HomeMy WebLinkAbout09272010 City Council Packet/R10-093 Backup,- K � 0 - 1 ) — F6 P�r� o �>
The Managers of the Railbelt Utilities have formed and requested an Ad -Hoc Reliability
Group to develop standards to better emulate national utility practices and to provide
direction to the Railbelt Utilities on how to cooperatively operate their systems for the
betterment of the interconnected electrical system. The Group has drafted these
standards giving careful consideration to the many technical and operational issues
involved with interconnecting entities to the Alaska Railbelt Electrical System (also
referred to as the "Railbelt Interconnection" or "The System ") and with five overarching
goals:
• First, these standards set the minimum requirements for interconnection to The
System; serving utilities may have additional or more stringent interconnection
standards.
• Second, to the extent practical, these interconnection standards should be
performance based rather than requirements based.
• Third, to the extent practical, interconnecting entities should not be allowed to
degrade the performance or reliability of The System. Such degradation in
performance shall be determined by modeling the Railbelt Electrical System using
the boundary dispatch cases against all N -I and probable N -2 contingencies.
• Fourth, interconnecting entities should not be required to build or improve
System facilities beyond those necessary to meet the third overarching goal
(above).
• Fifth, the interconnecting entity, as a condition of interconnection, shall abide by
all other applicable Railbelt standards as they may be modified or implemented
from time to time.
Given the complex and technical nature of the subject, the authors have worked diligently
to maintain a high level of clarity throughout this document, in order to meet the needs of
the participants, but they recognize that these standards are often based upon highly
technical subject matter. To aid in understanding and implementing these requirements
and criteria, the Intertie Management Committee will require potential entities to obtain
the assistance of qualified engineering professionals with specific expertise in the areas of
electrical supply systems, power system analysis and protection as well as control. Such
professionals must have demonstrated experience in modeling, designing, constructing,
commissioning and operating facilities on small stability - limited interconnections.
These guidelines are subject to revision, at any time, at the discretion of the Ad -Hoc
Railbelt Operating Guidelines Committee or the Intertie Management Committee (as
defined in the Railbelt Operating Standards). This document is not intended to be a
design specification.
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Each Entity desiring to interconnect to the Railbelt System must,fill out an Entity
Function Matrix (shown below) checking off the functions which they believe they
perform. This document will be kept by the Intertie Management Committee and in part
is used to determine its obligations as well as what areas it may participate in. Vertically
integrated Utilities may find themselves participating in most, if not all categories.
Entity Function
Balancing Authority
Compliance Enforcement Authority
Distribution Provider
Generator Operator
Generator Owner
Interchange Authority
Load - Serving Entity
Market Operator (Resource Integrator)
Reliability Coordinator
Planning Coordinator
Purchasing - Selling Entity
Reliability Assurer
Resource Planner
Standards Developer
Transmission Operator
Transmission Owner
Transmission Planner
Transmission Service Provider
Sanctions Matrix for Non Compliance
Number of Occurrences at a Given Level within Specified Period
Level of Non-
1
2
3
4 or more
Compliance
Level 1
Letter (A)
Letter (B)
Higher of $1000
Higher of $2000
or $10 per MW
or $20 per MW
of Sanction
of Sanction
Measure
Measure
Level 2
Letter (B)
Higher of $1000
Higher of $2000
Higher of $4000
or $10 per MW
or $20 per MW
or $40 per MW
of Sanction
of Sanction
of Sanction
Measure
Measure
Measure
Level 3
Higher of $1000
Higher of $2000
Higher of $4000
Higher of $6000
or $10 per MW
or $20 per MW
or $40 per MW
or $60 per MW
of Sanction
of Sanction
of Sanction
of Sanction
Measure
Measure
Measure
Measure
Level 4
Higher of $2000
Higher of $4000
Higher of $6000
Higher of
or $20 per MW
or $40 per MW
or $60 per MW
$10,000 or $100
of Sanction
of Sanction
of Sanction
per MW of
Measure
Measure
Measure
Sanction
Measure
Alaskan Railbelt Standard AKBAL -001 -0 — Real Power Balancing Control Performance
A. Introduction
1. Title: Real Power Balancing Control Performance
2. Number: AKBAL -001 -0
3. Purpose: To maintain Interconnection steady -state frequency within defined limits by
balancing real power demand and supply in real -time.
4. Applicability:
4.1. Balancing Authorities
5. Effective Date: TBD
B. Requirements
R1. Each Balancing Authority shall operate such that, on a rolling 12 -month basis, the average of
the clock - minute averages of the Balancing Authority's Area Control Error (ACE) divided by
lOB (B is the clock- minute average of the Balancing Authority Area's Frequency Bias) times
the corresponding clock- minute averages of the Interconnection's Frequency Error is less than
a specific limit. This limit F-i is a constant derived from a targeted frequency bound
(separately calculated for each Interconnection) that is reviewed and set as necessary by the
Intertie Management Committee.
AVGPeriod ACE;
[( ACE,.
AVGPer;od _ IOB. AF, ; or 2 IOBj < 1
,
The equation for ACE is:
ACE = (NI — NI — IOB (F — Fs) — IME
where:
• NI is the algebraic sum of actual flows on all tie lines.
• NI is the algebraic sum of scheduled flows on all tie lines.
• B is the Frequency Bias Setting (MW /0.1 Hz) for the Balancing Authority. The
constant factor 10 converts the frequency setting to MW/Hz.
• F is the actual frequency.
• F is the scheduled frequency. F is normally 60 Hz but may be offset to effect
manual time error corrections.
• I is the meter error correction factor typically estimated from the difference between
the integrated hourly average of the net tie line flows (NI and the hourly net
interchange demand measurement (megawatt- hour). This term should normally be
very small or zero.
R2. Each Balancing Authority shall operate such that its average ACE for at least 90% of clock -
ten- minute periods (6 non - overlapping periods per hour) during a calendar month is within a
specific limit, referred to as L,
1 of 7
Effective Date: TBD
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Alaskan Railbelt Standard AKBAL -001 -0 — Real Power Balancing Control Performance
sampling cycles in clock- minute
clock- minute
n sampling cycles in clock- minute
The Balancing Authority's clock- minute compliance factor (CF) becomes:
_
[( ACE
C F clock- minute _ I OB clock- minute
clock- minute
Normally, sixty (60) clock- minute averages of the reporting Balancing Authority's ACE and of
the respective Interconnection's Frequency Error will be used to compute the respective hourly
average compliance parameter.
_ I CF clock- minute
CF clock -hour
n clock- minute samples in hour
The reporting Balancing Authority shall be able to recalculate and store each of the respective
clock -hour averages (CF clock -hour average- month) as well as the respective number of
samples for each of the twenty -four (24) hours (one for each clock -hour, i.e., hour - ending (HE)
0100, HE 0200, ..., HE 2400).
I [(CFclock -hour )( minute samples in clock -hour
_ days -in -month
CF clock -hour average -month
n one- minute samples in clock -hour
days -in month
[( -hour average -month )( minute samples in clock -hour averages A
_ hours -in -day
CF month
J n one- minute samples in clock -hour averages
hours -in day
The 12 -month compliance factor becomes:
12
( -i )( minute samples in month ) —i
CF l2 -month
�j [ minute samples in month) -i
i =1
In order to ensure that the average ACE and Frequency Deviation calculated for any one-
minute interval is representative of that one - minute interval, it is necessary that at least 50% of
both ACE and Frequency Deviation samples during that one - minute interval be present.
Should a sustained interruption in the recording of ACE or Frequency Deviation due to loss of
telemetering or computer unavailability result in a one - minute interval not containing at least
50% of samples of both ACE and Frequency Deviation, that one - minute interval shall be
excluded from the calculation of CPS 1.
M2. Each Balancing Authority shall achieve, as a minimum, Requirement R2 (CPS2) compliance of
90 %. CPS2 relates to a bound on the ten- minute average of ACE. A compliance percentage is
calculated as follows:
3 of 7
Effective Date: TBD
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Alaskan Railbelt Standard AKBAL -001 -0 — Real Power Balancing Control Performance
1.4. Additional Compliance Information
None.
2. Levels of Non - Compliance — CPS1
2.1. Level 1: The Balancing Authority Area's value of CPS is less than 100% but
greater than or equal to 95 %.
2.2. Level 2: The Balancing Authority Area's value of CPS is less than 95% but
greater than or equal to 90 %.
2.3. Level 3: The Balancing Authority Area's value of CPS is less than 90% but
greater than or equal to 85 %.
2.4. Level 4: The Balancing Authority Area's value of CPS I is less than 85 %.
3. Levels of Non - Compliance — CPS2
3.1. Level 1: The Balancing Authority Area's value of CPS2 is less than 90% but
greater than or equal to 85 %.
3.2. Level 2: The Balancing Authority Area's value of CPS2 is less than 85% but
greater than or equal to 80 %.
3.3. Level 3: The Balancing Authority Area's value of CPS2 is less than 80% but
greater than or equal to 75 %.
3.4. Level 4: The Balancing Authority Area's value of CPS2 is less than 75 %.
5 of 7
Effective Date: TBD
E. Regional Differences
Version History
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Alaskan Railbelt Standard AKBAL -001 -0 — Real Power Balanci
Power System Disturbances and Contingency Response
Chapter 3
Spinning Reserve
(X% of Contingency Reserve)
Contingency
Reserve
Operating Non - spinning (supplemental)
Reserve reserve
Real -time total I I
guncraun Regulating Reserve
fpIIgwin&the mosI
Native Load severe single
plus confirrgency
Capacity Sales
Figure 4. Operating Reserve
56
Control Performance
7 of 7
Effective Date: TBD
Alaska Standard AKBAL -002 -0 — Disturbance Control Performance
Introduction
1. Title: Disturbance Control Performance
2. Number: AKBAL -002 -0
3. Purpose:
The purpose of the Disturbance Control Standard (DCS) is to ensure the Balancing Authority
is able to utilize its Contingency Reserve to balance resources and demand and return
Interconnection frequency within defined limits following a Reportable Disturbance. Because
generator failures are far more common than significant losses of load and because
Contingency Reserve activation does not typically apply to the loss of load, the application of
DCS is limited to the loss of supply and does not apply to the loss of load.
4. Applicability:
4.1. Balancing Authorities
4.2. Reserve Sharing Groups (Balancing Authorities may meet the requirements of
Standard 002 through participation in a Reserve Sharing Group.)
4.3. Regional Reliability Organizations
5. Effective Date:
B. Requirements
Rl. Each Balancing Authority shall have access to and/or operate Contingency Reserve to respond
to Disturbances. Contingency Reserve may be supplied from generation, energy storage
systems, loadshed, controllable load resources, other devices, or coordinated adjustments to
Interchange Schedules.
R1.1. A Balancing Authority may elect to fulfill its Contingency Reserve obligations by
participating as a member of a Reserve Sharing Group. In such cases, the Reserve
Sharing Group shall have the same responsibilities and obligations as each Balancing
Authority with respect to monitoring and meeting the requirements of Standard BAL-
002.
R2. Each Regional Reliability Organization, sub - Regional Reliability Organization or Reserve
Sharing Group shall specify its Contingency Reserve policies, including:
R2.1. The minimum reserve requirement for the group, as determined by coordinated
Railbelt UP loadshed/spinning reserve /droop coordination study
R2.2. Its allocation among members, as defined in the Reserve Policy, and as modified by
coordinated Railbelt OF loadshed/spinning reserve /droop coordination studies.
R2.3. The permissible mix of Operating Reserve — Spinning and Operating Reserve —
Supplemental that may be included in Contingency Reserve.
R2.4. The procedure for applying Contingency Reserve in practice including
recommendations on geographic dispersion.
R2.5. The limitations, if any, upon the amount of interruptible load that may be included.
R2.6. The same portion of resource capacity (e.g. reserves from jointly owned generation)
shall not be counted more than once as Contingency Reserve by multiple Balancing
Authorities.
1 of 7
Effective Date: TBD
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Alaska Standard AKBAL -002 -0 — Disturbance Control Performance
Ml. A Balancing Authority or Reserve Sharing Group shall calculate and report compliance with
the Disturbance Control Standard for all Disturbances involving all generating unit trips,
transmission line trips, and distribution level disturbances that result in frequency deviation
>.2 Hz. Regions may, at their discretion, require a lower reporting threshold. Disturbance
Control Standard is measured as the percentage recovery (R).
3 of 7
Effective Date: TBD
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Alaska Standard AKBAL -002 -0 — Disturbance Control Performance
The average percent recovery is the arithmetic average of all the calculated R for Reportable
Disturbances during a given quarter. Average percent recovery is similarly calculated for
excludable Disturbances.
D. Compliance
1. Compliance Monitoring Process
Compliance with the DCS shall be measured on a percentage basis as set forth in the measures
above.
Each Balancing Authority or Reserve Sharing Group shall submit one completed copy of DCS
Form, "Alaskan Railbelt Control Performance Standard Survey — All Interconnections" to its
Resources Subcommittee Survey Contact no later than the 10th day following the end of the
calendar quarter (i.e. April 10th, July 10th, October 10th, January 10th).
1.1. Compliance Monitoring Responsibility
Regional Reliability Organization.
1.2. Compliance Monitoring Period and Reset Timeframe
Compliance for DCS will be evaluated for each reporting period. Reset is one calendar
quarter without a violation.
1.3. Data Retention
The data that support the calculation of DCS are to be retained in electronic form for at
least a one -year period. If the DCS data for a Reserve Sharing Group and Balancing
Area are undergoing a review to address a question that has been raised regarding the
data, the data are to be saved beyond the normal retention period until the question is
formally resolved.
1.4. Additional Compliance Information
Reportable Disturbances — Reportable Disturbances are contingencies involving any
generating unit trips, transmission line trips, and distribution level disturbances that
result in frequency deviation >.2 Hz. . A Regional Reliability Organization, sub -
Regional Reliability Organization or Reserve Sharing Group may optionally reduce
this criteria, provided that normal operating characteristics are not being considered or
misrepresented as contingencies. Normal operating characteristics are excluded
because DCS only measures the recovery from sudden, unanticipated losses of supply -
side resources.
Simultaneous Contingencies — Multiple Contingencies occurring within one minute
or less of each other shall be treated as a single Contingency. If a multiple contingency
event occurs within a time span greater than one minute the regional reliability
organization will have at its discretion the option to consider it a single contingency.
If the combined magnitude of the multiple Contingencies exceeds the most severe
single Contingency, the loss shall be reported, but excluded from compliance
evaluation.
Multiple Contingencies within the Reportable Disturbance Period — Additional
Contingencies that occur after one minute of the start of a Reportable Disturbance but
before the end of the Disturbance Recovery Period can be excluded from evaluation.
