excitation system
type and settings, facility location, area transmission
system configuration and other factors. This will be
determined on a case-by-case basis.
5.1.12 Speed Governing
All synchronous generators shall be equipped with speed
governing capability. This governing capability shall be unhindered
in its operation consistent with overall economic operation of the
generation facility. See NERC Reliability Standard VAR-002.
Over-speed protection in the event of load rejection is the
responsibility of the Customer.
5.1.13 Dynamic Performance Data
Dynamic performance data shall be made available to WPSC as
part of the facility specifications and plans for evaluation by
WPSC. This data is required to evaluate the system dynamic
performance of the generation facility that includes but is not
limited to transient stability.
5.1.14 Automatic Generation Control (AGC)
Depending upon various control area factors applicable to tie line
and frequency regulation, provision for dispatch control of the
generation facility by the MISO Control Center AGC system may
be required. This will be considered on a case-by-case basis and
any provision for control by AGC should be included in a Facility
Connection Agreement between the Customer and WPSC/MISO.
5.1.15 Black Start Capability
Depending upon the geographic location and other
considerations, black start capability may be required.
Recommendations for black start requirements will be made in the
SIS. The Facility Connection Agreement shall address the black
start requirements.
5.1.16 Sub-Synchronous Torsional Interactions or Resonances
High speed reclosing and sub-synchronous currents may result in
excessive torsional stress on the generator. The Customer must
provide WPSC with protection from damaging torsional
oscillations resulting from all WPSC transmission system
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Page 13operations, and ensure the turbine-generator is not excited into
resonance by normal system operations. The Facility Connection
Agreement shall address these matters.
5.1.17 Unbalanced Electric Conditions
5.1.17.1 Voltage Balance
All three-phase generation shall produce balanced 60 Hz
voltages. Voltage unbalance attributable to the Customer
combined generation and load shall not exceed 1.0%
measured at the point-of-service. Voltage unbalance is
defined as the maximum phase deviation from average as
specified in ANSI C84.1, American National Standard for
Electric Power Systems and Equipment – Voltage Ratings,
60 Hertz.
5.1.17.2 Current Balance
Phase current unbalance attributable to the Customer
combined generation and load shall not exceed that which
would exist with balanced equipment in service, measured
at the point-of-common coupling. Situations where high
unbalance in voltage and/or current originates from the
transmission system are to be addressed in the Facility
Connection Agreement.
5.1.18 Harmonics and Flicker
The Customer shall take responsibility for limiting harmonic
voltage and current distortion and/or voltage flicker caused by
their generation equipment. Limits for harmonic distortion
(including inductive telephone influence factors) are consistent
with those published in the latest ANSI/IEEE 519, Recommended
Practices and Requirements for Harmonic Control in Electrical
Power Systems. WPSC criteria requires that flicker occurring at
the point of compliance shall remain below the “Border Line of
Visibility” curve on the IEEE 1453/GE curve for fluctuations less
than 1 per second or greater than 10 per second. However, in the
range of 1 to 10 fluctuations per second, voltage flicker shall
remain below 0.4%. Depending upon the nature of the generation
and its location, WPSC may require the installation of a monitoring
system to permit ongoing assessment of compliance with these
criteria. The monitoring system, if required, will be installed at the
Customer’s expense. Situations where high harmonic voltages
and/or currents originate from the transmission system are to be
addressed in the Facility Connection Agreement.
5.2 Operating Requirements
The Customer is responsible for operating their generation with full regard
for the safe practices of, and with full cooperation under the supervision
of, the WPSC/MISO Operation Center. A Customer’s generation shall not
supply power into the WPSC transmission system unless a specific
written agreement has been made to supply power to the WPSC
Version Number: 5.0
Page 14transmission system. Under no circumstances shall a Customer energize
WPSC transmission facilities that have been de-energized. Circuits that
are electrically disconnected from the WPSC transmission system and
are energized by a Customer constitute a potential safety hazard for both
WPSC transmission personnel and the general public. Also, the
energizing of such circuits at abnormal voltage or frequency could cause
damage to electrical equipment of both the WPSC transmission system
and the Customer’s generation. WPSC reserves the right to disconnect
service to any generating facility if, for any reason, WPSC deems the
continuation of the service is, or may be, a detriment to the operation of
the WPSC Transmission System. The minimum requirements for
operation of a generation facility on the WPSC Transmission System are
contained herein.
