GTC Facility Connection Requirement Document

FACILITY CONNECTION
REQUIREMENTS
Georgia Transmission Corporation
Effective date March 3, 2014
Individual
Making
Edits
Date
Version
Number
03/24/2005
1
04/13/2005
2
04/13/2007
3
04/19/2007
4
01/29/2008
5
J. W. Chiles
03/31/2009
6
S. G. Miller
05/07/2009
7
S. G. Miller
3/15/2013
8
Zakia El Omari
11/22/2013
9
Zakia El Omari
Rob Wiley
02/19/2014
10
Zakia El Omari
Rob Wiley
Reason / Comments
FCR Document reviewed and updated to align with the new
SERC Supplement.
Paragraph 1.18 (Abnormal frequency and Voltage
Operation) updated to address GTC connection
requirements, per SERC Audit Team request.
FCR document reviewed and updated to align with GTC's
procedure for maintenance coordination.
Section 1.14, 1.15, 3.3 and 4.5 of the FCR document have
been reviewed and updated to reflect GTC's current
standard operating practice and procedures utilized in the
protection of interconnected transmission facilities.
Review based on Internal GTC Review by Electronic
Maintenance, Protection & Control, Bulk System Planning,
Substation Maintenance.
Review based on Internal GTC Review by Electronic
Maintenance, Protection & Control, Bulk System Planning,
Substation Maintenance.
Review based on Internal GTC Review by Electronic
Maintenance, Protection & Control, Bulk System Planning,
Substation Maintenance.
Added section to describe compliance with R.2.1.2.
Reviewed and updated sections addressing R2.1.1, R2.1.35, R2.1.7-8 and R2.1.14-16
FCR updated to reflect new FAC-001-1 requirements
numbering (ex. R2.1.1 changed to R3.1.1). Grammar
correction in Purpose statement. Changed document
applicability to include sub-transmission system
Added clarification statements based on GDS Mock Audit
feedback. Updated sections: Purpose, R3.1.1, R3.1.3 to
R3.1.6, R3.1.9 to R3.1.11. Added section: A5: Maintenance
of FCR document. Additional review based on input from
GTC managers and regulatory compliance manager
TABLE OF CONTENTS
A.
INTRODUCTION ...........................................................................................................................................2
A.1.
A.2.
A.3.
A.4.
A.5.
B.
FAMILY OF COMPANIES ..................................................................................................................................2
INTEGRATED TRANSMISSION SYSTEM (ITS) ...................................................................................................2
PURPOSE .........................................................................................................................................................2
APPLICATION OF FCR DOCUMENT .................................................................................................................3
MAINTENANCE OF FCR DOCUMENT...............................................................................................................3
REQUIREMENTS ..........................................................................................................................................4
B.1. FAC-001-1, R3.1.1 PROCEDURES FOR COORDINATED JOINT STUDIES OF NEW FACILITIES AND THEIR
IMPACTS ON THE INTERCONNECTED TRANSMISSION SYSTEMS ...................................................................................4
B.2. FAC-001-1, R3.1.2 PROCEDURES FOR NOTIFICATION OF NEW OR MODIFIED FACILITIES TO OTHERS (THOSE
RESPONSIBLE FOR THE RELIABILITY OF THE INTERCONNECTED TRANSMISSION SYSTEMS) AS SOON AS FEASIBLE. ...... 5
B.3. FAC-001-1, R3.1.3 VOLTAGE LEVEL AND MW AND MVAR CAPACITY OR DEMAND AT POINT OF
CONNECTION. .............................................................................................................................................................7
B.4. FAC-001-1, R3.1.4 BREAKER DUTY AND SURGE PROTECTION ......................................................................9
B.5. FAC-001-1, R3.1.5 SYSTEM PROTECTION AND COORDINATION ....................................................................9
B.6. FAC-001-1, R3.1.6 METERING AND TELECOMMUNICATIONS ...................................................................... 11
B.7. FAC-001-1, R3.1.7 SYSTEM GROUNDING .................................................................................................... 13
B.8. FAC-001-1, R3.1.8 INSULATION AND INSULATION COORDINATION............................................................. 14
B.9. FAC-001-1, R3.1.9 VOLTAGE, REACTIVE POWER, AND POWER FACTOR CONTROL ..................................... 14
B.10.
FAC-001-1, R3.1.10 - POWER QUALITY IMPACTS .................................................................................... 17
B.11.
FAC-001-1, R3.1.11 EQUIPMENT RATINGS .............................................................................................. 19
B.12.
FAC-001-1, R3.1.12, SYNCHRONIZING OF FACILITIES ............................................................................. 21
B.13.
FAC-001-1, R3.1.13, MAINTENANCE COORDINATION ............................................................................. 21
B.14.
FAC-001-1, R3.1.14, OPERATIONAL ISSUES (ABNORMAL FREQUENCY AND VOLTAGES) ........................ 23
B.15.
FAC-001-1, R3.1.15, INSPECTION REQUIREMENTS FOR EXISTING OR NEW FACILITIES ........................... 24
B.16.
FAC-001-1, R3.1.16, COMMUNICATIONS AND PROCEDURES DURING NORMAL AND EMERGENCY
OPERATING CONDITIONS .......................................................................................................................................... 24
B.17.
PROVISIONS FOR FUTURE CHANGES ......................................................................................................... 25
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A. INTRODUCTION
A.1.
Family of Companies
Georgia Transmission Corporation (GTC) and Georgia System Operations Corporation (GSOC) were
formed out of Oglethorpe Power Corporation (OPC), created in 1974 to be the primary supplier of
electricity to 38 of the 41 Electric Membership Corporations (EMCs) throughout Georgia. In 1997
Oglethorpe Power Corporation implemented a comprehensive restructuring by moving from the
traditional vertically integrated organization to become 3 separate generation, transmission and system
operation entities. OPC provides the generation and asset management function. GTC owns and
maintains the EMC’s share of the Integrated Transmission System (ITS) and provides transmission
services. GSOC provides system operation support. GSOC economically operates the generation and
transmission assets of OPC and GTC, respectively while adhering to reliability standards of the North
American Electric Reliability Corporation (NERC) and the SERC Reliability Corporation (SERC).
A.2.
Integrated Transmission System (ITS)