The Balancing Authority or Reserve Sharing Group shall determine the DCS
compliance of the initial Reportable Disturbance by performing a reasonable
5 of 7
Effective Date: TBD
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Alaska Standard AKBAL -002 -0 — Disturbance Con Performance
Version History
7 of 7
Effective Date: TBD
Alaska Standard AKBAL -003 -0 — Frequency Response and Bias
A. Introduction
1. Title: Frequency Response and Bias
2. Number: AKBAL -003 -0
3. Purpose:
This standard provides a consistent method for calculating the Frequency Bias component of
ACE.
4. Applicability:
4.1. Balancing Authorities
5. Effective Date:
B. Requirements
Rl. Each Balancing Authority shall review its Frequency Bias Settings by January 1 of each year
and recalculate its setting to reflect any change in the Frequency Response of the Balancing
Authority Area.
R1.1. The Balancing Authority may change its Frequency Bias Setting, and the method used
to determine the setting, whenever any of the factors used to determine the current bias
value change.
R1.2. Each Balancing Authority shall report its Frequency Bias Setting, and method for
determining that setting, to the Intertie Management Committee.
R2. Each Balancing Authority shall establish and maintain a Frequency Bias Setting that is as
close as practical to, or greater than, the Balancing Authority's Frequency Response.
Frequency Bias may be calculated several ways:
R2.1. The Balancing Authority may use a fixed Frequency Bias value which is based on a
fixed, straight -line function of Tie Line deviation versus Frequency Deviation. The
Balancing Authority shall determine the fixed value by observing and averaging the
Frequency Response for several Disturbances during on -peak hours.
R2.2. The Balancing Authority may use a variable (linear or non - linear) bias value, which is
based on a variable function of Tie Line deviation to Frequency Deviation. The
Balancing Authority shall determine the variable frequency bias value by analyzing
Frequency Response as it varies with factors such as load, generation, governor
characteristics, and frequency.
R3. Each Balancing Authority shall operate its Automatic Generation Control (AGC) on Tie Line
Frequency Bias, unless such operation is adverse to system or Interconnection reliability.
R4. Balancing Authorities that use Dynamic Scheduling or Pseudo -ties for jointly owned units
shall reflect their respective share of the unit governor droop response in their respective
Frequency Bias Setting.
R4.1. Fixed schedules for Jointly Owned Units mandate that Balancing Authority (A) that
contains the Jointly Owned Unit must incorporate the respective share of the unit
governor droop response for any Balancing Authorities that have fixed schedules (B
and Q. See the diagram below.
1 of 2
Effective Date: TBD
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Alaska Standard AKBAL -004 -0 — Time Error Correction
A. Introduction
1. Title: Time Error Correction
2. Number: AKBAL -004 -0
3. Purpose:
The purpose of this standard is to ensure that Time Error Corrections are conducted in a
manner that does not adversely affect the reliability of the Interconnection.
4. Applicability:
4.1. Reliability Coordinators
4.2. Balancing Authorities
5. Effective Date:
B. Requirements
R1. Only a Reliability Coordinator shall be eligible to act as Interconnection Time Monitor. A
single Reliability Coordinator in each Interconnection shall be designated by the Intertie
Management Committee to serve as Interconnection Time Monitor.
R2. The Interconnection Time Monitor shall monitor Time Error and shall initiate or terminate
corrective action orders in accordance with the Time Error Correction Procedure.
R3. Each Balancing Authority, when requested, shall participate in a Time Error Correction by one
of the following methods:
R3.1. The Balancing Authority shall offset its frequency schedule by 0.02 Hertz, leaving the
Frequency Bias Setting normal; or
R3.2. The Balancing Authority shall offset its Net Interchange Schedule (MW) by an amount
equal to the computed bias contribution during a 0.02 Hertz Frequency Deviation (i.e.
20% of the Frequency Bias Setting).
R4. Any Reliability Coordinator in an Interconnection shall have the authority to request the
Interconnection Time Monitor to terminate a Time Error Correction in progress, or a
scheduled Time Error Correction that has not begun, for reliability considerations.
R4.1. Balancing Authorities that have reliability concerns with the execution of a Time Error
Correction shall notify their Reliability Coordinator and request the termination of a
Time Error Correction in progress.
C. Measures
Not specified.
D. Non - Compliance
None
E. Regional Differences
None identified.
Effective Date: TBD
1 of 2
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Alaska Standard AKBAL -005 -0 — Automatic Generation Control
A. Introduction
1. Title: Automatic Generation Control
2. Number: AKBAL -005 -0
3. Purpose:
This standard establishes requirements for Balancing Authority Automatic Generation Control
(AGC) necessary to calculate Area Control Error (ACE) and to routinely deploy the
Regulating Reserve. The standard also ensures that all facilities and load electrically
synchronized to the Interconnection are included within the metered boundary of a Balancing
Area so that balancing of resources and demand can be achieved.
4. Applicability:
4.1. Balancing Authorities
4.2.
Generator Operators
4.3.
Transmission Operators
4.4.
Load Serving Entities
5. Effective Date:
B. Requirements
Rl. All generation, transmission, and load operating within an Interconnection must be included
within the metered boundaries of a Balancing Authority Area.
111.1. Each Generator Operator with generation facilities operating in an Interconnection
shall ensure that those generation facilities are included within the metered boundaries
of a Balancing Authority Area.
R1.2. Each Transmission Operator with transmission facilities operating in an
Interconnection shall ensure that those transmission facilities are included within the
metered boundaries of a Balancing Authority Area.
R1.3. Each Load - Serving Entity with load operating in an Interconnection shall ensure that
those loads are included within the metered boundaries of a Balancing Authority Area.
R2. Each Balancing Authority shall maintain Regulating Reserve that can be controlled by AGC to
meet the Control Performance Standard.
R3. A Balancing Authority providing Regulation Service shall ensure that adequate metering,
communications, and control equipment are employed to prevent such service from becoming
a Burden on the Interconnection or other Balancing Authority Areas.
R4. A Balancing Authority providing Regulation Service shall notify the Host Balancing
Authority for whom it is controlling if it is unable to provide the service, as well as any
Intermediate Balancing Authorities.
R5. A Balancing Authority receiving Regulation Service shall ensure that backup plans are in
place to provide replacement Regulation Service should the supplying Balancing Authority no
longer be able to provide this service.
R6. The Balancing Authority's AGC shall compare total Net Actual Interchange to total Net
Scheduled Interchange plus Frequency Bias obligation to determine the Balancing Authority's
ACE. Single Balancing Authorities operating asynchronously may employ alternative ACE
Effective Date: TBD
1 of 4
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Alaska Standard AKBAL -005 -0 — Automatic Generation Control
Authority shall provide its operating personnel with real -time values for ACE, Interconnection
frequency and Net Actual Interchange with each Adjacent Balancing Authority Area.
R15. The Balancing Authority shall provide adequate and reliable backup power supplies and shall
periodically test these supplies at the Balancing Authority's control center and other critical
locations to ensure continuous operation of AGC and vital data recording equipment during
loss of the normal power supply.
R16. The Balancing Authority shall sample data at least at the same periodicity with which ACE is
calculated. The Balancing Authority shall flag missing or bad data for operator display and
archival purposes. The Balancing Authority shall collect coincident data to the greatest
practical extent, i.e., ACE, Interconnection frequency, Net Actual Interchange, and other data
shall all be sampled at the same time.
R17. Each Balancing Authority shall at least annually check and calibrate its time error and
frequency devices against a common reference. The Balancing Authority shall adhere to the
minimum values for measuring devices as listed below:
Device Accuracy
Digital frequency transducer < 0.001 Hz
MW, MVAR, and voltage transducer <_ 0.25 % of full scale
Remote terminal unit < 0.25 % of full scale
Potential transformer 5 0.30 % of full scale
Current transformer < 0.50 % of full scale
C. Measures
Not specified.
D. Compliance
I. Compliance Monitoring Process
1.1. Compliance Monitoring Responsibility
Balancing Authorities shall be prepared to supply data to the Intertie Management
Committee in the format defined below:
1.1.1. Within one week upon request, Balancing Authorities shall provide the
Intertie Management Committee or the Regional Reliability Organization
CPS source data in daily CSV files with time stamped one minute averages
of: 1) ACE and 2) Frequency Error.
1.1.2. Within one week upon request, Balancing Authorities shall provide the
Intertie Management Committee or the Regional Reliability Organization
DCS source data in CSV files with time stamped scan rate values for: 1) ACE
and 2) Frequency Error for a time period of two minutes prior to thirty
minutes after the identified Disturbance.
1.2. Compliance Monitoring Period and Reset Timeframe
Not specified.
1.3. Data Retention
1.3.1. Each Balancing Authority shall retain its ACE, actual frequency, Scheduled
Frequency, Net Actual Interchange, Net Scheduled Interchange, Tie Line
Effective Date: TBD
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Alaska Standard AKBAL -006 -0 — Inadvertent Interchange
A. Introduction
1. Title: Inadvertent Interchange
2. Number: AKBAL -006 -0
3. Purpose:
This standard defines a process for monitoring Balancing Authorities to ensure that, over the
long term, Balancing Authority Areas do not excessively depend on other Balancing Authority
Areas in the Interconnection for meeting their demand or Interchange obligations.
4. Applicability:
4.1. Balancing Authorities.
5. Effective Date TBD
B. Requirements
R1. Each Balancing Authority shall calculate and record hourly Inadvertent Interchange.
R2. Each Balancing Authority shall include all AC tie lines that connect to its Adjacent Balancing
Authority Areas in its Inadvertent Interchange account. The Balancing Authority shall take
into account interchange served by jointly owned generators.
R3. Each Balancing Authority shall ensure all of its Balancing Authority Area interconnection
points are equipped with common megawatt -hour meters, with readings provided hourly to the
control centers of Adjacent Balancing Authorities.
R4. Adjacent Balancing Authority Areas shall operate to a common Net Interchange Schedule and
Actual Net Interchange value and shall record these hourly quantities, with like values but
opposite sign. Each Balancing Authority shall compute its Inadvertent Interchange based on
the following:
R4.1. Each Balancing Authority, by the end of the next business day, shall agree with its
Adjacent Balancing Authorities to:
R4.1.1. The hourly values of Net Interchange Schedule.
R4.1.2. The hourly integrated megawatt -hour values of Net Actual Interchange.
R4.2. Each Balancing Authority shall use the agreed -to daily and monthly accounting data to
compile its monthly accumulated Inadvertent Interchange for the On -Peak and Off -
Peak hours of the month.
R4.3. A Balancing Authority shall make after - the -fact corrections to the agreed -to daily and
monthly accounting data only as needed to reflect actual operating conditions (e.g. a
meter being used for control was sending bad data). Changes or corrections based on
non- reliability considerations shall not be reflected in the Balancing Authority's
Inadvertent Interchange. After - the -fact corrections to scheduled or actual values will
not be accepted without agreement of the Adjacent Balancing Authorities.
Adjacent Balancing Authorities that cannot mutually agree upon their respective Net Actual Interchange
or Net Scheduled Interchange quantities by the 15th calendar day of the following month shall, for the
purposes of dispute resolution, submit a report to their respective Regional Reliability Organization
Survey Contact. The report shall describe the nature and the cause of the dispute as well as a process for
correcting the discrepancy. By mutual agreement with respect to scheduling Bradley lake losses, and if
other arrangements have not been made:
Losses shall be accumulated as an after the fact scheduled transaction.
However losses will not be added to the hourly or accumulated inadvertent.
1 of 3
Effective Date: TBD
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Alaska Standard AKBAL -006 -0 — Inadvertent Interchange
3of3
Effective Date: TBD
Alaska Standard AKFAC -001 -0 — Facility Connection Requirements
A. Introduction
1. Title: Facility Connection Requirements
2. Number: AKFAC -001 -0
3. Purpose: To avoid adverse impacts on reliability, Transmission Owners must establish
facility connection and performance requirements.
4. Applicability:
4.1. Transmission Owner
5. Effective Date: TBD
B. Requirements
R1. The Transmission Owner shall document, maintain, and publish facility connection
requirements that at a minimum meet the Intertie Management Committee's facility
connection requirements and ensure compliance with its Reliability Standards and applicable
Regional Reliability Organization, subregional, Power Pool, and individual Transmission
Owner planning criteria and facility connection requirements. The Transmission Owner's
facility connection requirements shall address connection requirements for:
R1.1. Generation facilities,
111.2. Transmission facilities, and
R1.3. End -user facilities
R2. The Transmission Owner's facility connection requirements shall address, but are not limited
to, the following items:
R2.1. Provide a written summary of its plans to achieve the required system performance as
described above throughout the planning horizon:
R2.1.1. Procedures for coordinated joint studies of new facilities and their impacts on
the interconnected transmission systems.
R2.1.2. Procedures for notification of new or modified facilities to others (those
responsible for the reliability of the interconnected transmission systems) as
soon as feasible.
R2.1.3. Voltage level and MW and MVAR capacity or demand at point of connection.
R2.1.4. Breaker duty and surge protection.
R2.1.5. System protection and coordination.
R2.1.6. Metering and telecommunications.
R2.1.7. Grounding and safety issues.
R2.1.8. Insulation and insulation coordination.
R2.1.9. Voltage, Reactive Power, and power factor control.
R2.1.10.Power quality impacts.
R2.1.11. Equipment Ratings.
1 of 3
Effective Date:
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3 of 3
Effective Date:
Alaska Standard AKFAC -002 -0 — Coordination of Plans for New Facilities
A. Introduction
1. Title: Coordination of Plans For New Generation, Transmission, and End -User
Facilities
2. Number: AKFAC -002 -0
3. Purpose: To avoid adverse impacts on reliability, Generator Owners and Transmission
Owners and electricity end -users must meet facility connection and performance requirements.
4. Applicability:
4.1.
Generator Owner
4.2.
Transmission Owner
4.3.
Distribution Provider
4.4.
Load - Serving Entity
4.5.
Transmission Planner
4.6.
Planning Authority
5. Effective Date:
B. Requirements
Rl. The Generator Owner, Transmission Owner, Distribution Provider, and Load - Serving Entity
seeking to integrate generation facilities, transmission facilities, and electricity end -user
facilities shall each coordinate and cooperate on its assessments with its Transmission Planner
and Planning Authority. The assessment shall include:
111.1. Evaluation of the reliability impact of the new facilities and their connections on the
interconnected transmission systems.
R1.2. Ensurance of compliance with the Intertie Management Committee's Reliability
Standards and applicable Regional, subregional, Power Pool, and individual system
planning criteria and facility connection requirements.
R1.3. Evidence that the parties involved in the assessment have coordinated and cooperated
on the assessment of the reliability impacts of new facilities on the interconnected
transmission systems. While these studies may be performed independently, the
results shall be jointly evaluated and coordinated by the entities involved.
R1.4. Evidence that the assessment included steady- state, short- circuit, and dynamics studies
as necessary to evaluate system performance..
R1.5. Documentation that the assessment included study assumptions, system performance,
alternatives considered, and jointly coordinated recommendations.