5.2.1 Synchronization
The Customer shall assume all responsibility for properly
synchronizing their generation for operation with the WPSC
Transmission System. Upon loss of the WPSC supply, the
Customer shall immediately and positively cause the generation to
be separated from the WPSC system. Synchronizing of
generation to the WPSC Transmission System may be, at
WPSC’s discretion, performed under the direction of the
WPSC/MISO Control Center.
5.2.2 Generator Step-up and Auxiliary Transformer Tap
Settings
The Customer must provide to WPSC the tap settings, available
tap ranges, and impedance data for generator step-up and
auxiliary transformers. WPSC may require changes to the tap
settings for voltage control purposes. If tap setting changes are
necessary, WPSC will provide the Customer with a report that
specifies the required tap changes and technical justification for
these changes.
5.2.3 Voltage Schedule/Power Factor
Specification of the generator voltage schedule will be determined
under the direction of the WPSC/MISO Control Center. This
requirement is listed on the MISO website. See also NERC
Reliability Standard VAR-002. A steady-state deviation between
+0.5% to –0.5% of the nominal voltage will be permissible.
WPSC’s voltage schedule is determined by WPSC’s Energy
Control Center and can be obtained by calling 800-283-1260. In
certain unusual situations where a voltage schedule is
inappropriate, WPSC/MISO, initially and in the future, may
substitute adherence to a specified voltage schedule with a
specified power factor. A steady state deviation from this power
factor of less than +/-1% is required.
Version Number: 5.0
Page 155.2.4 Voltage Range
The generation facility must be capable of continuous non-
interrupted operation within a steady-state voltage range during
system normal and single facility outage conditions. This voltage
range is from 95% to 105% of the nominal transmission voltage.
During emergency and/or transient system conditions, as voltage
may temporarily be outside the 95% to 105% range, all
reasonable measures should be taken to avoid tripping of the
generation facility due to high or low voltage.
5.2.5 Frequency Range
The generation facility must be capable of continuous, non-
interrupted operation in the frequency range of 59.5 to 60.5 Hz.
Limited time, non-interrupted operation is also expected outside
this frequency range in accordance with the generator
manufacturer’s recommendations.
5.2.6 Net Demonstrated Real and Reactive Capabilities
The Net Demonstrated real capability in accordance with ECAR
(RFC) Document 4 and NERC Reliability Standards MOD-024 and
MOD-025 must be provided to WPSC annually. In addition,
individual generators in the generation facility must make available
the full steady-state over and under-excited reactive capability
given by the manufacturer’s generator capability curve at any MW
dispatch level. Tests that demonstrate this capability must be
conducted and documented at not more than five-year intervals in
accordance with ECAR (RFC) Document 4 and NERC Reliability
Standards MOD-024 and MOD-025. Such documentation shall be
provided to WPSC. WPSC reserves the right to witness these
tests.
5.2.7 Other Applicable Operating Requirements
In order to assure the continued reliability of the WPSC
Transmission System, the Customer may be requested to adhere
to other operating requirements and/or encouraged to adopt
common operating practices. These operating requirements and
practices include the coordination of maintenance scheduling,
performance not to exceed a specified forced outage rate,
operations procedures during system emergencies, participation
in control area operating reserves, provisions for backup fuel
supply or storage, and provisions for emergency availability
identified by the North American Electric Reliability Council.
WPSC, as the Transmission Provider, may require the Customer
to provide Interconnected Operation Services defined by NERC
under Policy 10. Such requirements shall be addressed in the
Connection Agreement with the Customer. Conformance with
applicable requirements in ECAR (RFC) Documents, particularly
Document 4, “Criteria and Methods for the Uniform Rating of
Generation Equipment, RFC Reliability Standard PRC-002-RFC-
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Page 1601, “Disturbance Monitoring and Reporting Requirements”, and
NERC Reliability Standard VAR-002, “Generator Operation for
Maintaining Network Voltage Schedules”, are required. All data
reportable to RFC and/or NERC shall also be made available to
WPSC.