To deliver the most cost-effective power to Georgia electric consumers, the state’s major electric
utilities participate in a unique statewide network called the ITS, which was formed in 1975. Participants
in the ITS include GTC, Georgia Power Company (GPC), MEAG Power (MEAG) and Dalton Utilities (DU).
The ITS participants share usage of their combined power transmission lines and substations that are
included in the ITS. The ITS is jointly planned by all four companies and is operated as one system. This
arrangement benefits customers by eliminating the costly duplication of transmission facilities.
A.3.
Purpose
This document defines the requirements for connecting new or modified transmission, generation, or
end user (load serving) facilities to the ITS. The requirements established in this document are intended
to ensure that facilities connected to the transmission grid do not have an adverse effect on reliability or
public safety and meet NERC/SERC standards. Within this document, the entity requesting
interconnection service is referred to as the “customer”.
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Connection requirements for facilities (generation, transmission, and end-user) not presently connected
and modifications of facilities already connected will be consistent in content and application to the
requirements used by the ITS.
It is recognized that while this document provides guidance on the technical issues that must be
considered, it should not be considered as an all-encompassing set of requirements. Specific projects
must be reviewed on an individual case by case basis. This document should not be considered as a
design specification manual and therefore all final designs are subject to the approval of GTC.
Further, this document only covers the technical requirements of connecting facilities to the system.
There is no attempt to address legal matters or liability issues.
Parties interested in accessing GTC and ITS procedures and guidelines referenced in this document may
contact GTC Bulk Planning manager.
A.4.
Application of FCR Document
The requirements set forth in this guide apply to the facilities of GTC as well as those of all other entities
who wish to interconnect new or modified generation, transmission, or end-use facilities to the ITS. It
applies only to facilities that are connected to the ITS at voltages 40 kV and above.
A.5.
Maintenance of FCR Document
This document is updated as needed. When changes occur to GTC procedures and guidelines, ITS
procedures and/or NERC and SERC standards, GTC conducts an assessment to determine if an update of
the FCR document is warranted. In addition GTC departments are requested to evaluate the need to
modify the FCR document on an annual basis. This process is documented in GTC’s facility connection
requirement update process (BP-022)
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B. Requirements
B.1.
FAC-001-1, R3.1.1 Procedures for Coordinated Joint Studies of New
Facilities and their Impacts on the Interconnected Transmission
Systems
GTC performs and coordinates joint studies of new facilities (generation, transmission and end-user) and
their impacts on the ITS. The following are studies performed by GTC and their corresponding study
processes:
- Regional Studies (BP-009 and BP-002) (Transmission and End-User Facilities)
- Area Studies (BP-001 and BP-002) (Transmission and End-User Facilities)
- System Impact Studies (BP-010) (Generation Facilities) and
- Facilities Studies (BP-006) (Generation Facilities)
Generation Facilities
System Impact Studies (SIS) are triggered in response to a Generation Interconnection Request (GI) or
Transmission Service Request (TSR). A SIS identifies the impact of the request on the ITS through
analyses such as stability, short circuit, closing angle, reactive requirement, power flow, interface, bus
ampacity and ground grid. The process includes an initial affected party meeting to discuss the study
scope and a second affected party meeting to discuss the study results and solutions with the ITS
members.
Facilities Studies (FS) are conducted subsequent to System Impact Studies. These studies identify in
detail the required system improvements including cost and lead time but also are an opportunity to
conduct further system impact analyses as necessary. GTC holds meetings with ITS members to discuss
the study results.
In the event of changes to study assumptions (including previously provided customer data) a new SIS
and/or FS may be initiated based on engineering judgment.
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Once the GI or TSR requestor signs an Interconnection Agreement with GTC or confirms the
Transmission Service Request, the generator data is submitted for inclusion into the base cases per the
Base Case Development Process (BP-002).
Transmission and End-User Facilities
GTC collaborates with the other ITS members throughout the study process. The base cases used to
perform the studies are jointly created and reviewed. In particular, collaboration on integrating new or
modified end-user and transmission facilities is achieved at this stage as described in the Base Case
Development process (BP-002).
Regional studies and Area studies are performed annually to identify thermal and voltage constraints in
each of GTC’s regions within the ITS for the near term (0-5 years) and long term (6-10 years). The study
process includes meetings among ITS members through the year to verify the base cases data, discuss
the system violations identified and propose solutions. Any identified solutions are re-evaluated every
year.
The prior mentioned studies (Regional Studies, Area Studies, System Impact Studies and Facilities
Studies) may indicate the need for system improvements such as construction of new transmission
facilities or modification of existing transmission facilities. If these improvements are to be
implemented, GTC uses the Capital Project Approval Process (BP-004) to review the projects internally
then solicit the ITS members approval. Once projects are approved they moved to the construction
phase.
B.2.
FAC-001-1, R3.1.2 Procedures for Notification of New or Modified
Facilities to Others (those responsible for the reliability of the
Interconnected Transmission Systems) as soon as feasible.
The following are GTC’s procedures for notification of new or modified generation, transmission and
end-user facilities to others (those responsible for the reliability of the interconnected transmission
systems) as soon as feasible:
Generation Facilities:
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Notification of new or modified generation facilities to external contacts and ITS participants is
performed through the following processes:

BP-010 System Impact Study Process

BP-006 Facilities Study Process

BP-005 Transmission Facilities Upgrades Process

BP-004 Capital Project Approval Process
GTC posts all received Generation Interconnections (GIs) and Firm Transmission Service Requests (TSRs)
on its OATI webOASIS portal: http://www.oatioasis.com/gtc/index.html.
Changes to the rated MW output or Point of Interconnection require submitting a new GI request. Either
Party (GTC or the generator owner) shall notify the other in advance of any changes in their respective
facilities, which reasonably can be expected to affect the proper coordination of protective devices of
either party. Should any changes occur to the customer interconnection facilities, GTC must be notified
and provided appropriate data to perform studies as needed.
Once a request moves to the System Impact Study phase, the BP-010 process ensures notification of ITS
participants of the study scope, analyses and results of the study.
At the Facilities Study stage, the BP-006 process ensures the external contacts and ITS participants
notification regarding the scope, analyses and results of the FS including project cost and timeline.
Should the project move forward, Transmission Facilities Upgrades Process (BP-005) and Capital Project
Approval Process (BP-004) identify how GTC notifies the ITS participants and obtains approval of the
associated capital projects.
Transmission and End-User Facilities
Notification of new or modified transmission or end -user facilities to external contacts and ITS
participants is performed through the following processes:

BP-001 Area Study Process

BP-009 Regional Study Process

BP-002 Base Case Development Process

BP-005 Transmission Facilities Upgrades Process

BP-004 Capital Project Approval Process
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ITS notification of new and modified end-user facilities to ITS members is performed through the Base
Case Development process (BP-002). The Regional Study, Area Study, Transmission Facilities Upgrades
and Capital Project Approval processes. A Regional or Area study may determine the need for a
transmission facility modification to address transmission system constraints. Notification of ITS
participants of such modifications is performed through the Transmission Facilities Upgrades Process
(BP-005) and Capital Project Approval Process (BP-004).
B.3.
FAC-001-1, R3.1.3 Voltage Level and MW and MVAR Capacity or
Demand at Point of Connection.
Generation Facilities
The generator shall have the capability to supply or absorb reactive power in accordance with Good
Utility Practice, ITS Planning and Operating Guidelines and Procedures (ITS Operating Procedure #23),
the generator’s Interconnection Agreement with GTC and applicable operational and/or reliability
criteria, protocols, and directives, including those of the Applicable Reliability Council and Applicable
Laws and Regulations and this Agreement
GTC requires the generators to meet design and operational requirements as described in NERC FAC-001
Reliability Standard and SERC Guideline for Facility Connection Requirements.
Design requirements include:

Load following capability

AGC

Reactive power output

Remote control functions

Coordination of generation control system settings

Load shedding

Black start capability

Dynamic stability and the use of power system stabilizers as appropriate

Internal plant systems design (e.g., transformer rating/taps/impedance, cooling systems,
generator/exciter rating) should not limit continuous reactive capability.