R2. The Planning Authority, Transmission Planner, Generator Owner, Transmission Owner, Load -
Serving Entity, and Distribution Provider shall each retain its documentation (of its evaluation
of the reliability impact of the new facilities and their connections on the interconnected
transmission systems) for three years and shall provide the documentation to the Regional
Reliability Organization(s) and the Intertie Management Committee on request (within 30
calendar days).
Effective Date: TBD
1 of 2
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Alaskan Railbelt Standard AKINT -001 -0 — Interchange Information
A. Introduction
1. Title: Interchange Information
2. Number: INT -001 -0
3. Purpose:
Scheduled interchange must be coordinated between Balancing Authorities to prevent
frequency deviations and accumulations of inadvertent interchange, and prevent exceeding
mutually established transfer limits.
4. Applicability:
4.1. Purchase - Selling Entities.
4.2. Balancing Authorities.
5. Effective Date:
B. Requirements
Rl. Interchange shall be scheduled only between Balancing Authorities having directly connecting
facilities in service unless there is a contract or mutual agreement with another Balancing
Authority to provide connecting facilities.
R2. Interchange schedules or schedule changes shall not cause any other system to violate
established reliability criteria.
R2.1. When Balancing Authorities are connected so that parallel flows present reliability
issues, the combinations of Balancing Authorities shall develop multi- control area
interchange monitoring techniques and pre - determined corrective actions to mitigate or
alleviate potential or actual transmission system overloads.
R2.2. Transfer limits shall be reevaluated and interchange schedules adjusted as soon as
practicable if transmission facilities become overloaded or are out of service, or when
changes are made to the bulk system which can affect these limits.
R3. The maximum net scheduled interchange between two Balancing Authorities shall not exceed
the lesser of two values:
R3.1. The total capacity of the transmission facilities in service between the two Balancing
Authorities owned by them or available to them under specific arrangements, contract,
or mutual agreements, or
R3.2. The mutually established First Contingency Total Transfer capability of the two
control areas considering other transmission facilities available to them under specific
arrangements.
R4. The sending, contract intermediary, and receiving Balancing Authorities that are parties to an
interchange transaction shall agree on the following:
R4.1. The schedule's magnitude, starting and ending times.
R4.2. The schedule's magnitude and rate of change shall be equal and opposite and not
exceed the ability of the systems to effect the change.
R4.3. The scheduled generation in one Balancing Authority that is delivered to another
Balancing Authority must be scheduled with all intermediate Balancing Authorities
unless there is a contract or mutual agreement among the sending, contract
intermediary, and receiving Balancing Authorities to do otherwise.
Adopted by the Intertie Management Committee: Page 1 of 2
Effective Date:
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Interconnection Standards_for Railbelt Generation
Table of Contents
Section I ntroduction ......................................... ............................... 4
110 How the Standards are Organized .................................. ..............................4
120 Operational Policy for interconnection to the Interconnected
Railbelt Electrical System .............................................. ..............................5
140 Parallel Operation .......................................................... ..............................6
150 Islanding .................................................................... ............................... 6
Section 2.• Interconnection Process and Application ProcedureS ......... 7
210 Objectives ...................................................................... ..............................7
220 Authority ................................................... ............................... ........9
230 Process Review and Responsibilities ............................. ..............................9
Section 3.• Interconnected Operating ReQUI REMENTS ........................ 15
310 Approval for Parallel Operation .................................... .............................15
320 Discontinuance of Parallel Operation ........................... .............................15
330 Islanded Operation ........................................................ .............................16
340 Voltage Requirements ................................................... .............................16
341 Voltage Levels .................................................. .............................16
342 Voltage Fluctuations ......................................... .............................17
343 Voltage Regulation and Reactive Power Requirements ................17
350 Generator Droop Requirements .................................... .............................18
351 Generator Inertial Response Requirements .................. .............................18
352 Operating (Spinning) Reserve Requirements ............... .............................18
353 Non - Operating (Non - Spinning) Reserve Requirements ............................18
360 Harmonics ..................................................................... .............................18
370 Power Factor Requirements .......................................... .............................19
380 Coordination with the Railbelt Protective System ........ .............................19
390 Maintenance & Testing ................................................. .............................20
391 Interconnection Equipment Maintenance ......... .............................20
392 Protective Systems Functional Testing ............. .............................20
Section 4.• General Requirements ........................ ............................... 23
410 Design Requirements .................................................... .............................23
411 Design Documentation and Information ........... .............................23
412 Protective Systems and Equipment ................... .............................24
413 Railbelt System Modifications .......................... .............................25
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Interconnection Standards_for Railbelt Generation
Figure 1: Typical Secondary System Interconnection - Facilities ............................65
Figure 2: Typical Primary System Interconnection - Facilities ... .............................66
These Standards are subject to revision, at any time, at the discretion of the Intertie
Management Committee (as defined in the Railbelt Operating Standards). This
document is not intended to be a design specification.
Page 3
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Interconnection Standards for Railbelt Generation
120 Operational Policy for interconnection to the Interconnected
Railbelt Electrical System
It is the operating policy of the Utilities to provide authorization for generating
facilities to interconnect and operate in parallel with the Interconnected Railbelt
Electrical System provided this can be done without adverse effects to, personnel,
equipment, or system operations. The power to grant such interconnection
authorization is delegated to the Intertie Management Committee. Such authorization
is governed by and subject to adherence to the Alaskan Railbelt Operating Standards.
This document provides the general Standards and requirements to make such
interconnection and operation possible. All interconnected entities will be subject to
the requirements of the Alaskan Railbelt Operating Standards as adopted by the
Intertie Management Committee at the time of interconnection
In these Standards, interconnection is defined as the electrical connection of
generation facilities greater than 10 MW evaluated at Standard Temperature and
pressure or that as a result of any N -1 or probable N -2 contingencies (including Fuel
Supply) assessed against the boundary dispatch cases adopted by the Intertie
Management Committee at the time of interconnection, and as identified in the
required system studies is found to be capable of moving the interconnected system
frequency by 0.1 Hz (one -tenth Hertz). Parallel operation is the condition where
generation operates while electrically connected to the Interconnected Railbelt
Electrical System; under this condition, real and reactive electric power can either
flow from the Interconnected Railbelt Electrical System to the generation facility or
vice versa.
Within these Standards, the term `Producer' is used to refer to the owner(s) of
generating facilities, or agents acting on their behalf, who have been authorized by
the Intertie Management Committee to interconnect and operate generation in parallel
with the Interconnected Railbelt Electrical System. Also in these Standards, an
`applicant' is defined as an individual or party who has applied for the
interconnection of generation with the Interconnected Railbelt Electrical System.
The operation of generation in parallel with The System poses important safety
concerns for personnel and equipment. The safe, reliable operation of the
Interconnected Railbelt Electrical System is of the utmost importance to the Intertie
Management Committee. Accordingly, any interconnected generating facility must
meet all applicable federal, state, and local safety codes and regulations, in addition to
the specific Standards and requirements contained in these standards, and, the most
current version of the Railbelt Operating Standards as adopted by the Intertie
Management Committee. The Intertie Management Committee requires those
applying for interconnection to obtain the services of an engineering professional,
expert in power system analysis, the design of wiring and of protection and controls
systems, including control and protection systems for generating equipment
interconnected within small stability limited interconnected electric grids.
Page 5
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Interconnection Standards for Railbelt Generation
while maintaining energization to a portion of the electrical system temporarily
separated electrically from the rest of the System, but normally considered part of the
Railbelt Electrical System.
Of primary concern are safety and reliability issues which may be present to the
System and its personnel under islanding conditions. Maintenance personnel must
have the assurance that any section of The System that has been de- energized and is
under a hotline order or working clearance will not be re- energized until there is
confirmation that they are physically clear of the System. Under an islanded
condition, such assurance to personnel must be provided by the generating facility
following the appropriate Transmission Operators" switching and clearance
procedures. In addition, appropriate System frequency and voltage must be
maintained within the Island.
SECTION 2: INTERCONNECTION PROCESS AND
APPLICATION PROCEDURES
210 Objectives
This portion of the interconnection Standards contains an overview of the process and
required procedures to interconnect Producer -owned generation with the
Interconnected Railbelt Electrical System. It also provides both administrative and
technical Standards to assist the applicant in obtaining such interconnection in an
efficient and consistent manner.
A Producer intending to operate generation in parallel with the Interconnected
Railbelt System is required to complete an "Application for Operation of Producer -
Owned Generation." The time required to complete the process generally depends on
the complexity of the proposed project. The applicant must provide the appropriate
Balancing Authority and the Intertie Management Committee with a complete design
package including accurate machine modeling data in the PTI -P /SSE format and
system control and protection settings so that the nature and extent of system
integration requirements may be determined.
• As a rule of thumb, the smaller the proposed generation system (as a
percentage of the total system generation) the more limited the design review
and study requirements will be.
The review of the interconnection facilities and analysis of the impact of the proposed
interconnection on the Interconnected Railbelt Electrical system will be evaluated
based upon preliminary power system studies. Several of the process steps may be
satisfied with an initial application, based on the detail and completeness of the
application and supporting documentation submitted by the applicant. Additional
more detailed and rigorous studies may need to be accomplished depending upon the
outcome of the preliminary system studies. The Balancing Authority will clearly
Page 7
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Interconnection Standards or Railbelt Generation
220 Authority
The state regulatory agency having authority over the supply of electrical service
requires the certificated Utilities within the Railbelt Interconnection to provide safe,
adequate, efficient, and reasonable service. All interconnection requirements must
comply with the appropriate Transmission Owners internal interconnection standards
and requirements and the Balancing Authorities control requirements. Any party
desiring to interconnect and operate generation in parallel with the Railbelt Electrical
System must comply with the requirements contained in these Standards as well as
any other adopted Railbelt Standards.
230 Process Review and Responsibilities
The following process is designed to provide the Applicant with an understanding of
the information and steps necessary to allow the Intertie Management Committee,
Transmission Owner, and Balancing Authority to review the Applicant's proposal
and provide authorization for interconnection in a reasonable and expeditious manner.
Page 9
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Interconnection Standards for Railbelt Generation
Step 2.• Application Processing
A. Initial Application Initial processing involves:
Processing a) Payment of estimated administrative and
preliminary study and analysis processing fees
(see Step 1, C).
b) Determination of the scope and performance of
preliminary interconnection studies required.
Including but not limited to preliminary:
Power Flow Analysis, Transient Stability
Analysis, Available Fault Current Analysis,
Existing Facility Rating Analysis and Fuel
Supply analysis.
c) Performing a preliminary impact review, to
assess the impact that the proposed
interconnect will have on Railbelt facilities
and consumers and providing guidance on the
extent to which more rigorous studies or
expanded studies are to be performed
d) Assessment of any specific requirements in
addition to the general requirements outlined in
the Standards.
Typically not to
exceed 90 calendar
days.
Page 11
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'sauauuaimboi Ioiluoo
put: fulowajat ot3loods 3o uoijuuiuuajaQ (p
's.tatautund
2ugujodo ot3toods- Xjtitauj 3o uopuu►uumC[ (o
'suopuot3ipow
tualsXs faussaoau put sluotua.nnbaa
uotloauuoo.zaaui oi3►oads ssosst? of `pa.ttnba.t
�jq!gvi!PAU
se `satpnis puu sass lt:u>; tuajs�s snoto2t.t
oomosat
put; 3131dutoo 3o aoueuuojiad put; 2utdooS (q
puu adoas loafojd
- Xl!.toglnV Buiouuiug agl
uo 2utpuod3p
Xq pauuo3.t3d aq of sisoo sisXltuu puu Xpnis
.n ox Jt puaieo
I>?uoilippt pa ;t utpsa 30 �uatuXud lisodaQ (v
8uzssa�o�d
I osI
:sanionui XIPuaua2 2utss000id uotivoiiddt luui,d
uozjvoildddlvu •g
uoilviauag ilag11vg jof sprvpuviS uopaauuoa.ra ;ul
Interconnection Standards for Railbelt Generation
B. Final Design Review
and Coordination
provide definition on specific content necessary
in the draft final design package.
This procedure involves the Balancing
Authorities' review and coordination of the
submitted final design. The Balancing
Authority will assign a Project Manager,
responsible for design review, project schedule
coordination (with the Balancing Authority and
Intertie Management Committee), and any
necessary system modifications.
Variable;
dependent on scope
of project.
If system modifications are necessary to
accommodate the proposed interconnection,
such work will be initiated by the Balancing
Authority and these modifications, billable to
the Applicant. A preliminary cost estimate will
be provided to the applicant prior to work order
finalization.
After the Balancing Authority and Intertie
Management Committee approve the final
interconnection design, a `Provisional
Interconnection Agreement' can be executed
between the Applicant and the Balancing
Authority, and construction can proceed.
Step 4: Construction, Inspection, and Acceptance
A. Provisional with approval of the applicant's final design, and
Interconnection written agreement that the applicant will bear all
Agreement costs associated with system modifications (as
necessary), The Balancing Authority will
authorize construction of the interconnection via
the Provisional Interconnection Agreement.
Essentially, this agreement allows the applicant
to proceed with construction and to perform
subsequent testing to ensure that the
interconnection is safe, adequate, and reliable.
Dependent upon
Parties.
Page 13
v I aOud
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2uiouulug oql 3o sluaatatinbai aql puu sptupuulS
uotloouuootalui llaglTug g1Tm aouuildwoo
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•siopio 31101A uotluO!J!pout
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slim paluToossu slsoo flu io3 �IpoglnV 2uiouulug
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s, 2uiouulug aql 3o uoiluAJosgo
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aql slim aouup1033 u pa lsal pauoisSIWWoo
oq Ipm luaurdinbg III' •soilsizaloujugo 2uilut3do
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am �jqunb .tamod `su llam su `sindlno uttulu puu
falautalal `osuodsai oouututo3a3d liun `soililiquduo
2utziuojgou�s `sluiod los utals�s uoilooloid
aql lugl amsua of `papoau su `(2uiuoisstwwoo)
2uilsol aouuld000u Iuuoiloun3 uoiloauuootalui
azt.toglnu IP.m Xl!joglnd 5utouulug
aq j, `uoilon.zlsuoo jo uoilaldwoo aql fuimollod
•ui?Tsap IuuT3
panotddu aql jo suoiluoy!oads oql laaut soililiou3
uoiloouuoo.talui aql lugl lugl wnsuo o f Xl!.zoglnd
2utouulug oql jo uoTlolosip oql lu `pmioj.tad
aq llim (uoiloodsui Inn put suopoodsui oipoind
•uotloadsui umpouuootalui luuij puu `suoiloodsui
otpoi.tad .toj .taiuuum loofoid �soil!joglnV
�?ulouulug slim 2uiluuipi000 `uoilorulsuoo
uoiloauuoo.talui slim paaootd �vw luuoilddu oqZ
u011nazO.10A saaTn raS
'Unpp .mv pun
uo?1n p ?ouooa y ;soD
aounldaoad pnuzj •j
uolloadsu1 pnuzj
pun uotlan asuoD •g
uoyvrauag ilagpzvy jof sprvpums uo?loauuoaraluj
Interconnection Standards for Railbelt Generation
D. Trial Operating
The facility will undergo a trial operating period
45 Days or more
Period
of the greater of 45 days or the projects
depending upon
declaration of being "commercial ". During this
performance.
period, Online Reliability must meet or exceed
the 12 month rolling average of the remainder of
the Railbelt interconnection generating units
Online Reliability. For each occurrence in which
unit Online Reliability exceeds Railbelt average
the 45 day clock is reset and begins again.