5.2.8 Operating Restrictions
Situations necessitating generation curtailments or forced outages
as the result of unavailability of transmission facilities owned
and/or operated by WPSC are to be addressed in a Facility
Connection Agreement with the Customer.
5.3 Relay Protection Requirements
5.3.1 Customer Facilities
The customer is responsible for determining the generation and
transformer protective equipment required to meet all applicable
standards that it is properly installed, and coordinates with WPSC
relaying. WPSC reserves the right to specify relay settings
deemed necessary to ensure coordination, avoid safety hazards,
or to prevent any impairment of WPSC’s ability to serve other
customers. The customer is liable for failure of the protective
relays to meet standards and operate effectively.
The relay protection system may be part of a self-contained
generation control package. Additional relay protection may be
required if testing or operational problems are encountered with
this self contained generation control package. WPSC shall
review the interface protection and/or the self-contained protection
schemes included with the generation before the unit will be
permitted to connect to the WPSC system.
The following relay functions are required by the customer for
protection of the WPSC system. The use of the transfer trip
receiver is conditional as set forth below.
Relay Purpose
Frequency To detect under and over-frequency
operation and separate the customer
parallel generation.
Under/Over-Voltage To detect under and over-voltage
operation and cause separation of
the customer parallel generation.
Transfer Trip Receiver To receive a trip signal from a
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Page 17WPSC transfer trip transmitter and
separate the customer parallel
generation.
Ground Fault Detector To detect a ground fault on the
WPSC or customer system and
separate the customer’s generation.
Over-Current To detect an over-current condition
and separate the customer’s
generation.
Directional Power To detect a reverse power flow
condition and separate the customer
parallel generation.
Output contacts of these relays shall directly energize the trip
coil(s) of the generation breaker or an intermediate auxiliary
tripping relay that directly energizes the breaker trip coil(s). The
relaying system shall have a power source independent from the
ac system and immune to ac system loss or disturbances (e.g., dc
battery and charger) to ensure proper operation of the protection
scheme. The loss of this source shall cause removal of the
generation from the WPSC system. The protective relays
required by WPSC and any auxiliary tripping relay associated with
those relays shall be utility-grade devices.
Utility grade relays are defined as follows:
Meet ANSI/IEEE Standard C37.90, Relays and Relay
Systems Associated with Electric Power Apparatus.
Have relay test facilities to allow testing without
unwiring or disassembling the relay.
Have appropriate test plugs/switches for testing the
operation of the relay.
Have targets to indicate relay operation.
It is the Customer’s responsibility to determine that their protective
equipment is adequate to meet all applicable standards.
5.3.2 WPSC Facilities
A transfer trip relaying system must be installed at the Customer’s
expense if WPSC determines it is necessary to protect WPSC
facilities at this level. The transfer trip relaying system shall
consist of all transfer trip transmitters located at WPSC facilities,
transfer trip receivers at the Generation Facility, and the
communication channels between the WPSC location(s) and the
Generation Facility.
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Page 185.4 Other Protection Requirements
5.4.1 Generator Control
The following items shall be coordinated with each other:
Ground Time Over-Current elements at adjacent facilities.
Volts/Hz and over-excitation protection/limiting.
Loss-of-excitation and under-excitation limiting.
See also NERC Reliability Standard VAR-002.
5.4.2 Transformer Surge Protection (Lightning Arresters)
Lightning arresters protecting transformers are generally mounted on
the transformer. However, since lightning arresters can adequately
protect equipment some distance from the arresters, the overall
number of lightning arresters required in each design can be reduced.
Allowable lightning arrester separation distance from the equipment
being protected shall be determined by the latest edition of IEEE Std.
C62.22 IEEE Guide for the Application of Metal-Oxide Surge Arresters
for Alternating –Current Systems. The Transmission/End-User should
consult the manufacturer’s catalog for details concerning arrester
protective characteristics, ratings, and application.
5.4.3 Breakers
The minimum breaker duty ratings, in regards to the interrupting
capabilities, will be provided by WPSC.
The minimum breaker ratings, in regards to continuous and short
circuit capabilities, will be provided by WPSC.
5.4.4 Equipment Basic Insulation Levels
The minimum required Basic Insulation Levels (BIL) for stations will
be provided by WPSC. Facilities in areas with significant air pollution
may require a higher insulation level.