Transmission interconnected equipment should have the tap ranges and self-regulation
necessary to accommodate the transmission system's reactive power flow requirements.
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
Transmission interconnections should not have an impact on adjacent areas' voltage and
reactive power flow requirements
Operational requirements include:

Operation at 60Hz nominal

Mode of frequency control

Operation of generators during frequency decline conditions

Coordination between generator controls and under-frequency load shedding programs

Speed droop setting

Responsibility for coordination with the appropriate operating entity

Verification of reactive support capability per NERC Reliability Standards and corresponding
SERC documents

Generator step-up transformer (GSU) tap changes as necessary to meet voltage schedule and
reactive support requirements
The generator owner shall respond to requests from GTC to increase or decrease generator reactive
power output in a manner consistent with generator's obligation to operate and control the generation
facility. The generator facility shall supply or absorb such reactive power in accordance with the voltage
schedule or reactive levels prescribed by GTC but not in excess of the amount available from the
generation facility’s equipment in operation at the time and within the manufacturer’s design
limitations of the generation facility. ITS Operator shall provide the voltage schedule to the generator
owner/operator.
Transmission and End User Facilities
Transmission interconnected equipment should have the tap ranges and self-regulation necessary to
accommodate the transmission system's reactive power flow requirements.
Transmission interconnections should not have an impact on adjacent areas voltage and reactive power
flow requirements
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B.4.
FAC-001-1, R3.1.4 Breaker Duty and Surge Protection
Generation, Transmission and End-User Facilities
All interconnection facilities must meet or exceed the fault duty capability as determined through short
circuit analyses and should fully comply with the latest ANSI/IEEE standards for circuit breakers,
switchgear, substations, and fuses.
It is the responsibility of the generation interconnection customer and the transmission and load
interconnection customer to notify GTC of any changes in their facilities that may cause an increase in
fault currents.
Additional requirements for Generation Interconnection Customers
GTC requires the generation interconnection customers to meet the following design requirements
described in NERC Reliability Standard FAC-001 and SERC Guideline for Facility Connection
Requirements:

Each Party (GTC and customer) is responsible for the short circuit capabilities of their own
current carrying elements.

Each Party is responsible for the ratings of their own interrupting devices. It is the responsibility
of the customer to coordinate their relays and devices with the Transmission System Operator

Each Party shall supply the other existing and planned future fault current levels when
requested.
B.5.
FAC-001-1, R3.1.5 System Protection and Coordination
Generation, Transmission and End-User Facilities
The customer is responsible for providing a protection system that will protect its equipment against
disturbances on GTC’s system and minimize the effects of disturbances from the customer facilities on
GTC’s equipment and transmission system.
The "protection system" arrangement selected by the customer must be compatible with the protection
system used by GTC to protect the transmission grid. Compatibility will include protection philosophy,
operating speed, types of communication media (such as power line carrier or fiber optic) and
communication (carrier) frequency. GTC’s minimum protection requirements can be found in the ITS
Operating Procedure #5: ITS Protection System Philosophy.
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Transmission Facilities
Operating voltage and proximity to a generating unit will be a major consideration in the selection of the
primary and backup relay units that will be required for protecting a transmission line that connects to
the ITS. These considerations, in conjunction with the particular stability classification (critical or noncritical) determined during the facility tests, will determine the extent to which backup coverage is to be
incorporated in a transmission line's protection scheme.
Generation Facilities
The type, size, and location of the generation will determine the specific requirements. At the request of
the customer and prior to granting a generation interconnection, GTC conducts a System Impact Study
and Facilities Study to determine any ITS system protection and coordination requirements. During the
System Impact Study, the customer shall submit its protection scheme for review and approval by GTC.
The customer will be responsible for synchronizing its facility to GTC’s electrical system.
Anti-Islanding Requirements: Should the generator connect to a transmission line having other tapped
load, there may be an additional requirement to prevent islanding. For the purpose of this document,
islanding is defined as a generator being isolated such that it is the only source of power to a utility
customer.
Generation customer’s protection system should be responsible for sensing abnormal
frequency and tripping the customer’s own generator to isolate from GTC’s system.
End User Facilities
The End User is responsible for providing a protection system that will protect the End User equipment
against disturbances on GTC’s system and minimize the effects of disturbances from its facilities on
GTC’s equipment and transmission system. For facilities larger than 100 MW, the End User shall provide
GTC its planned protection system for GTC to review to ensure proper coordination of the protection
schemes.
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B.6.
FAC-001-1, R3.1.6 Metering and Telecommunications
Generation, Transmission and End-User Facilities
Telemetering and Metering (Communication)
A GTC supplied Data Concentrator and/or Remote Terminal Unit (RTU) will be required for gathering
customer load and transmission equipment status information that will be communicated back to the
GSOC Operations Control Center.
The customer will reimburse GTC for the required SCADA devices and GTC shall own and maintain these
devices. The Data Concentrator/RTU will have the ability to accept many standard protocols; however,
the GTC preference is DNP 3.0 with Level 2 compliance. It is the responsibility of the customer to
coordinate and provide the data in a protocol/interface that can be interfaced with the GTC SCADA
system. A point assignment sheet will be developed in coordination with the customer showing
expected data type and physical interface. It is the responsibility of the customer to ensure timely and
accurate translation of the data required and documented by the point assignment sheet.
Instantaneous voltage data plus bi-directional analog real power and reactive power flow information
must be telemetered directly to the location(s) specified by GTC. The customer will also provide the
dedicated data circuit(s) necessary to provide necessary customer data to GTC. The data circuit(s) shall
extend from generator’s facility to a location(s) specified by GTC.
The customer shall provide, at their expense, an Ethernet or MPLS data circuit dedicated for GTC’s use
and have, at a minimum, 1.5Mbps of committed information rate bandwidth and throughput.
The customer will provide standard voice and facsimile communications at its facility control room
through use of the public telephone system
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Typical data requirements include the following:

Status of interrupting devices

MW flow

MVAR flow

Amps – three phase and per phase

Power factor

Voltage at interconnection point
Telemetering and Metering (Billing)
GTC shall specify, own, and maintain all meters and metering devices (including RTUs) used to measure
the delivery and receipt of energy for payment purposes. The revenue metering package consists of a
primary revenue meter and a secondary revenue meter as a backup. The secondary revenue meter will
be polled in case of failure of the primary revenue meter and utilized for billing purposes. If both meters
should fail, GTC will use a metering translation process to determine the usage. Meter accuracy will be
maintained within +/- 0.3%. Primary meters in service are tested by GTC on an annual basis, or as
requested by the ITS or any other lawfully constituted authority having jurisdiction over meter accuracy.
A fiber optic interface, for the purpose of communications between GTC’s metering equipment, RTU,
and MPLS communication access shall be provided by the customer at their expense.
The customer shall provide, at their expense, an extension of the GSOC Operations Control Center's PBX
system in the control room of the customer for purposes of generation scheduling and/or coordination
of switching.
In addition, GTC shall specify, own, and maintain at customer expense any additional equipment or
materials deemed necessary by GTC to protect the aforementioned Telemetering and Metering
equipment from cyber/physical threats or comply with NERC or other security standards.
At a minimum, generator and load metering data requirements shall include the following:

kW

kWh
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
kVAr, leading and lagging

kVAr-hour

kV 2 -hour

Voltage (to monitor voltage schedule compliance)

Automatic Voltage Regulation Status

Power System Stabilizer Status if applicable

Status of interrupting and/or syncing devices
GTC will provide kW and kVAr data pulses to the customer upon request if technically feasible.
Additional equipment and network connections may be required to be purchased by the customer. The
preferred method of data transfer is digitally via serial port from the meter or a solid state pulse
initiator.
All revenue metering instrument transformers installed shall be of metering class, dedicated solely for
revenue metering, and must be strictly in accordance with the latest version of IEEE Standard C57.13
and, if applicable, ANSI Standard C93.1. Metering cables shall be connected directly between the
secondary posts and the GTC Revenue Meter Test Switch with no breaks. All such connections shall be
inspected by GTC ECS personnel for accuracy prior to being energized.
B.7.
FAC-001-1, R3.1.7 System Grounding
Generation, Transmission and End-User Facilities
The interconnecting facility shall have its own independent ground grid if the facility is outside of the
GTC substation fence. When the GTC substation and the interconnecting facility are adjacent to each
other, the grids shall be connected together. The specifics for coordination of the interties between
ground grids are discussed at pre-design meetings. The ground grid to be interconnected with the GTC
ground grid shall be of compatible design.
The substation grounding system in general shall provide for personnel safety and enable coordinated
system protection.
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When the interconnecting facility is within the GTC substation fence, the interconnecting facility will be
incorporated into the design and construction of the GTC ground grid.
The substation grounding design standards can be found in the ITS Operating Procedure #7: ITS
Substation Design Standard. The transmission line grounding criteria can be found in the ITS Operating
Procedure #13: ITS Overheard Line Design Standards.
B.8.
FAC-001-1, R3.1.8 Insulation and Insulation Coordination
Generation, Transmission and End-User Facilities
The insulation coordination must be done properly to ensure electrical system reliability and personnel
safety. Basic Surge Levels (BSLs), surge arrester, conductor spacing and gap application, substation and
transmission line insulation strength, protection, and shielding shall be documented and submitted for
evaluation as part of the interconnection plan.
GTC’s standard is to shield substations and transmission lines from direct lightning strokes. Surge
arresters are also applied at major components and systems.
Interconnection facilities to be constructed in areas with contamination shall be properly designed to
meet or exceed the performance of facilities not in a contamination area with regard to contamination
caused outages.
Additional information can be found in the following ITS procedures:
B.9.
•
ITS Operating Procedure #7: ITS Substation Design Standard.
•
ITS Operating Procedure #13: ITS Overheard Line Design Standards.
FAC-001-1, R3.1.9 Voltage, Reactive Power, and Power Factor
Control
Generation, Transmission and End-User Facilities
GTC requires generators to meet the following design and operational requirements described in NERC
Reliability Standard FAC-001 and SERC Guideline for Facility Connection Requirements.
Design requirements include the following:

The internal plant electrical system design (e.g., transformers, tap settings, motors & other
loads, generator/exciter, voltage regulator) should not restrict any mode of project operation
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within ITS voltage range and regulation. Anytime the generator plans to replace any of the stepup or auxiliary transformers, the generator shall supply data related to the transformer (e.g. size
and type, available tap settings, impedance data, loss data etc.) to GTC for the purpose of
determining the optimum tap setting via reactive requirement study. When tap changes are
necessary, GTC shall provide the generator with a report that justifies the required tap setting
changes and technical justification for these changes.