Successful conclusion of the trial operating
period is required prior to Final Interconnection
Acceptance. The facility will be required to
provide or acquire 100% spinning reserves
during the trial operating period. This
requirement may be reduced by the Intertie
Management Committee on a case by case basis
for facilities that clearly could not (or would not)
be substantially base loaded.
E. Final
Upon completion of Final Acceptance, Cost
Dependent upon
Interconnection
Reconciliation, and Trial Operating period the
parties.
Acceptance and
Final Acceptance Agreement can be executed
Commercial Operation
between the Applicant and The Balancing
Authority.
SECTION 3: INTERCONNECTED OPERATING REQUIREMENTS
The general operating requirements and criteria contained in this section apply to all
generation facilities interconnected to the Railbelt Electrical Interconnection electric
system. Any Producer operating outside of these requirements, unless provided
expressed permission by the Intertie Management Committee, will not be permitted to
operate in parallel with the Interconnection and will be responsible for any and all
remediation actions and associated costs prior to gaining approval for parallel
operation. The consequences for failing to meet any of these requirements are
immediate disconnection and payment of all associated costs.
310 Approval for Parallel Operation
The Producer may not commence parallel operation of generation facilities without
final written approval from the Intertie Management Committee The Intertie
Management Committee, Transmission Owner, and Balancing Authority reserve the
right to inspect, test, or perform witness testing of the Producer's equipment or
devices associated with the interconnection.
320 Discontinuance of Parallel Operation
Page 15
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slt;anat luauzdinbo SutlwouoS s,aaonpo.zd oql jo uoiloodsui uu uogM ■
`uotpoouuooialul llagltt agp op poloauuoo saaonpoid i3mod
joglo to/puu Xpiligvila2l ao Aliltnb iomod uoipoauuoo.zapul llogliL,2I
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`.saipiiion3
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:aalliurtuoo puowa2Nuvw atlaalul io ,ipiaogpnv 2uiout:lrg
aqp aagpia Sq polsanbaa uogm uoiltando Iallujud onutpuoosip IILgs nonpozd aqZ
uopvrauag ;Iagllv2r jof sprvpuviS uozjaauuoa.ra ;uj
Interconnection Standards.for Railbelt Generation
342 Voltage Fluctuations
For all N -1 and probable N -2 contingencies (including Fuel Supply) assessed
against the boundary dispatch cases adopted by the Intertie Management
Committee at the time of interconnection), and as identified in the required
system studies The Producers interconnection with the Railbelt may not
increase voltage fluctuations that may be noticeable as visual lighting
variations (flicker) or may damage or disrupt the operation of electronic
equipment. Voltage Fluctuations may not exceed the operating conditions
prior to interconnection. The Institute of Electrical and Electronics Engineers'
(IEEE) Recommended Practices and Requirements for Harmonic Control in
Electric Power Systems (IEEE Standard 519) provides definitions and limits
on acceptable levels of voltage fluctuation. Generators operating in parallel
with the Railbelt Interconnection shall comply with IEEE Standard 519,
Section 10.5.1, and Figure 10.3: Maximum Permissible Voltage Fluctuations.
Specifically, no interconnected utility generation facility will be allowed to
exceed the percent voltage fluctuation above the `Border Line of Visibility
Curve' contained in the referenced figure assuming this condition did not exist
prior to interconnection..
343 Voltage Regulation and Reactive Power Requirements
For all N -1 and probable N -2 contingencies ( including Fuel Supply) assessed
against the boundary dispatch cases adopted by the Intertie Management
Committee at the time of interconnection., operation of the Producer's
generator shall not adversely affect the voltage regulation or profile of the
Railbelt Interconnection. Adequate voltage control shall be provided by the
Producer to minimize voltage fluctuations on the Railbelt Interconnection
caused by changing generator loading conditions.
Interconnection of the plant or unit shall not result in degradation of the
voltage profile of any system bus under any N -1 and probable N -2
contingencies (including Fuel Supply) assessed against the boundary dispatch
cases adopted by the Intertie Management Committee at the time of
interconnection.
For synchronous generators, for all N -1 and probable N -2 contingencies
(including fuel supply), as identified in the required system studies, sufficient
generator reactive power capability shall be provided (or obtained as an
ancillary service) to withstand normal voltage changes on the Railbelt
interconnection without degrading the pre - interconnection voltage profile at
the point of interconnection. The generator reactive power requirements,
voltage regulation, and transformer ratio settings will be jointly determined by
Page 17
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Interconnection Standards for Railbelt Generation
The Producer shall be responsible for providing (or contracting for the provision of)
non - operating reserves to the Railbelt Interconnection. Reserves provided shall be in
an amount specified by the most current operating reserve policy approved by the
Intertie Management Committee and shall meet the requirements of minimum start
time, quality of response, and geographic location as set forth in that policy
360 Harmonics
Harmonic distortion is defined as the ratio of the root mean square (rms) value of the
harmonic to the rms value of the fundamental voltage or current (refer to IEEE
Standard 519). Distortion of the harmonic content of voltage and /or current
waveforms can cause telecommunication interference, disable solid -state equipment,
overheat transformers, and create resonant over - voltages. In order to protect The
Railbelt equipment and consumers from damage, harmonics must be maintained
within acceptable limits. As such, for all N -1 and probable N -2 contingencies
(including fuel supply), as identified in the required system studies, the
interconnection of the Producers facilities shall not be allowed to introduce harmonics
into the system beyond those present prior to Producer interconnection.
IEEE Standard 519 specifies a range of Total Harmonic Distortion (THD) limits
based on the size of the load with respect to the size of the power system. The
Producer's equipment shall not introduce, onto the Railbelt Interconnection, voltage
or current distortion in excess of the limits contained in IEEE Standard 519 or those
present prior to interconnection, whichever is greater. Specifically, voltage distortion
shall not exceed the limit outlined in Section 11.5, and current distortion shall not
exceed the limits contained in Section 10 of the referenced standard. In addition, the
Balancing Authority and Intertie Management Committee advise that the Producer
consider and account for harmonics in the early stages of facility planning and design.
If excessive harmonic distortion is suspected, voltage and current distortion
measurements will be performed and compared to base line data to determine whether
the Producer's equipment is a source of, or contributor to, excessive distortion. If the
Producer's facility is found to be the source of excessive harmonic distortion, the
Producer will be billed for the investigation costs, and will be held responsible for
corrective action to bring the harmonic content within the referenced limits.
370 Power Factor Requirements
Producers are responsible for reactive power necessary to maintain power factors such that
the voltage profile of the interconnection point is not degraded by interconnection of the
Producers facilities. Producers are required to provide or contract for the provision of
ancillary services for reactive power support in order to maintain operation within the
specified limits.
380 Coordination with Railbelt Protective Systems
Page 19
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`3011iUTWOD luaW;)OuutW ailtalui aqj Xg panoiddt, put, paMatna.T uaag ant,q SBUTIJOS
put, SUOTJOunj antloaloid uopoauuoomut paatnbai Ilu plun pannollt, zo paztaoglnt,
ag lou Ilion uotit,aado Iallt,at,d `XISutpi000d •pta2 XIddns It,otzjoala a p jo Xjtitgt
put, X13jt,s atp of oomliodurt luotlt.To jo st walsKs uotloaloid siounno uotsstuzsuujjL aqi
glint SUOTJOunj antloaloid uotjoouuoo.zaiut s,.Taonpoid atp 3o UOIILutpj000 zadoid oqZ
uoyvjauaf) ;Iaqllv2f jof sprvpuviS uoz;aauuoaralul
Interconnection Standards for Railbelt Generation
Generally, functional testing of protective relay settings and interconnection circuit
breaker operations shall be performed by the Producer per the manufacturers
recommended testing interval. Documented test results must be provided to
Transmission Owner within five (5) working days after the completion of tests.
The Producer must grant the Intertie Management Committee the right to review and
modify the functional testing requirements, as necessary, during the life of the
facility.
Page 21
Interconnection Standards, for Generation Section 4
SECTION 4: GENERAL REQUIREMENTS
490 Design Requirements
411 Design Documentation and Information
For review and reference purposes, the Producer shall submit the following
information and design documentation with the interconnection application(s)
(Refer to Appendix P Applications for Interconnection). In certain cases some
submittal requirements may be waived, at the Intertie Management
Committee's discretion. The design documentation will need to be approved
by an electrical engineer, registered and recognized as a Professional Engineer
in the State of Alaska. Where this approval is required, it shall be indicated
by the presence of the engineer's professional seal on all drawings and
documents.
A. One -Line Diagram
This is a schematic electrical drawing with sufficient detail to show the major
elements of the facility electrical connections, interconnection and protective
equipment, and point of interconnection to the Transmission Owners electrical
system. The diagram should include the following:
• Generating equipment
• Circuitry of the facility, to include conductor types, sizes, and bus
electrical ratings
• Metering points and instrument transformers (as applicable)
• Interconnection transformer
• Relays and circuit breakers /interrupting devices
• Switchgear (as applicable)
• Utility circuitry at the point of interconnection
B. Three -Line Diagram (as required)
This schematic electrical drawing shall represent all three phases and
neutral connections of the interconnected facility circuits, showing
potential transformer (PT) and current transformer (CT) ratios and details
of their configuration, including relays, meters, and test switches.
C. Relay, Metering, and Telemetering Functional Drawing
Page 23
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of luatudinbo sigp jo i?uimnzp 3uii- 312uis L litugns iirgs jumiiddu 3gl `u oisXs
szaumo uoissitusuujjL aqi jo uoiloaloid agl ioj saoinap aniloolojd 2uisodoid
uogm 'sapoo iudioiuntu puu `iUooi `alUls `JUJOPa3 Iiu puu SPJLpuuls ggql
`aPOD �1o3us ILoialoaig iuuoilLN aql `aPOD iUoialoaig TuoilRN 3111 0 uuOJuoo
lsntu lumadinbo puL su21sop iiu put `slu3urazmbaz s,.r3umo uoisslwsuu.zZ
laatu lsntu nonpord oqZ 'suoilu.r3pisuoo orjioads -oiis aaglo ptre `azis
`3dXl iolujouag agl uo spuodap wolsxs uoiloalord ail jo u2isop oijioods aqZ
•pirB oiuoolo ltagiiw2l
3ql glim uoiloauuoozalui JOJ ignoiddu of roiad oouiunuoo lumuoOlom w arliolui
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wolsXs liagtit 3tli tlpim iatiu.rud ui 3wnodo of sosodoid putp luuoiidde qo - eg
juawdinb3 pue SWOISAS anl}oaIoad Z 6Vl
'3311iunuo:) lu3w3SuuvW ailiolul oql fq poisonboi
su xlll!ouj paloouuooaalui agl op Ouiuiuli3d sivatunoop jo uoilUuuo3ui
uOrsap iUuoiliPPU Sue of apinoid Ipm izonpoid 3ql `3nogv oqi of uoiliPPu ul
'Suiouds
put `sopozloolo jo aEi puu `azis `.iogtunu oqi su iiom se `suorloauuoo
put `i?uipuoq `sozis aiim punoiS 3 1toiPui iirgs s2uimigzp osagZ
siluimu iQ 2uipunoag Xl!l!an3 •g
's5ulmnap 3111 ui pownipui fizL'aio
oq pings iozluoo gou3 aoj jamod 3o oa.mos 3qZ 'asoio jo uodo of Xiiiio - ej
3uilommoralui oql of poiiddr sioVojq pinojio lie 3snuo lugi sx3 uaojsuujl
lu3turulsui pug sxtiar `suoilipuoo aql molts iitgs sOuimuap asagZ
s21ulmu.aQ io tluo3 .aa3ina.ig ;maai3 '(I
•Xuu 3i `luatudinbo Surz31atu3ial put `2uilalatu
`sXb ivnPinipui 3111 3o suoilounj aql 3 IlL'gs tu161.1BUIP siq,L
1, u093as uoyvraua!) Jof sprvpuVIS uozpauumialul
Interconnection Standards or Generation Section 4
The Intertie Management Committee will accept only those portions of the
Producer's system designs which apply to the interconnection with, and
protection of, the Railbelt system. The Intertie Management Committee may
comment on other areas, which appear to be incorrect or deficient, but will not
assume responsibility for the correctness of protection pertaining to the
Producer's system.
At the completion of construction, functional tests of all protective equipment
must be performed and witnessed by designated Transmission Owner
personnel. In order to gain Transmission Owner approval for interconnected
operation, successful completion of the functional tests and verification that
protective relay criteria are correctly applied must be demonstrated and
documented.
413 Railbelt System Modifications
Any modification to the Railbelt electric grid, such as the installation of
additional equipment, reconductoring of all or a portion of the connecting
Transmission Owners line, or reconfiguration of Transmission Owners
protection systems necessary to permit in- parallel operation with the Railbelt
electric grid, will be performed by the Transmission Owner.
Where such system modifications are required to allow the interconnection of
the Producer's facilities, the Transmission Owner will perform these
modifications, providing all labor, materials, and equipment necessary, at the
Producer's expense.
420 Design Information -- Rai /be /t System
421 Standard System Voltages
The Railbelt standard system voltages conform to ANSI C84.1 standards, and
are outlined as follows. Specific voltage requirements and limits for
Producer's generation are described in Section 3: Interconnected Operating
Criteria.
■ Transmission Voltages:
— 69,000 volts, three -phase
— 115,000 volts, three -phase
— 138,000 volts, three -phase
— 230,000 volts, three -phase
Page 25
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oI uoiltsuodwoo jo lioddns antloUaa jjU apinoad of iaonpOJd 3ql Jo �I!pq!suodsaj
a14j si
11 •saolou3 jamod Buipuaj it of mado Xlluaioqui szojl6 uoilonpui `.IVA Jo
(uopdjosgu zo) uopdwnsuoo sigl of OnCl •(slium) iomod oiijoa10 luaa oonpoad of zapzo
ut (.VA) .zamod oixioaja Ontlolow jo slunouzr 5U ThUA a szo uoilonpul
sio;aaauag uoi;onpu/ 0£p
t uoYaas uo . nvrauao Jof sprvpuvis uopaauummalul
Interconnection Guidelines or Non - Utility Generation Section S
SECTION 5: INTERCONNECTION EQUIPMENT REQUIREMENTS
510 Introduction
In order to simplify the process for determining the interconnection equipment
necessary to operate generation in parallel with the Railbelt electric system, the
Intertie Management Committee has developed this section which outlines the
minimum interconnection requirements for Producer -owned facilities.