5.4.5 Insulators for Station
WPSC will determine the required station post insulator types.
Facilities in areas with significant air pollution may require a higher
insulation level. Higher strength insulators are available and should
be used if needed to meet bus momentary fault circuit withstand
values.
5.5 Costs Incurred
The customer must take responsibility for all costs incurred by WPSC to provide
parallel operation of the generation facility. This includes, but is not limited to:
Each review of the engineering and engineering drawings associated
with the generation.
All metering not covered under the transmission tariff of general
applicability.
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Page 19 The necessary facility modifications on the WPSC transmission
system to adequately accommodate the operation of the Customer’s
facility
WPSC facility replacements, modifications, and/or enhancements due
to exceeded ratings directly caused by or which could potentially be
caused by the power flow attributed to the generation.
All communications circuits required for telemetering, protective
relaying, and/or voice communications with the generation.
All protective devices to be provided by the Customer for the
protection of the WPSC transmission system.
All protective relaying, including any transfer trip transmitter(s),
receiver(s), and associated equipment, not on the Customer's
premises required by WPSC due to the addition of the generation.
All protective relaying required to protect the generation from faults
and abnormal system operating conditions.
All additional regulating and control devices required. This would
include any equipment necessary for suppression of harmonic current
and/or voltages.
WPSC equipment replacements or modifications caused by the
increase in available fault current associated with the installation of
the Generation Facility.
Calibration, testing, and maintenance of relays and protective devices
provided by the Customer for the protection of the WPSC
transmission system.
All telemetering equipment to provide necessary telemetry to the
WPSC/MISO Control Centers.
Future changes associated with the generation due to changing
conditions on the WPSC system.
All studies performed by WPSC/MISO pertaining to the Generation
Facility.
5.6 Design Review
The Customer is responsible for submitting all specifications and detailed plans
to WPSC for review and approval prior to receiving permission to connect to the
WPSC transmission system. WPSC requires a review of the Customer’s plans
for the generation to determine the compatibility of design and operation with the
WPSC system. This design review does not relieve the Customer of any
responsibility identified in this document or determine in other contracts.
5.7 Facility Data
At least nine (9) months prior to the in-service date, WPSC shall receive the
following data. The purpose of generation facility data to be provided to WPSC
by the Customer is to ensure proper coordination to protect against equipment or
facility damage, to mitigate safety hazards to utility personnel and the public, and
to minimize interference with WPSC’s ability to serve other transmission system
users.
5.7.1 Data on Equipment to be Installed
Interrupting Devices and Relays
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Page 20Complete manufacturer's data for interrupting devices and relays
used for the protection of the WPSC system and the generation.
Power Transformers
Complete nameplate and test sheet data.
Power Capacitors
Voltage and VAR rating of capacitor banks, number of units, bank
configuration, and detailed drawings of capacitor interconnect.
Data on the generation protection equipment. including transfer
switches, fuses, breakers, relays, relay settings, and detailed
schematic diagrams.
Complete manufacturer's data and specifications for transfer
switches, testing procedures, equipment schematics, and backup
protection.
Information on characteristics of load, such as initial and near future
expected load, power factor of such load, and dynamic (flicker,
harmonics, etc.) character of such load.
Required minimum and maximum low-side operating voltages.
5.7.2 Generator Data
Type (synchronous, induction, dc with solid-state inverter, etc.);
Nameplate data and ratings, including any rectifying, regulating, or
inverting equipment;
Harmonic content at full rated output;
Detailed dynamic performance data.
Real and reactive capabilities at scheduled voltages.
Electric one-lines and schematic diagrams showing the generation,
the interconnecting facility with the WPSC transmission system, and
the protective relaying.
5.8 Final Documentation
WPSC shall receive final documentation of the generation facility that
replaces the above specifications and data submitted for the design
review once the facility is ready for operation. Prior to operation of a
generation facility, the Customer shall supply to WPSC three copies of all-
final electric one-line, equipment data, and schematic diagrams.
Subsequent revisions affecting the generation facility shall be
documented with three copies of the revised electric one-line and
schematic diagrams.
5.9 Approval
The construction, testing, and maintenance of the protective relaying
equipment provided by the Customer for protection of the WPSC
transmission system shall be subject to review and approval by WPSC.