Transmission interconnected equipment should have the tap ranges and self-regulation
necessary to operate within the ITS voltage range. Generator step-up and auxiliary transformers
shall have their tap settings coordinated to meet the ITS voltage requirements.

Voltage regulator load compensation, if required, to control voltage at a point beyond the
generator terminals.

Voltage regulator droop compensation, if required, for generators whose terminals are directly
connected (i.e., cross-compound, hydro)

Coordination of excitation system settings with GTC.

Transmission interconnection impact on adjacent areas' voltage or reactive compensation
devices.
The following operational requirements must be adhered to:

Load and/or generation operation to be within the acceptable voltage range and regulation as
specified by GTC. The interconnection shall not result in any condition where the voltage
excursion shall exceed NERC, SERC, ITS or GTC requirements. ITS acceptable voltage level ranges
can be found in the ITS Planning Procedure #9.

Generator voltage regulator to be operated in automatic modes. A generator voltage regulator
is required to be in service and in automatic mode whenever the generator is synchronized to
the system. Unless otherwise directed by GSOC operations center, the automatic voltage
regulator shall control the voltage output within the reactive capabilities of the generator to
maintain the nominal voltage of the connected transmission system.

Generator to maintain voltage schedules on transmission as required by the ITS Operator.
Generators connected directly to GTC’s transmission system operate in automatic voltage
regulation.

Any reactive compensation devices to be coordinated with GTC.
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Generation Facilities
Voltage Schedule
GTC requires all generator owners/operators to keep detailed records as to when each on-line operating
generating unit is not in automatic voltage control mode. The generator owner/operator shall be
responsible for providing detailed reports on voltage deviations from the acceptable voltage ranges and
summary report for a specified time period when requested by GTC, the respective NERC region or NERC
(within 30 business days of the request).
Power Factor
Unless otherwise agreed, the generator is required to maintain a power factor within the same range as
GTC pursuant to Good Utility Practices. Power factor limits are described in ITS Planning and Operating
Guidelines and Procedures (ITS Operating Procedure #23), and the generator’s Interconnection
Agreement.
Reactive Power
Generator shall supply reactive power to or absorb reactive power from the ITS in accordance with
Good Utility Practice, ITS Planning and Operating Guidelines and Procedures (ITS Operating Procedure
#23), the generator’s Interconnection Agreement, applicable operational and/or reliability criteria,
protocols, and directives, including those of the Applicable Reliability Council and Applicable Laws and
Regulations and this Agreement. Generator shall respond to requests from GTC to increase or decrease
generator reactive power output in a manner consistent with the generator's obligation to operate and
control the facility. The generator facility shall supply or absorb such reactive power in accordance with
the voltage schedule or reactive levels prescribed by GTC but not in excess of the amount available from
the facility’s equipment in operation at the time and within the manufacturer’s design limitations of the
facility. ITS Operator shall provide the voltage schedule to the generator owner/operator.
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End User Facilities
Power Factor
All transmission load customers are required to maintain a power factor within the same range as GTC
pursuant to Good Utility Practices. The End User facilities shall maintain a minimum power factor of
97.3% (lagging) at transmission level delivery points or as specified in the Service Agreement where
applicable.
B.10.
FAC-001-1, R3.1.10 - Power Quality Impacts
Generation, Transmission and End-User Facilities
Any interconnection of a generator, transmission or end user facility to the ITS should not compromise
or degrade the power quality of the ITS or its existing customers. The connection facility shall also meet
any FERC, NERC or SERC reporting and reliability standards.
Power quality may include but not be limited to the following:

Voltage Unbalance

Voltage Flicker

Voltage Fluctuation

Harmonic Distortion

Transient over voltage

Temporary over voltage

Temporary under voltage

Operating frequency

Power factor range

Interruption / Outage frequency as may be required by regulatory standards
A permanent digital fault recorder and/or other monitoring equipment (Power Quality Meter) may be
deemed necessary and installed by the transmission owner at the Point of Common Coupling to ensure
that Power Quality standards are met and maintained, and Power Quality events are captured and
measured.
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Frequency Control
A speed governor system is required on all generators with a net output greater than 20 MW to regulate
the output of the generator as a function of the system frequency. The speed governor system must
respond to system frequency changes to help maintain the stability of the power system. The speed
governor system shall have a speed regulation (droop) characteristic settable between three and seven
percent and typically be set at five percent.
Temporary Over/Under Voltage
Assuming that temporary is longer than 5 to 10 seconds, then the SCADA scan rate of 2-6 seconds will
capture appropriate changes.
GTC measures voltage via SCADA at appropriate delivery points (load and generation). Two alarm levels
are in place for both high and low voltage. The GSOC Control Center is staffed 24/7/365 and responds
as needed to the mentioned alarms. Both GSOC and GPC Control Centers will alter system configuration
as needed to control and maintain the voltage consistent with Table 1 of Section 1.10.
Assuming temporary is less than 2-3 seconds or even less than a second:
GTC has DFRs that will record the duration and magnitude of the abnormalities. GTC will study specific
cases upon request and rectify the situation.
Power Factor Range
End User facilities: The ITS maintains an overall load power factor of 0.93 at the system peak with a
minimum power factor of 97.3 lagging.
Generators: Unless exempt, Generators connected to the ITS are required to maintain a voltage
schedule as determined in the System Impact and/or Facilities Studies.
Flicker Requirements
Flicker will be assessed at the Point of Common Coupling (PCC) using an instrument in compliance with
IEC 61000-4-15 (IEEE Std. 1453-2004), except that the weighting curve used to represent the response of
the light bulb shall be based on the 120 volt lamp characteristics as recommended in UIE 96-10.
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The flicker measured at the PCC shall be 0.8 or less for the short-term flicker (Pst) and 0.6 or less for the
long- term Flicker (Plt). The Pst and Plt values measured shall not be exceeded more than 1% of the
time based on a probability distribution calculated for a one-week period.
Harmonic and Inter-Harmonic Requirements
Harmonic levels will be assessed at the PCC with an instrument that can take individual samples of
voltage and current waveforms and determine the probability distribution of the individual harmonic
levels for both the current and the voltage.
Harmonic distortion levels at the PCC shall meet the current requirements of IEEE Standard 519 with
respect to the harmonic current components. Background harmonic voltage distortion levels at the PCC
should be in compliance with the recommendations in IEEE 519
In addition, the individual inter-harmonic currents shall be limited to 25% of the values in IEEE 519 and
the THD calculation shall include the inter-harmonic components.
The Inter-harmonics shall be
calculated in 10 Hz increments. The current distortion levels specified in IEEE 519 shall not be exceeded
by more than 5% of the time based on a probability distribution calculated for a one-week period.
If a transmission outage occurs that does not separate the generation from the transmission system,
then a second method of synchronization is used that will allow automatic reclosing relays to reconnect,
the control scheme initiates a close only after a synchro-verifier relay determines that the angle and
voltage are within preset limits.
B.11.
FAC-001-1, R3.1.11 Equipment Ratings
Generation, Transmission and End-User Facilities
All current carrying equipment and devices shall be designed to carry the maximum loads that are
projected and used in load flow analysis. Facility loadings exceeding “nameplate” or “normal” design
capacities are only acceptable when allowed by manufacturers design documentation or standard
industry practices.
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GTC shall have the right to review customer design and specifications to verify that equipment ratings
are consistent with GTC criteria.
GTC’s methodology for determining facility and equipment ratings is discussed in GTC’s “Facility Rating
Methodology” document.
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B.12.
FAC-001-1, R3.1.12, Synchronizing of Facilities
Generation, Transmission and End-User Facilities
Transmission breakers are closed to connect two energized lines only after the phase angle across the
breaker is verified. This is accomplished by one of two methods. In the first method, manual closing
utilizes a sync permissive switch. The switch must be turned on to allow breaker closing. Turning on the
switch energizes a synchroscope, which shows the phase angle between the lines to be tied together.
This method requires the Operator to determine that the angle is within limits. The customer shall be
responsible for the synchronization of generation with the transmission system.
If a transmission outage occurs that does not separate the generation from the transmission system,
then a second method of synchronization is used that will allow automatic reclosing relays to reconnect, the control scheme initiates a close only after a synchro-verifier relay determines that the
angle and voltage are within preset limits.
B.13.
FAC-001-1, R3.1.13, Maintenance Coordination
Generation, Transmission and End-User Facilities
GTC shall have the right, but shall have no obligation or responsibility to
I. Observe generator's tests and/or inspection of any of generator's system protection facilities
and other protective equipment,
II. Review the settings of generator's system protection facilities and other protective equipment,
and
III. Review generator's maintenance records relative to the facility, generator interconnection
facilities, and/or generator's system protection facilities and other protective equipment.
GTC shall maintain its facilities and equipment, to the extent they might reasonably be expected to have
an impact on the operation of the facility (ies) in a safe and reliable manner, in accordance with Good
Utility Practice and in accordance with the provisions of this document. The generator shall maintain its
facilities and equipment, to the extent they might reasonably be expected to have an impact on the
operation of the transmission system and GTC’s systems in a safe and reliable manner, in accordance
with Good Utility Practice and in accordance with the provisions of this Agreement.
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Maintenance requirements are also covered in the General Requirements section of this document.
Complete, precise, and timely communication is an essential element for maintaining reliability and
security of a power system. Under normal operating conditions, the major link of communication with
various interconnects shall be by telephone lines.
GTC and the customer shall maintain communications which shall include, but not be limited to, system
paralleling or separation, scheduled or unscheduled shutdowns, equipment clearances, periodic load
reports, maintenance schedules, tagging of interconnection interrupting devices, meter tests, relay
tests, billing, and other routine communication.
The Parties shall coordinate inspections, planned outages, and maintenance of their respective
equipment, facilities and systems so as to minimize the impact on the availability, reliability and security
of both Parties’ systems and operations.
Each Party shall provide the other with reasonable notification for routine maintenance, operational
tests, inspection activities and Revenue Meter tests. For such activities that do not require major
equipment or system outages, the Party performing the maintenance shall provide the other Party with
at least twenty-four (24) hours prior written notice.
For such activities that will require major
equipment or system outages, the Party performing the maintenance shall provide the other Party with
not less than five business days prior written notice. All transmission switching will be done through
GSOC and GPC Control Centers for scheduled and unscheduled maintenance.
Maintenance Requirements
The customer shall be responsible for the design, construction, installation, maintenance and
synchronization of generation with the transmission system and ownership of all interconnection
facilities located on its side of the Interconnection Points. GTC shall be responsible for the design,
construction, installation, maintenance, and ownership of all interconnection facilities located on GTC’s
side and revenue metering equipment located on the customer’s side of the Interconnection Points.
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In order to perform certain maintenance, testing, and repair activities, GTC’s transmission line(s) must
be de-energized. Under this condition, station service power may be interrupted to the customer. GTC
will require periodic transmission line(s) outages to perform protective relay maintenance. GTC will
coordinate protective system checks during these outages with the customer.
GTC’s circuit breaker(s) are required to be opened periodically in order to exercise the breaker
mechanism. In instances where the breaker has not been operated for an extended period, GTC may
manually operate the breaker. GTC will coordinate this and any other circuit breaker maintenance with
the customer.
GTC or the customer may request, from time to time, routine switching of each other’s equipment. In
such cases, GTC and the customer will provide reasonable notice to the other Party of any equipment
switching that affects electrical service to the other Party.
B.14.
FAC-001-1, R3.1.14, Operational Issues (Abnormal Frequency and
Voltages)
Generation, Transmission and End-User Facilities
When a customer desires to interconnect a generating, transmission or load-serving facility to the
Integrated Transmission System (ITS) through a GTC facility, the general protection settings must be
submitted to GTC for review. GTC reviews and ensures that the proper coordination between GTC and
customer protection exists.
GTC also ensures that customer frequency protection meets GTC
requirements and that the proper metering is in place to monitor abnormal voltage conditions.
GTC requires its interconnection customers to meet the design requirements described in NERC FAC-001
Planning Standard and SERC Guideline for Facility Connection Requirements:
Design requirements that should be addressed include:

Consideration for abnormal voltage conditions

Consideration for abnormal frequency conditions

Consideration for generators connected through a tapped transmission line (e.g., islanding)

Relay coordination to maintain stability

Load shedding implementation
Operational requirements that should be addressed include:
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
Provisions for abnormal voltage conditions

Provisions for abnormal frequency conditions

Provisions for load shedding

Special procedures for coordination
B.15.
FAC-001-1, R3.1.15, Inspection Requirements for Existing or New
Facilities
Generation, Transmission and End-User Facilities
Each Party shall perform routine inspection and testing of its facilities and equipment, including
secondary low voltage control systems, in accordance with Good Utility Practice as may be necessary to
ensure the continued interconnection of the facility with ITS in a safe and reliable manner.
Each Party shall, at its own expense, have the right to observe the testing of any of the other Party’s
facilities and equipment whose performance may reasonably be expected to affect the reliability of the
observing Party’s facilities and equipment.
Each Party shall notify the other Party in advance of performing tests on its own facilities and
equipment, and the other Party may have a representative attend and be present during such testing.
If a Party observes any deficiencies or defects on, or becomes aware of a lack of scheduled maintenance
and testing with respect to, the other Party’s facilities and equipment that might reasonably be
expected to adversely affect the observing Party’s facilities and equipment, the observing Party shall
provide notice to the other Party that is prompt under the circumstance, and the other Party shall make
any corrections required in accordance with Good Utility Practice.
B.16.
FAC-001-1, R3.1.16, Communications and Procedures during Normal
and Emergency Operating Conditions
Generation, Transmission and End-User Facilities
Complete, precise, and timely communication is an essential element for maintaining reliability and
security of a power system. The Parties shall establish a point of contact that shall have the authority
and capability to operate customer facilities according to the instructions of GTC or the appropriate
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operating entity. Under normal operating conditions, the major link of communication with various
interconnects shall be by telephone lines. The Parties shall maintain communications which shall
include, but not be limited to, system paralleling or separation, scheduled or unscheduled shutdowns,
equipment clearances, periodic load reports, maintenance schedules, tagging of interconnection
interrupting devices, meter tests, relay tests, billing, and other routine communication. All customers
who are interconnecting generation facilities shall have provisions to obtain approval from Georgia
System Operations Corporation (GSOC) prior to starting generation and connecting it to the
transmission system. All customers who are interconnecting transmission facilities shall have provisions
to obtain proper clearances from Georgia System Operator prior to commencing work on the customer
facility. Emergency telephone numbers must be agreed upon by both parties prior to the actual connect
date.
B.17.
Provisions for Future Changes
Either Party shall notify the other in advance of any changes in their respective facilities, which
reasonably can be expected to affect the proper coordination of protective devices of either party.
Should any changes occur to customer interconnection facility, GTC must be notified and provided
appropriate data to perform studies as needed.
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