520 Overview of Required Equipment
This overview of required equipment and devices provides general descriptions as to
the components, including functionality, purpose, and responsibilities by both the
Producer and the Transmission Owner regarding ownership, installation, and
maintenance.
Specific requirements for Producer -owned interconnected generation can be found in
Section 530: Equipment Requirements.
521 Metering Requirements
For all generating facilities, the Intertie Management Committee requires that
"In -Out Metering" be utilized to capture the real power flows (watt- hours)
into and out of a Producer's facility.
It is the Producer's responsibility to provide, install, and maintain all facilities
necessary to accommodate metering. All meters shall be provided by the
Transmission Owner at the Producer's expense. Depending upon the specific
application required metering may also include the following:
■ VAr -hour metering
■ Real power (watt) demand metering
■ Reactive power (VAr) demand metering
522 Interconnection Disconnect Device
The Transmission Owner approved manual disconnect device must be
provided as a means of electrically isolating the generating facility from the
Railbelt system, and establishing working clearances for maintenance and
repair work in accordance with the Transmission Owners safety rules and
practices.
Page 27
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:sui.iajauz ,�jiii3R3 oqj irou `uotloauuoonjui
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ssaoou jo asua ao3 paluooi �IiroisXgd aq Isnw aoinap Ioauuoosip lunum aqZ
•pasn aq IILgs aaumo uoissimsuujjL oqj Xq panojddu
XIi7aoi3ioads saoinap Xluo •saijiligisuodsaz aourualuim pur digsaaumo
auznssr put aoinap aqj IiVIsui llugs joumo uoissiwsuuj L oip `osuodxo
s,aaonpozd aql IV •juzod uogaauuoa.ra;uz aul fo apis siawto uolsslussuv — l'
ayl uo palvaol aq 11vgs aainap pauumulp aq; 'jauMo uozssiuisuv l
aqj wo f uolsslumad uanuM passajdxa painAoid ssalun Isasva 11v ul
•Ii jurimm of sisixo aznsodxa mil dm luaioijjns `luow2pnf saaliiunuoD
jumo2vurW aiiajul age ui `3i paiinboi aq osle (Luz golims ouil dri u
`p!J2 uoisstWSUL' l oql of suopoauuoo io3 pins oizloola aqj uzorj u0113auu03sip
jo uoijU3i3iaan olgisin apinoid pur `lauuoszad snumo uoissiuisuLzZ 31 11
,�q algiss000, XIipra.z pur algmnoas aq Isnw aoinap loauuoosip lionumz sitU
S uopaas uopvrauaf) i1 -uo)V jof saullapino uoyaauuoa.raiul
Interconnection Guidelines or Non - Utility Generation Section 5
523 Intentionally Left Blank
524 Protection and Control Devices
Certain protective functions and control equipment are necessary to ensure
that both the safety and reliability of the Railbelt system are maintained.
While the Producer is responsible for the installation and maintenance of such
equipment, it should be noted that the required equipment outlined in this
section apply only to the protection of the Railbelt system, not the Producer's
facilities. The minimum protective and control equipment requirements for
Producer -owned facilities are as follows:
■ Interconnection Circuit Breaker(s)
■ Anti - Islanding Protective Functions
— Overvoltage Protective Relaying
— Undervoltage Protective Relaying
— Overfrequency Protective Relaying
— Underfrequency Protective Relaying
■ Synchronization Protection:
— Synchronous Generators: Automatic Synchronizing with Relay
Supervision
— Induction Generators: Speed Matching Relaying
Due to the impact that larger facilities can have on the system, additional
requirements shall be necessary for such facilities, including but not limited
to:
• System Fault Protection Functions
— Ground Overcurrent Protective Relaying
— Phase -fault Protective Relaying
■ Transfer Trip Capability
■ Export Power Control Equipment
— Voltage Regulator/Power Factor Controller
— SCADA Control (including Balancing Area SCADA Control)
— Power System Stabilizer
Page 29
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Interconnection Guidelines for Non - Utility Generation Se ction 5
528 Protection & Control System Testing Capabilities
To allow performance and verification of functional testing, the Producer's
protective relays and control systems associated with the interconnection shall
have accessible sensing inputs or testing terminal blocks, or acceptable
equivalents as approved by the Transmission Owner and Balancing Authority.
Page 31
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S uoYaas uOymauag -uoAT jof saiglainng uoyaauuoma;uj
Interconnection Guidelines for Non - Utility Generation Section 5
2. Under / Overvoltage Protection
This protection is required in order to trip the interconnection circuit
breaker when the Producer's voltage level is above or below the
Transmission Owners nominal level at the point of interconnection.
a) Undervoltage protection (Device No. 27) must be set to initiate a
trip of the circuit interconnection circuit breaker when the
Producer's voltage level falls below a level approved by the
Transmission Owner.. Intentional trip time delays must be
coordinated with and approved by the Transmission Owner.
b) Overvoltage protection (Device No. 59), in general, must be set to
initiate a trip of the interconnection circuit breaker, with no
intentional time delay, when the voltage is equal to or above
110 percent of nominal voltage level at the point.
c) Specific under /overvoltage trip settings will depend on the
location, type, and size of the interconnected generation facility.
The Producer must coordinate with the Transmission Owner for
specific relay settings.
3. Under /Overfrequency Protection
This protection is required in order to trip the interconnection circuit
breaker when the frequency varies from the nominal of 60 Hz.
Generally, the following trip settings will be required for all facilities:
a) Underfrequency protection (Device No. 81U) will be set to initiate
a trip of the interconnection circuit breaker with delays and
setpoints required to coordinate with the Railbelt Underfrequency
Protection Scheme.
b) Overfrequency protection (Device No. 810) will be set to
initiate a trip of the interconnection circuit breaker when the
Producers voltage level raises above a level approved by the
Transmission Owner and the Intertie Management Committee.
4. Synchronization Protection
a) Synchronous Generators
Synchronous generators operated in parallel with the Railbelt
electric grid are required to have automatic relay supervision
(Device No. 25) to verify synchronism for permissive closure of
the interconnection circuit beaker. Facilities are allowed to
interconnect and operate in parallel with the Railbelt system when
the phase angle difference between the Producer's voltage and the
Railbelt system voltage at the point of interconnection is less than
Page 33
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Interconnection Guidelines for Non - Utility Generation Section 5
6. Phase -Fault Protection
Phase -Fault Protection is required for all facilities. This protection
senses phase -to -phase or three -phase faults on the Railbelt system and
initiates tripping of the interconnection circuit breaker in order to
prohibit continuous contribution to such faults from the Producer's
facilities.
Voltage- restrained overcurrent relaying (Device No. 50/51V) or
impedance relaying (Device No. 21) is required for phase -fault
protection. Prior to authorization for interconnected operation, the
Transmission Owner shall review and approve the phase -fault
protection scheme and trip settings.
7. Transfer Trip Capability
Communications Assisted Tripping may be required to allow Railbelt
system protection to disconnect the Producer's facility in order to
ensure that Railbelt system protection operates properly during system
faults or disturbances. The Producer shall provide a dedicated,
isolated digital communications circuit for this purpose.
Vi. Telemetry and Monitoring
1. Telemetry
All facilities are required to have equipment to continuously telemeter
data to the Balancing Authorities Power Control Center via approved
data communications lines provided by the Producer. Telemetering of
generation and transmission data is required to enable the system
dispatchers to continually monitor the power system from the
Balancing Authorities Power Control Center.
As a minimum, the following data and measurements shall be
telemetered to the Balancing Authority:
• Energy Flows (MWh)
• Real Power Flows (MW)
• Reactive Power Flows (MVAr)
• Voltage at Point of Interconnection
• Interconnection Circuit Breaker status
2. Monitoring
Page 35
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10.1Ju03 181#11Q ;aa i1Q •Z
•sanssi pun suoporuisui Inuopn.iado oijioads ioj iojua:)
IoaiuoD sailljoglnd 2ui3uning aria giim omuipi000 Iings iaonpo.zd OU
•lonaluoo osngo.md iomod agj 3o suuai oijioods agl uo 2uipu3dap sisnq
Inuosnas jo `.ipvp `Xlznog un uo alnpagos JdA ao 32VII0n paiJioads
soilizoglnd Ouiouning n molloj of pojinba.i aq Xnui ioan.iauoS agZ
•spinpunls gggl uigjim 2upi3s .io;on3 iomod agp guiuimuinui jo olqudno
aq jsnui ji `pazililn si jolloiwoo .ioion3 iomod n aiogm •spanpunls ggal
paaoxa jo 10aui pun `2upung inoglim `suoiiipuoo ;Dwis- Xpna ;s .spun
32nIIon juiod uouoauuooiaiui Inuiuiou oqi 2uiumnumw jo olgndno
aq isnui 1! `osodind sigl ioj pozilpn si aoinlnSai aSnJIon n azagM
•sliuzil pagioads
uigpim 32LJI IozIuoo 0 Japio u .1311011uoo .ioIon3 aamod jo aolnln2ai
30nIIon panoiddn un aaglia azililn of paambw oq �uw zaonpoid ags
aagoaluoa jolaug ja,tod/aojnlnWaH 32 n;I 0 A 'I
:loniluoo oijioads agp 3o suuai aqi gpim aounpa000n ui Xanss000u oq XLw
luauudmba i?uimollo3 aqj luauiaai2V 3uil3ailm uoissiuisuril n Jo luauiaa .12d
asngoand .zamod n alnlnuuo3 Al!lua .iagloun pun nonpotd agl azagm sasno iod
;uawdinb3 loj;uo,g JGmOd ;jodx3 111A
•soomynisip uialsAs 5uizAlnun
ui XIinioadso `s�?ol asagP mainaa 01 lq .5i.i aql an ng Iings Xiuotpnd Suiouning
aq.L •(SS:WW:14H) Xup jo auip pun mnp i?uipnloui `salgni.inn p03I0nal Jo3
duims auiil poziuoagou�s SdIJ n apinoid Iings zai?Sol mnp oqZ •sloOml Snlai
pun suoiluado snjnls .iapaaq 1inoiio uoiloauuoozalui oql Suipnloui `sjuauiala
uialsXs X03I 3o smnls oqj pun `Xouanbaij `s.idA `slInm `sJlon spiooai goigm
a02501 MVP IMISIP uinJuinui pun annq of paiinbaz are soijipon3 5uijnaauai? Iid
5 VI VO leuoi;eaadO '11A
- sisnq Innpinipui un uo 0311tuiuioD
ivauiaBnuvW aiiaiul �q pouiuualap aq Ipm 3uiioliuoui Slilnnb
iomod .ioj sluomimboi aqZ suoiliolsip oiuouuzq pun suoilninap
.�ouanbaa3 `sllams ao s2ns 02nII0n `asiou InoiAoala `suoiI.ioIsip
uuoJannm sn saounganjsip Bons paooa.i pun loalap of paiinboi aq
XL uialsSs 2uizoiiuoui aqj `sjuauxajinbaa ogloads aqj uodn BuipuadaQ
- s.Iauinsuoo 0 pazanilap aamod jo fI!ILnb
oqi ao uiaisXs oialoolo ilzglinZl zip jo aounuuojaad pmpums aqj Ioajjn
�las.zanpn uno flilion3 s, .iaonpoid age uioaj indino aqj jngj uoilnoipui
uu zo Inilualod n .iaglia si ongi wqi souiuuaiap �i!.zogind Suiouuing
3g1 0.13gm sasno ui paiinbai aq Ipm Suiaoliuoui XITILnb .iamod
S u uo mauag 11?gfl-uoN jof sauyapzng uo .qa555535515l
Interconnection Guidelines for Non - Utility Generation Section 5
Direct control (supervisory control) of unit output from the Balancing
Authorities Power Control Center may be required if the unit is to be
dispatchable by the Balancing Authority under agreement.
3. Power System Stabilizer
A multi node Power System Stabilizer (PSS) control system may be
required to provide necessary stability to the electrical system when
system power oscillations occur.
The necessity of a PSS will depend on the generator capacity and
characteristics, the location of the interconnection to the Railbelt
system, and the system voltage level at the point of interconnection.
Page 37
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•sisuq Iunp►ntpur uu uo polunisna oq
Iltm sluauiannbai luowdmbo agpods `s.iallanuoo lamod io3 pannboi �Iipo►d, j tou opgM :£ 0 1 0 N
•sivauzannbaj ogpads io3 L't,'£'S uOIIOzsgnS of ia3a1 :pannbai si ia22oi ujup Iz3i2►p d :Z MON
- sisuq Iunpin ► put
ue uo possassu aq Ipm puL smaw;mift Iunpuuuoo ogpods uo puadap Iiim sluawa.unbag :1 31O
(£ atoN aaS) pajmbag toN
uoisiniodnS ,Gulag /m i?uiziuolgauXS o►auwoand
s.za110nuoD .zamod
paiinbag
iuc,Culag 2uig3tuW paadS
siotunuag uoitonpul
polinbag
uoisinladnS ,Gulag /m i?uiz►uoigou.�S opuutoand
siotuzauoD odAl jupwiS puu snouorgou,(S
(Z a;oN aaS) pajmbag
gulfOoZ utuCl Iuuo►tuaado
poiinbag
AppquduD uoiaumunwwoD UIRG puu aoton
I atoN aaS
luowdmbg IoituoD JOmod uodxg
I 31 aaS
guijot►uoW Xl!luno i3mod
pazmbag
,Ct►IiquduD ,Glawolal
pojinbag
uo►toatold tlnu3-3sugd
paa►nbag
4ltqudvD dill ia3suuzl
pajtnbag
uolpoiold tlnu3 punoig
pazmbo -d
uoitoatold ,Couanbaajjanp
paimbag
uoitoatoid ,(ouonbwpopun
pazmbo -d
uoitoatoad a2ualonJ0no
paltnbag
uo►toatold a9ualon13pun
pwinbag
ioijua.ig ttnojiD uotloauuoonjul
polinbag
2upoioW tno/ul
paitnbag
suuaW toauuoos►Q panoiddV
suoiaulluisul IId
lua=jinbag
auautdmbg
kmwwnS sluauzaimbag luauzdmbg uotloouuooniui
S alan.L
Aaewwng s;uawa gnbay juawt#nb3 X/
S u0113as uoymouag iOlizill •uoAT jof sauzpapzng uozlaauuoa raluj
Interconnection Guidelines for Non - Utility Generation Section 5
540 Voice and Data Communications
The capability to make direct verbal communications via telephone with the Producer
or the Producer's facility designee is required for all facilities. Voice
communications must be provided so that operating instructions or notification of
system conditions can be given to the Producer or any designated operator of the
Producer's equipment as necessary. Accordingly, the Producer is required to provide
a 24 -hour accessible voice contact telephone number to the Balancing Authority.
Data communications capability is required so that electronic data and/or operating
instructions can be transferred between the Balancing Authority and the Producer's
facility as necessary.