Prior to establishing service for operation, the Customer shall obtain
approval from WPSC for the generation, electrical equipment
specifications, and operating procedures. WPSC will issue final approval
for operation of a Customer’s generation. Failure to meet any of the
requirements stated herein to the satisfaction of WPSC may result in a
refusal to permit operation of the generation facility. Review and approval
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Page 21by WPSC of the proposed generation facility specifications and plans
shall not be construed as confirming or endorsing the design or
warranting the safety, durability, reliability, adequacy, or otherwise of the
generation facility.
6 WPSC Non Generation Connections Technical Requirements
6.1 Distribution Interconnection Guidelines
6.1.1 Procedure for Distribution Interconnections
6.1.1.1 Introduction
This procedure describes the process for a Distribution Utility
["DU"] to establish a new or modify an existing Distribution
Interconnection with WPSC. The process requires a formal
Transmission Service Request that meets WPSC and Midwest
ISO requirements. The procedure provides for regular, on-going,
well coordinated planning, design and construction processes so
that new interconnection facilities can be completed within a
normal project schedule time frame. It also provides for an
expedited application process when unanticipated needs occur.
6.1.1.2 Transmission Access and Annual Load & Resource
Update
A DU requesting an interconnection from WPSC for service from
MISO, including any DU interconnected to WPSC under a
grandfathered coordination or transmission ownership agreement,
must request transmission access for each individual distribution
interconnection. In addition, any DU connected to the WPSC
transmission system must submit an annual Network Integration
Transmission Service [NITS] application update to the Midwest
ISO.
6.1.1.3 Transmission Service Request
For each new distribution interconnection project or modification to
an existing interconnection, the applicant must submit a
Transmission Service Request to the MISO. The MISO, in
accordance with Attachment D in the MISO tariff, will process the
request and complete a System Impact Study. This includes an
analysis of the alternatives to satisfy the request and a preliminary
estimate of any direct assignment facilities and network upgrades
required.
6.1.1.4 Annual Network Integration Transmission Service [NITS]
Application Update
Any DU interconnected to WPSC must file an annual NITS
application update with MISO by November 1 each year. The
application provides a forecast of the DU load and resources,
plans for distribution system expansion, and a forecast of all new
and expanded distribution interconnections.
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Page 22WPSC will perform on-going planning studies taking into
consideration the DU forecast growth and expansion plans.
WPSC will work with the DUs on its system to develop optimized
solutions for new and expanded distribution interconnections.
6.1.1.5 Expedited Application Process
When unanticipated needs occur requiring expedited application
processing, such actions as temporary facilities, shortened
schedules and special letter agreements to support parallel work
activities may be used to attempt to meet the requested service
date. Each requirement for expedited service will be handled
individually under the Midwest ISO Tariff provisions. The
requesting DU will be responsible for any costs for providing
expedited service over and above those normally incurred by
WPSC.
6.1.2 Distribution Interconnection Configuration
6.1.2.1 Introduction
A radial distribution interconnection is the standard service for DU
interconnections. Special distribution system needs requiring
services beyond the standard will be handled in accordance with
Section C, Extraordinary Service Requests.
6.1.2.2 Standard Connection to WPSC System
Radial supply connections will be implemented for all types of DU
interconnections including but not limited to interconnections for
distribution substations (load service substation), dedicated
customer substations and bulk power substations (substation
feeding a sub-transmission system).
The cost of the radial portion of each interconnection from the
WPSC tap point to the DU substation and any associated
switching will be direct assignment costs and the financial
responsibility of the requesting DU.
6.1.2.3 Dedicated Customer Substation Distribution
Interconnection with Parallel Generation
Where a dedicated Distribution Interconnection is required to
serve a large retail load with parallel generation that can be
offered for sale to third parties across the grid, the greater of the
maximum retail load served or maximum power delivered to the
grid will dictate the interconnection design. The DU must request a
dual purpose interconnection, since the customer is both a DU
retail customer and a Transmission Service customer.
Full open access to the transmission grid will be available via this
dual purpose interconnection. Service needed to meet the retail
service requirements will be determined first, with additional
capacity and facilities, if any, to allow full open access to the
transmission grid added.
Version Number: 5.0
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