550 Intentionally Left Blank
Page 39
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sa.71puaddV uo vjauaq 11?jn- uoA.ro sauz1aping uouaauuoa.ra ;ur
Interconnection Guidelines for Non - Utility Generation Appe ndices
APPENDIX B. FINAL APPLICATION FOR INTERCONNECTION
Page 41
Interconnection Standards for Railbelt Generation Glossary
GLOSSARY
For industry standard definitions of electric industry terminology not contained in this
glossary, please refer to the IEEE Standard Dictionary of Electrical and Electronic Terms,
IEEE Std 100.
M
ITA
The abbreviation for alternating current.
Abnormal Voltage
Voltage that is outside of the standard nominal voltage level.
Ampere (Amp)
The unit of current flow of electricity. It is the same with reference to electricity as is
the number of gallons per minute when referring to the flow of water. One ampere
flow of current is equal to one coulomb per second.
Automatic
Self - acting, operated by its own mechanism when actuated by some impersonal
influence as, for example, a change in current strength; not manual; without personal
intervention.
Automatic Circuit Recloser
(A) A self - controlled device for automatically interrupting and reclosing an
alternating current circuit with a predetermined sequence of opening and
reclosing, followed by resetting, hold closed or lockout (ANSI C37.60).
(B) A relay that controls the automatic reclosing and locking out of an AC circuit
interrupter.
Automatic Control
An arrangement of electrical controls which provide for opening and/or closing in an
automatic sequence and under predetermined conditions; the switches which then
maintain the required character of service and provide adequate protection against all
usual operating emergencies.
Available Fault Contribution
The maximum current that can be supplied to a fault (short- circuit).
Page 43
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•loauuoo mi jo iuiod zip Ir saouraealo
IIL aoj Siguo Sutziaogjnv agj si numo uotsstursucil oql •Iouuosi3d pazijoglnt? Xq
poifiim oq soomos nmod algissod iir jrgl puv saoinos nmod olgissod IIR wor3 palt?losl
,fIoialduzoo aq souil ao ivauzdmba agj Imp ivaauai? ui oju palunai? aq uuo uoissiuuod
eons ;)jojoq Iit?naad isnw go!gm suoilipuoD •ajil uruzng of snojoOmp slvpualod
Ivoliloolo w pazisnuo X-Ilmuou On goigm juawdmbo aagpo ao `sagolims `siolonpuoo
`saatm `oi �;turtxoad ;)solo ui awoo of ao tp!m IoLIuoo olut awoo of uotsstuuod
('91TWOM) aauv rval3
•Itnojio cogs tL jo asogl sL Bons `suoiitpuoo It?uuoug, pog!oads zapun sluauno
Sutpatq pug `auzp patjtoads v ao3 i?ui,i. o `i?uivw oslL puL suopipuoo 1moiio
lt iopun smanno 3uiVa.tq put? Suthuuo `guilm jo alqdro aoinap 3uigoltms d
.raalvarg �zna.rz�
S Iuautala Ivoliloolo jo uopoauuooaalut ud
;zna rzj
•fiitligt?dro gilm SlsnowXuouXs pasn oslr
si SitordrD •pal - ea si uzalsAs ao uoijuls `snjereddL `ltnouo uoisstuzsu it `.tauuojsu - exl
`autgani `aoiuzaua2 U goigm aoj pt'ol ag 1 (£) `suotIipuoo aainaas 2utlsixo aapun
algt?dt?o si li goigm jo wnwixLw agp `sllt?m 10 (VA) saaadutt? -1I0n ui u aAl2 XlluoidXl
`aotnap ao `snjuiuddu `autgouw a jo Xjiouduo ags (Z) `paw,ag XInpun 3uiwoo3q
jnogjim A=o Ipm aaim u luazmo ouioala jo saaadwu ui luonno jo iunouzr ag,l, (I )
fqzavdvj
07
,.raayvarg pnoiiD, ooS
jaxvarg
Ianal iomod ag!oads r of sdajs alatosip ui iolvjauoS r jo SuipLwj
palrvo7- -Yao1g
•ao.tnos aga XIILuuou
st Imp woisXs agp oiuo womno .to/pue 02LIllon aonpoilui 01 331Aap u 3o �I!p t? aqZ
paaf -y-?Vg
L q,
vssolo uopvrauag;lagllvg jof sprvpuviS uoyaauuoajajul
Interconnection Standards for Railbelt Generation Glossary
Cogeneration Facility
Equipment used to produce electric energy and forms of useful thermal energy (such
as heat or steam) - -used for industrial, commercial, heating, or cooling purposes- -
through the sequential use of energy.
Control and Protection
Control refers to the methods and means of governing the performance of the
generating facilities. Protection refers to the system of devices used to detect
abnormal operating conditions and to initiate tripping of apparatus.
Converter
A machine or device for changing alternating current (AC) power to Direct Current
(DC) power or vice versa, or from one frequency to another.
Current
The flow of electric charge measured in amperes.
0
DC
The abbreviation for direct current. As ordinarily used, the term designates a
practically nonpulsating current, such as the output of an electric battery.
Dead -End Structure
The structure on which a span of aerial conductors terminate or transition to an
underground circuit.
Demand
The rate at which electric energy is delivered to or by a system; normally expressed in
kilowatts, megawatts, or kilovolt- amperes.
Direct Transfer Trip
Transferal of a signal to trip circuit breakers at the remote end of a line.
Disconnect Device
A device whereby the conductors of a circuit can be disconnected from their source of
supply (IEEE 100 - 1984).
Page 45
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Sui,�Iddns `uotjulsgns zo niuoo uoiingizlsip uiuuz a ju 2uijnui2iso szolonpuoo jo las d
Japaad
•oml agj uaamlaq (on uv Ruipnloui) uoiioouuoo leuuougte
ue of 3uimo `amonpuoo .iaglour io punoai? of zolonpuoo auo wojj smolt imp mauno d
;ua in j ;lnv j
•sa2Ujlon mol pup sjuauno g2Tg ,�q paziaajom.rego `punoj,'? puL (s)asugd
uaamiaq jo sosrgd uaamaaq `uuasAs IuoTmala uL uo 1m3aio ljogs Ieuopuaiuiun ud
;lnvj
3
- k2jouo omoolo jo ooanos L of juauidmba jo aoaid zo
1inogo pozi2nuo -op L 13auuoo of luautdmba jo aoaid ao ITnoiio v of ARIIon XiddL" 01,
azillaug
ramod oujoala aanTlap of posn sw;DlsXs
uoilnq!jlsip pur `souTl uoissTuzsuLjj suo,,Lls uot,LjauoS paloauuooaaluT jo ui31sxs agZ
pug ClddnS 1v3.z43alV
•(zo��.�aua�
of jojo - a) •.iomod oialoolo oiui aamod lt?oiuugoow suuojsuuzl lugs auigouw d
.ro ;vraua� azgaal�
a
•uoisTnip pVoi algt'Is
Tim IaIILIJLd ui ojamdo of szojuaauoS pajoauuooiajuT salgnuo `juaolad £ XiiuoTcU;
`dooap paads 3U •anano 3tjsu3jourego aamod -paads s,aanoW owijd agj jo adols agZ
down
•uolllpuoo wma s lruuougt ut saonpoid I - egj (•aIo
`suoptuodo ioVaaq `uoTjuaaua2 ao puol 3o ssol uoppns `IIntj ` a) Iuana pauutldun ud
aauvq rn;s!a
vssolo uoymauag jjaqjjvW jof sprvpuv ;S uouaauuoarajuj
Interconnection Standards for Railbelt Generation Glossary
Flicker
Impression of fluctuating brightness or color, occurring when the frequency of the
observed variation lies between a few hertz (cycles per second) and the flicker
threshold (the frequency of intermittent stimulation of the eye at which flicker
disappears).
Forced Outage
Any outage resulting from electrical equipment failure, a control systems
malfunction, a design defect, operator error, or failure of mechanical systems integral
to the electrical output of a generating facility. a breakdown of the mechanical or
electrical equipment that fully or partially curtails the electrical output of the
generating facility.
Frequency
The number of cycles occurring in a given interval of time (usually 1 second) in an
electric current. Frequency is commonly expressed in hertz.
Frequency Deviation
A change in frequency from 60 hertz caused by a temporary imbalance of generation
and load.
Fuel
A prime movers' energy source.
G
Gang- Operated
A multiple pole switch in which all poles are operated simultaneously.
Generating Facility
A plant wherein electric energy is produced from some other form of energy by
means of a suitable converting apparatus, including the generation apparatus and all
associated equipment owned, maintained, and operated by the Producer.
Generator
The physical electrical equipment that produces electric power. Sometimes used as a
brief reference to a Producer.
Generator Reactive Power Capability
The amount of reactive power (VArs) that a generator can produce or absorb from the
electric system to which it is connected.
Page 47
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•ucajsAS oiawjo jjagj!gd Oqj ql!m �1i1iau3
SuiivaauaB s,aaonpoad zip jo uopaiodo jajjuaud ioj uoiloouuoo luoialoolo juois,igd oqj,
uo 3auuoa.ra;uj
(V86I g3gl) 'panaasaad Xjjuijuulsgns sdigsuoTlujaa
asugd agp tp!m j!noaio kmuzud Sj! Jo 32u110n ao luaaano agp `uoillodoad umoul
put aiiuijap u ui `jTnoaio kmpu000s sii ui oonpoadaa of popumui sT imp aauuojsuuai V
jawjofsuv ,L ;uawn.r;suj
I
Q661 - 619 9991) iI!juunb luluampun3 oql jo anlun Suu aql 01111011103 atuoUUUq agP
3o onjun (suu) Oaunbs urow loon oql jo oilua oqj su pauTjap si onjun Slgl •soiuouuug
jo oouosaad oqj of anp juauno ao 32u110n 3o anunn OUTS juluompun3 oqj jo uoiliolsiQ
uo? lio ;s!a azuoulivH
•oiuouuuq puooas oqi pajjuo si ,�auonbaaj juluompunj aqp Ooiml si jugj ,�ouonbaa3
R gllm luouodtuo3 u `oldmuxa and - Smonbaaj juju3TUUpun3 oql jo oldillnw lua ?ajui
uu si wqj ,�auanbaaj u 2uinuq ,�jijuunb ao Onunn 3ipoiaad u jo juauodwoo Iupiosnuis d
azuour.IvH
,iouonbaa3 ao puooas aad sojoXo Builouap uual aTU
PH) z ;.raH
H
•punoa2 oql
puu sao;onpuoo poziRaauo wow ao ouo u3omlog moi3 juauno oTaiaaja jumpualuiun ud
;Inv j puno g
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.i!noaio Oqj ui juowdmba jo aaaid ao ITnaaio u auau ao uo ouop 8uiag si Iiom Xuu ajTgm
,fJuo popunoiS On saolonpuoo 1Tnaaio `sasodand X13jus ao,d '(s110n) jutIualod luouloaja
jo oaaz aqi su ao aolonpuoa u su gjjn aql of i?uiaaajaa ui Thom luouloolo ui pasn uual H
puno g
•aamod ouloola
jo uoiingTalsip oql ao3 pasn `,saapaa3, pauual Slivaauai? `saolonpuoo jo - 3laomiou d
PluJ
vssolo uo mauag;1aQj!PM jof sprvpuv ;S uoyaauuo,?ja;uj
Interconnection Standards for Railbelt Generation Glossary_
The amount of current a switch or circuit breaker can safely interrupt.
Interruption
The loss of electrical supply to one or more consumers or facilities.
Inverter
A device that converts direct current (DC) power to alternating current (AC) power.
Island
A portion of the interconnected Railbelt system that has become isolated due to the
tripping of transmission system elements. ( "Local" Island - A portion of the
transmission system, often a single line, which is isolated from the main system and
energized by a local generator.)
Islanded
Separated from the rest of the electrical supply grid.
K
Kilovolt (W)
One thousand volts.
Kilovolt - Ampere (M)
The product of kilovolts times amperes. Used to refer to high voltage alternating
current systems.
Kilovolt - ampere - reactive (Mr)
A measure of reactive power that is required to regulate system voltage.
Kilowatt (kW)
An electrical unit of power that equals 1,000 watts.
Kilowatt -hour (kWh)
One thousand watts of energy supplied for one hour. A basic unit of electric energy
equal to the use of 1 kilowatt for a period of one hour.
Page 49
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•uos .iad p jo uopop lowip agl �q
,�Iiroijvuiojnu -uou polviodo si goiims ioauuoosip Imumu d - iomod 3o ooinos aql uioIj
1moiio p ioauuoosip oa pasn aoinap SUIgOIiMS lU3IUUg3aui 10 Si g3JIMS l oauu ooSip V
ga ;iMS pauuoasi 1vnuvn
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sasso7
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`summ.zado uoilvis Ilu 2uipaoo3z joj siaags 3pol -osool zo `}looq `oli3 joinduioo V
807
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uoijngi.iisip .io uoissiuisupil oijjoolo up 3o szolonpuoo owgj aql st 3o 1gBnogj �Iluu IoN
auT7
- iomod QAIIOUa3 i?uiflddns oligm .iomod luaa sgaosqu ioinj
.iomod Suipval R 2uinRq pRol V `XIZS.ianuoD •(sJVn) iomod OATIOU'03 i?uigaosqu oligm
(slit .iamod Inn sailddns ioloLj nmod 2uippal p gjim aojpaguo2 d - .iomod luai 3o
uogoomp alisoddo aqi ui smolt iomod DATIMW uagM sin000 zoiob3 iomod ,ftipval, d
.1013vg jaMod 81qpva7
vsso1!) uopv rauaq ;1a41zv1 jof sp rvpuv;S uoslaauuoa ra ;uj
Interconnection Standards for Railbelt Generation Glossary
Megawatt (MW)
One million watts.
10
Neutral
The common point of a star connected transformer bank, a point normally at zero
potential with reference to the earth.
Non - Utility Generation
Generation facilities that are owned and operated by a person or company other than
an electric power supply utility.
0
Ohm
The standard unit of practical unit in resistance of an electric circuit; generally the
resistance to the flow of electric current.
One -Line Diagram
An electrical schematic drawing which represents the phases of a three -phase
electrical system as a single line.
Online Reliability
[The number of unit trips (forced outages) times the unit output just prior to the trip,
divided by the number of online hours] collected over a specified period of time.
Open - Transition Mode
A method of switching generation from one system to another without connecting the
two systems. This can be accomplished by employing a transfer switch with break
before make contacts (breaks contact with one system before making contact to the
other system).
Outage
A condition existing when a line or a station is de- energized.
Output
The energy delivered by a machine or piece of apparatus during its operation.
Overvoltage
Page 51
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.raanpord
•i?uiplinq u uigpim suzalsXs uoiingialsip .zo `sjinoaio uoiingijlsip
Xjupu000s se Bons `XIlvool iomod 3o XIddns aluipounui age ioj s32VI10n zamol
gpim palsviwoo se iomod oploolo jo uoissiuzsuLml .zo3 posh a2VJIon XuL :zauuo3suL'zl
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sl zoiouj iomod juiHuj, d •osLgd ui ;Diu luauno pue a &IIlon aql uagm Xjiun si
.iolou3 .iamod aq L •osugd uaA? e Jo QSUIIon puu wouno aql uaampq aouajajjip 312uu
asL aql jo ouisoo oql si joloLj iomod •jamod wajuddu of iamod lunjou 3o oijuz aqy
.io ;avl JaMod
- Xsioua Smuuojsuuil zo 2uluojsu jo 31aa Own aqZ
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uozlaauuoa.ra ;uj fo;ulod
•ppS oploala jtagpX
aqj of iomod 2uiaanil3p Jo osodznd all; JOJ ao 30 5upundo s,iowolsno agp
zoj Xlolos aq XLw uoijuzado Iaiiujud 'Isaan aoin 10 AIilioLI3 SUTIU aua2 aqj 0 1 uz S
IiagpuN aqp wojj mold aaglia mo aamod uoilipuoo sup aapurl - ping oujoala llogl!u -d
aql of paloauuoo �11ROIJ1oala oligm zolmouag paumo aamoisno u jo uoijuaado oqZ
uoyvrado lallvjvd
F
•paui?isap si
uopsonb ui iuowdmba goigm joj ILgl ump zag2iq ao paaisop jugj uugi ragSiq oSMIon
vsso1f) uoymauaf) ilaqllv&r jof spivpuv ;S uopaauummajuj
Interconnection Standards for Railbelt Generation Glossary
Protection
All of the protective relays and other equipment which is used to open the necessary
circuit breakers to clear lines or equipment when faults or unacceptable operating
conditions develop within the power system.
Protective Devices
Devices used to protect equipment during abnormal conditions. This would include
protective relays, whose function is to detect power system conditions of an abnormal
or dangerous nature. It would also include circuit breakers or other interrupting
devices used to protect the generator, associated equipment, and the electrical system
to which the generation is interconnected.
Protective Relay
A device whose function is to detect system faults, defective lines or apparatus, or
other power system conditions of an abnormal or dangerous nature and to initiate
appropriate control circuit action.
I(N
Reactive Power
The component of total volt - amperes in an alternating current circuit where the
voltage and current are out of phase by ninety electrical degrees. It is measured in
units of volt- amperes reactive (VAr), kVAr, or MVAr. It represents the power
involved in the alternating exchange of stored energy in inductive and capacitive
electromagnetic fields. Although this type of power supplies no useful energy, it is an
inherent requirement for all alternating current power systems. By convention,
positive reactive power is "absorbed" by an inductance and "generated" by a
capacitance. Reactive power transferred over time is measured in VAr -hours (VArh).
Refer to Power Factor.
Reactive Volt - Amperes (VArs)
See Reactive Power.
Real Power
The component of total volt - amperes in an electric circuit where the voltage and
current are in phase. It is also called active power and is measured in watts (W), kW,
or MW. This is the electrical power associated with useful energy, including
mechanical work and heat. Real power used or transmitted over time is measured in
kilowatt -hours (kWh) or MWh.
Page 53
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(vlvp) alu1u pva2l
vssopo uo mauag;pagpzvy jof spivpuvjS uoyaauuoa.ra ;uj
Interconnection Standards for Railbelt Generation Gloss
The condition which occurs when a Producer interconnects with a local utility on the
secondary side of a distribution transformer, and other customers may also be
connected to the secondary side of the same transformer.
Short Circuit
An abnormal connection (including an arc) of relatively low impedance, whether
made accidentally or intentionally, between two points of different potential (IEEE
100 - 1984).
Single -Line Drawing
See One -Line Diagram.
Solid -State Equipment
Equipment that contains electronic components that do not use vacuum or gas filled
tubes. Discrete semiconductors (e.g., transistors, diodes, etc.), integrated circuits, or
other static components such as resistors and capacitors are used for the electrical
functioning of the equipment. Note: Equipment that uses a cathode ray tube for
display purposes, such as a television or computer monitor, may still be considered
solid -state if the other components within the equipment are solid - state.
Step -Up Transformer
A transformer in which the secondary winding has more turns than the primary, so
that the secondary delivers a higher voltage than is applied to the primary.
Stiffness Ratio
The ratio of system available fault current at the point of interconnection to the full
load rated output current of the installation.
Supervisory Control
A system by which equipment is operated by remote control at a distance by means of
some type of code transmitted by wire or electronic means.
Switch
A device for making, breaking, or changing the connections in an electric circuit.
System
The entire generating, transmitting, and distributing facilities of an electric supply
utility.
System Emergency
A condition on a utility's system which is likely to result in imminent significant
disruption of electric service to consumers. or is imminently likely to endanger life or
property.
Page 55
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vssolo uopvrauag jjagj?vM jof sprvpuviS uogaauuoa.rajul
Interconnection Standards for Railbelt Generation Glossary
A display or indication that a circuit breaker has tripped. This indication can be in
the form of relay targets, annunciator alarms, sequence -of- events recorder logs,
SCADA alarms, etc.
U
Undervoltage Protection
Upon loss or reduction of voltage, the protection device which interrupts power to the
main circuit and maintains the interruption.
Uninterruptible Power Supply (UPS)
A power conditioning and supply system that provides a continuous source of power
to equipment (e.g., computer systems) during short-term power outages or surges.
V
VAr (var)
A unit of measurement of reactive power. It is an expression of the difference
between current and voltage sine waves in a given circuit where:
var = 4(va) — ( watt) 2
Volt
The difference of electric potential between two points of a conductor carrying a
constant current of one ampere, when the energy dissipated between these points is
one watt. Analogously, this is comparable to the pounds per square inch pressure in a
fluid system.
Volt - Ampere (VA)
Page 57
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Interconnection Standards for Railbelt Transmission
Table of Contents
Section 1: I ntroduction ......................................... ............................... 4
110 How the Standards are Organized .................................. ..............................
120 Operational Policy for interconnection to the Interconnected
Railbelt Electrical System .............................................. ..............................
140 Parallel Operation .......................................................... ..............................
150 Islandin 6
Section 2.• Interconnection Process and Application Procedure............ 7
210 Objectives ...................................................................... ..............................
220 Authority ........................................................................ ..............................
230 Process Review and Responsibilities ............................. ..............................8
Section 3.• Interconnected Operating Requirements ............................ 94
310
Inspections and Approval for Parallel Operation .......... .............................14
320
Discontinuance of Parallel Operation ........................... .............................14
330
Islanded Operation ........................................................ .............................
340
Voltage Requirements ................................................... .............................
341 Voltage Levels .................................................. .............................
342 Voltage Fluctuations ......................................... .............................
343 Voltage Regulation and Reactive Power Requirements ................16
350
Intentionally Left Blank ................................................ .............................
351
Intentionally Left Blank ................................................ .............................
352
Operating (Spinning) Reserve Requirements ............... .............................17
353
Non - Operating (Non - Spinning) Reserve Requirements ............................17
360
Harmonics ..................................................................... .............................
370
Power Factor Requirements .......................................... .............................
380
Coordination with the Railbelt Protective System ........ .............................18
390
Maintenance & Testing ................................................. .............................
391 Interconnection Equipment Maintenance ......... .............................18
392 Protective Systems Functional Testing ............. .............................19
Section 4. General Requirements ........................ ............................... 29
410 Design Requirements .................................................... .............................
411 Design Documentation and Information ........... .............................21
412 Protective Systems and Equipment ................... .............................22
413 Railbelt System Modifications .......................... .............................23
Page 1
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Interconnection Standards for Railbelt Transmission
Figure 1: Typical Secondary System Interconnection - Facilities ............................65
Figure 2: Typical Primary System Interconnection - Facilities ... .............................66
These Standards are subject to revision, at any time, at the discretion of the Intertie
Management Committee (as defined in the Railbelt Operating Standards). This
document is not intended to be a design specification.
Page 3
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Interconnection Standards for Railbelt Transmission
120 Operational Policy for interconnection to the Interconnected
Railbelt Electrical System
It is the operating policy of the Utilities to provide authorization for transmission
facilities to interconnect and operate in parallel with the Interconnected Railbelt
Electrical System, provided this can be done without adverse effects to personnel,
equipment, or system operations. The power to grant such interconnection
authorization is delegated to the Intertie Management Committee. Such authorization
is governed by and subject to adherence to the Alaskan Railbelt Operating Standards.
This document provides the general Standards and requirements to make such
interconnection and operation possible. All interconnected entities will be subject to
the requirements of the Alaskan Railbelt Operating Standards as adopted by the
Intertie Management Committee at the time of interconnection
In these standards, interconnection is defined as the electrical connection of
transmission facilities operated at a nominal voltage of 69 kV or greater. Parallel
operation is the condition where transmission plant operates while electrically
connected to the Interconnected Railbelt Electrical System. Under this condition, real
and reactive electric power can either flow from the Interconnected Railbelt Electrical
System to the transmission facility or vice versa.
Within these standards, the term `Provider' is used to refer to the owner(s) of
transmission facilities, or agents acting on their behalf, who have been authorized by
the Intertie Management Committee to interconnect and operate transmission plant in
parallel with the Interconnected Railbelt Electrical System. Also in these standards,
an `applicant' is defined as an individual or party who has applied for the
interconnection of transmission plant with the Interconnected Railbelt Electrical
System.
The operation of transmission plant in parallel with The System poses important
safety concerns for personnel and equipment. The safe, reliable operation of the
Interconnected Railbelt Electrical System is of the utmost importance to the Intertie
Management Committee. Accordingly, any interconnected transmission facility must
meet all applicable federal, state, and local safety codes and regulations, in addition to
the specific Standards and requirements contained in these standards, and, the most
current version of the Railbelt Operating Standards as adopted by the Intertie
Management Committee. The Intertie Management Committee requires those
applying for interconnection to obtain the services of an engineering professional,
who is expert in power system analysis, the design of wiring and of protection and
controls systems, including control and protection systems for transmission
equipment interconnected within small stability limited interconnected electric grids.
Electrical interconnections are inherently complex systems in terms of both design
and operation. Each proposal to interconnect to The System will be unique in
geographic location, operational characteristics, and impact to the interconnected
Page 5
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wiloauuoonlul lloglie2i ail slim uoiloauuoo im algeilaj
pue ajes a joj uoijeziaoilne uielgo ueo jueoildde ail iloiilm Xq pogl3w luaipadxo
inq qi?noioil e apinozd of si ssaoo.id uoiloauuoonjui jIagiir -d ail jo osodind ail,L
•sluouiaambai aoejiajui Xlililn pue Lmiajijo Ouilemdo Ieoiuiloai og!oods ail
auiuuajap 01 saausisop Mail jo �IizoipnV Suioueleg ajeiidozdde ail pue aajjiuiuioD
juauiaseueW oilialul aql Xq pozXILue oq `aao3aaoq `Iiim slesodoid IId 'Pij$ leoiijoalo
uoissimsuv j ;Iaql!v2f jOf sprvpuVIS uoyaauuoajajul
Interconnection Standards for Railbelt Transmission
Of primary concern are safety and reliability issues that may be present to The
System and its personnel under islanding conditions. Maintenance personnel must
have the assurance that any section of The System that has been de- energized and is
under a hotline order or working clearance will not be re- energized until there is
confirmation that they are physically clear of The System. Under an islanded
condition, such assurance to personnel must be provided by the transmission facility
following the appropriate Transmission Operators' switching and clearance
procedures. In addition, appropriate System frequency and voltage must be
maintained within the Island.
SECTION 2: INTERCONNECTION PROCESS AND
APPLICATION PROCEDURES
210 Objectives
These portions of the interconnection Standards contain an overview of the process
and required procedures to interconnect Provider -owned transmission plant with the
Interconnected Railbelt Electrical System. It also provides both administrative and
technical Standards to assist the applicant in obtaining such interconnection in an
efficient and consistent manner.
A Provider intending to operate transmission plant in parallel with the Interconnected
Railbelt System is required to complete an "Application for Operation of Provider -
Owned Transmission." The time required to complete the process generally depends
on the complexity of the proposed project. The applicant must provide the
appropriate Balancing Authority and the Intertie Management Committee with a
complete design package, including accurate machine modeling data in the PTI-
P /SSE format and system control and protection settings, so that the nature and extent
of system integration requirements may be determined.
• As a rule of thumb, the smaller the proposed transmission system (as a
percentage of the total system transmission plant) the more limited the design
review and study requirements will be.
The review of the interconnection facilities and analysis of the impact of the proposed
interconnection on the Interconnected Railbelt Electrical System will be evaluated
based upon preliminary power system studies. Several of the process steps may be
satisfied with an initial application, based on the detail and completeness of the
application and supporting documentation submitted by the applicant. Additional,
more detailed and rigorous studies may need to be accomplished depending upon the
outcome of the preliminary system studies. The Balancing Authority and the
Transmission Owner will clearly identify its costs related to the applicant's proposed
interconnection. The applicant will be responsible for full payment of the costs the
Balancing Authority and Transmission Owner incurs as a result of the applicant's
proposed interconnection.
Page 7
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sa11!1!gisuodsoy pua M ain ay ssaooad 0£Z
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llogliL oql gllm lallu.ud ui luuld uoisstuzsuutl alvaado put loauuooaalui of 2uliTsop
Xuud Xud •swou winbai lonuoo soil!joglnV 2umulug oql puL sluow3iinboi puu
sp upuuls u0113auuooaajui luuJolui saaumo uoissimstmil alui.zdoiddt aqp gptm .ildwoo
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411joyind OZZ
uoissimsumij jjaqjjvMtof sprvpuvls uo lauuoa rajul
Interconnection Standards for Railbelt Transmission
B. Data Collection
From the initial communication, or subsequent
Variable,
meetings with the Balancing Authority, the
depending on
applicant should have a clear definition of the
project.
required technical data and information
regarding the proposed interconnection. To
help expedite application processing, the
Balancing Authority will also provide guidance
as to whether both the Initial and Final
Applications should be submitted before
commencement of application processing.
To note, additional information may become
necessary during Step 2: Application
Processing The Balancing Authority will
coordinate with the applicant, in an expedient
manner, to resolve any additional information
issues.
C. Initial Application
When the applicant files the completed
Typically 10
Submittal and Review
application, the Balancing Authority will
business days.
perform a brief review of the submittal to
determine if any additional information is
required.
Actual costs associated with study and analysis
of the proposed interconnection will be borne
by the applicant. The applicant will be
responsible for up front payment of the
estimated costs associated with application
processing, study, analysis and reviews of
applicant data including administrative costs.
Estimated administrative costs will be paid at
the time on initial application filing. A deposit
in an amount equal to the engineer's estimate
of study costs will be made at the time of final
application processing. Actual charges will be
billed monthly against these deposit amounts
and periodic additional deposits may be
required depending on the requirement for
additional study due to study results or scope
changes.
Within fifteen business days of receiving the
application(s), The Balancing Authority will
respond in writing to the applicant, noting
receipt of the application. If no discrepancies
are noted, application processing will begin
upon receipt of processing fees from the
applicant.
Page 9
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fluiss000Jd uoi;egllddy :Z da ;g
uoissimsuvil ilaqllvy jof sprvpuv ;s uopaauuoarajuj
Interconnection Standards for Railbelt Transmission
B. Final Application
Final application processing generally involves:
180 days -1
Processing
a) Deposit payment of estimated additional
calendar year
study and analysis costs to be performed by
depending on
the Balancing Authority.
project scope and
b) Scoping and performance of complete and
resource
rigorous system analyses and studies, as
availability
required, to assess specific interconnection
requirements and necessary system
modifications;
c) Determination of facility- specific operating
parameters;
d) Determination of specific telemetry and
control requirements;
e) Review and assessment of applicable code
and standards issues associated with the
proposed interconnection.
f) Review operating terms of any Power Sales
Agreements and proof of acquisition of
ancillary services.
g) Performance of required baseline testing of
system response and recovery parameters -
voltage, Frequency, stability etc. at or as
close as practical to the point of Railbelt
Interconnection for comparison to
commissioning tests.
C. Response to
The appropriate Balancing Authority will provide
(Duration included
Application
a written response regarding the proposed
in Initial/Final
interconnection. This will include notice of any
Application
facility- specific interconnection requirements, and
processing time)
will address any outstanding issues or cost items
which the applicant may be responsible for.
Step 3: Interconnection Design Review & Coordination
Page I 1
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sulounlug aql Kq paluiliui aq Ipm Niom Bons
`uorloauuowalui posodold aql alupoww000u
of tinSSaoau Olt suolluog!Pow walsAs JI
•suoilu3i3iPow walsxs kmssaoau
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pun �li.zogjnV ,3utouujug oql glim) uopuuipl000
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agl 3o uoiluutpa000 puu mainaa soil!ioglnV
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u011nu1p ooD pun
naaznad uS1sda lou19 g
uozsssgursuv l ;1agllvy jof sp rvpuviS uoy3auuo3 ralul
Interconnection Standards for Railbelt Transmission
B. Construction and
Final Inspection
The applicant may proceed with interconnection
construction, coordinating with Balancing
Authorities' project manager for periodic
inspections, and final interconnection inspection.
Periodic inspections (and final inspection) will be
performed, at the discretion of the Balancing
Authority to ensure that that the interconnection
facilities meet the specifications of the approved
final design.
C. Final Acceptance
Following the completion of construction, The
Cost Reconciliation
Balancing Authority will authorize
and Ancillary
interconnection functional acceptance testing
Services Verification
(commissioning), as needed, to ensure that the
protection system set points, synchronizing
capabilities, telemetry and alarm outputs, as well
as, power quality are acceptable under the full
range of facility operating characteristics. All
Equipment will be commissioned tested in
accordance with the Balancing Authorities
current accepted commissioning practices and
under the direct observation of the Balancing
Authority's assigned technical personnel. The
Balancing Authority will be provided with copies
of all commission test records.
Prior to provision of the Final Interconnection
Agreement the Applicant shall reimburse the
Balancing Authority for all costs associated with
application processing, and/or system
modification work orders.
Prior to provision of the Final Interconnection
Agreement the Applicant shall provide
agreements (filed with the RCA, if necessary),
insurance and/or bonding fully detailing and
guaranteeing the ancillary services acquired in
compliance with Railbelt Interconnection
Standards and the requirements of the Balancing
Variable.
Variable.
Page 13
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S1N3W32lI 03M JNllVU3dO C13133NNO0831NI :£ NO1103S
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palnxwo oq uuo luau ow2V xmuldaood Iuui3
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gaigm ui aouaun000 noun 103 •�liliquilag auiluo
luuld uoissiwsuunl uoiloauuoonjui llagltug
aql jo napuiutuan aql 3o a5unanu ifutllon gluotu
Z aql poono lou Ism Xliliquilag auiluo `poinad
•aouutuno3nad
stgl 2uinnQ • i?utaq jo uoilunuloap
uodn 2utpu3dap
sloafond oql no s.Cup sl, jo naluan5 oql jo
poua
avow no sXuCl St,
poinad ftjujodo Imil r o2napun llim Xlitiouj aqZ
Buz ;viddo lo.uL •Q
uozssimsuv l j1a41ivg jof sprvpuvls uo�wauuowami
Interconnection Standards for Railbelt Transmission
The Provider shall discontinue parallel operation when requested by either the
Balancing Authority or Intertie Management Committee:
■ To facilitate maintenance, test, or repair of Interconnected
facilities;
■ During system emergencies;
■ When the Provider's transmission equipment is interfering with
Railbelt Interconnection Power quality or Reliability;
■ When an inspection of the Provider's transmission equipment
reveals either a lack of adequate equipment maintenance necessary
to protect the Railbelt Interconnection or conditions that could be
hazardous to the Interconnection.
330 lslanded Operation
Transmission plant is required to be able to operate in an islanded mode with a
portion of a Balancing Authorities Connected electrical load, unless this requirement
is waived by the Balancing Authority considering location, system constraints and
specifics of the transmission plant, or during system disturbances.
340 Voltage Requirements
341 Voltage Levels
For all N -1 and probable N -2 contingencies assessed against the boundary
dispatch cases adopted by the Intertie Management Committee at the time of
interconnection), and as identified in the required system studies, The
Providers interconnection shall not degrade the voltage response or profile of
the Interconnection at the point of interconnection.
When operating in parallel with the Railbelt Interconnection, the Provider's
voltage must be maintained within ±5 percent of the standard Railbelt system
voltage at the point of interconnection. For all N -1 and probable N -2
contingencies, as identified in the required system studies, the Provider's
voltage (at the point of interconnection) shall adhere to the ratings and
recommendations contained in the current American National Standards
Institute (ANSI) C84.1 Standard.. In addition, transient and dynamic voltages
shall exhibit strong swing convergence during disturbances.. The
Interconnection and interconnected Transmission plant will be protected by
appropriate excitation and voltage related protective relaying.
Page 15
9 [ aftd
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Interconnection Standards for Railbelt Transmission
equipment shall be immediately separated from the Railbelt system or visibly
disconnected until the problem is resolved.
350 Intentionally left blank
351 Intentionally left blank
352 Operating (Spinning) Reserve Requirements
The Provider shall be responsible for providing (or contracting for the provision of)
operating reserves to the Railbelt Interconnection. Reserves provided shall be in an
amount specified by the most current operating reserve policy approved by the
Intertie Management Committee and shall meet the requirements quality of response,
and geographic location set forth in that policy.
353 Non- Operating (Non- Spinning) Reserve Requirements
The Provider shall be responsible for providing (or contracting for the provision of)
non - operating reserves to the Railbelt Interconnection. Reserves provided shall be in
an amount specified by the most current operating reserve policy approved by the
Intertie Management Committee and shall meet the requirements of minimum start
time, quality of response, and geographic location as set forth in that policy
360 Harmonics
Harmonic distortion is defined as the ratio of the root mean square (rms) value of the
harmonic to the rms value of the fundamental voltage or current (refer to IEEE
Standard 519). Distortion of the harmonic content of voltage and/or current
waveforms can cause telecommunication interference, disable solid -state equipment,
overheat transformers, and create resonant over - voltages. In order to protect The
Railbelt equipment and consumers from damage, harmonics must be maintained
within acceptable limits. As such, for all N -1 and probable N -2 contingencies, as
identified in the required system studies, the interconnection of the Providers facilities
shall not be allowed to introduce harmonics into the system beyond those present
prior to Provider interconnection.
IEEE Standard 519 specifies a range of Total Harmonic Distortion (THD) limits
based on the size of the load with respect to the size of the power system. The
Provider's equipment shall not introduce, onto the Railbelt Interconnection, voltage
or current distortion in excess of the limits contained in IEEE Standard 519 or those
present prior to interconnection, whichever is greater. Specifically, voltage distortion
shall not exceed the limit outlined in Section 11.5, and current distortion shall not
Page 17
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Interconnection Standards for Railbelt Transmission
interconnection. Maintenance records, procedures, and results shall be made available for
the Intertie Management Committee's review and records as required. Depending upon the
characteristics and utility of the facility, The Intertie Management Committee may elect to
observe and inspect maintenance work in order to assure the safety and integrity of the
interconnection.
The Provider must coordinate and schedule maintenance on interconnection
equipment with the Balancing Authority
392 Protective Systems Functional Testing
Periodic functional testing of protective equipment (i.e., circuit breakers, switches,
disconnect devices, protective relaying, etc.) shall be defined and coordinated with
the Balancing Authority within the Agreement for Interconnection between the
Transmission Owner and the Provider. The Provider must grant the Transmission
Owner the right to observe functional testing of the Provider's facilities.
Generally, functional testing of protective relay settings and interconnection circuit
breaker operations shall be performed by the Provider per the manufacturer's
recommended testing interval. Documented test results must be provided to
Transmission Owner within five (5) working days after the completion of tests.
The Provider must grant the Intertie Management Committee the right to review and
modify the functional testing requirements, as necessary, during the life of the
facility.
Page 19
Interconnection Standard for Railbelt Transmission Section 4
SECTION 4: GENERAL REQUIREMENTS
490 Design Requirements
411 Design Documentation and Information
For review and reference purposes, the Provider shall submit the following
information and design documentation with the interconnection application(s)
(Refer to Appendix I. Applications for Interconnection). In certain cases some
submittal requirements may be waived, at the Intertie Management
Committee's discretion. The design documentation will need to be approved
by an electrical engineer, registered and recognized as a Professional Engineer
in the State of Alaska. Where this approval is required, it shall be indicated
by the presence of the engineer's professional seal on all drawings and
documents.
A. One -Line Diagram
This is a schematic electrical drawing with sufficient detail to show the major
elements of the facility electrical connections, interconnection and protective
equipment, and point of interconnection to the Transmission Owners electrical
system. The diagram should include the following:
■ Circuitry of the facility, to include conductor types, sizes, and bus
electrical ratings
■ Metering points and instrument transformers (as applicable)
■ Interconnection transformer
• Relays and circuit breakers /interrupting devices
• Switchgear (as applicable)
• Utility circuitry at the point of interconnection
• Plan and profile
• Reactive power devices (as applicable)
B. Three -Line Diagram (as required)
This schematic electrical drawing shall represent all three phases and
neutral connections of the interconnected facility circuits, showing
potential transformer (PT) and current transformer (CT) ratios and details
of their configuration, including relays, meters, and test switches.
Page 21
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Interconnection Standard for Railbelt Transmission Section 4
The Intertie Management Committee will accept only those portions of the
Provider's system designs which apply to the interconnection with, and
protection of, the Railbelt system. The Intertie Management Committee may
comment on other areas, which appear to be incorrect or deficient, but will not
assume responsibility for the correctness of protection pertaining to the
Provider's system.
At the completion of construction, functional tests of all protective equipment
must be performed and/or witnessed by designated Transmission Owner
personnel. In order to gain Transmission Owner approval for interconnected
operation, successful completion of the functional tests and verification that
protective relay criteria are correctly applied must be demonstrated and
documented.
413 Railbelt System Modifications
Any modification to the Railbelt electric grid, such as the installation of
additional equipment, reconductoring of all or a portion of the connecting
Transmission Owners line, or reconfiguration of Transmission Owners
protection systems necessary to permit in- parallel operation with the Railbelt
electric grid, will be performed by the Transmission Owner.
Where such system modifications are required to allow the interconnection of
the Provider's facilities, the Transmission Owner will perform these
modifications, providing all labor, materials, and equipment necessary, at the
Provider's expense.
420 Design Information -- Railbelt System
421 Standard System Voltages
The Railbelt standard system voltages conform to ANSI C84.1 standards, and
are outlined as follows. Specific voltage requirements and limits for
Provider's transmission plant are described in Section 3: Interconnected
Operating Criteria.
■ Transmission Voltages (line to line):
— 69,000 volts, three -phase
— 115,000 volts, three -phase
— 138,000 volts, three -phase
— 230,000 volts, three -phase
Page 23
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Interconnection Standard for Railbelt Transmission Section 5
SECTION 5: INTERCONNECTION EQUIPMENT REQUIREMENTS
590 Introduction
In order to simplify the process for determining the interconnection equipment
necessary to operate transmission plant in parallel with the Railbelt electric system,
the Intertie Management Committee has developed this section which outlines the
minimum interconnection requirements for Provider -owned facilities.
520 Overview of Required Equipment
This overview of required equipment and devices provides general descriptions as to
the components, including functionality, purpose, and responsibilities by both the
Provider and the Transmission Owner regarding ownership, installation, and
maintenance.
Specific requirements for Provider -owned interconnected transmission plant can be
found in Section 530: Equipment Requirements.
521 Metering Requirements
For all transmission facilities, the Intertie Management Committee requires
that "In -Out Metering" be utilized to capture the real power flows (watt -
hours) into and out of a Provider's facility.
It is the Provider's responsibility to provide, install, and maintain all facilities
necessary to accommodate metering. All meters shall be provided by the
Transmission Owner at the Provider's expense. Depending upon the specific
application required metering may also include the following:
■ VAr -hour metering
■ Real power (watt) demand metering
■ Reactive power (VAr) demand metering
522 Interconnection Disconnect Device
The Transmission Owner approved manual disconnect device must be
provided as a means of electrically isolating the transmission facility from the
Railbelt system, and establishing working clearances for maintenance and
repair work in accordance with the Transmission Owners safety rules and
practices.
Page 25
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Interconnection Standard for Railbelt Transmission Section 5
spot, and mechanical relief telemetered. Periodic gas analysis will be
required.
524 Protection and Control Devices
Certain protective functions and control equipment are necessary to ensure
that both the safety and reliability of the Railbelt system are maintained.
While the Provider is responsible for the installation and maintenance of such
equipment, it should be noted that the required equipment outlined in this
section applies only to the protection of the Railbelt system, not the Provider's
facilities. The minimum protective and control equipment requirements for
Provider -owned facilities are as follows:
■ Interconnection Circuit Breaker(s)
■ Anti - Islanding Protective Functions
— Overvoltage Protective Relaying
— Undervoltage Protective Relaying
— Overfrequency Protective Relaying
— Underfrequency Protective Relaying
■ Synchronization Protection:
— Auto Synchronizing
— Sync Check
Due to the impact that larger facilities can have on the system, additional
requirements shall be necessary for such facilities, including but not limited
to:
■ System Fault Protection Functions
— Ground Overcurrent Protective Relaying
— Phase -fault Protective Relaying
— Breaker Failure
— Buss Differential
— Transformer Differential
■ Transfer Trip Capability
■ Export Power Control Equipment
— Voltage Regulator/Power Factor Controller
— SCADA Control (including Balancing Area SCADA Control)
Page 27
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Interconnection Standard for Railbelt Transmission Section 5
depending on the specific determination. Refer to the specific requirements
under Subsection 530 for further information.
528 Protection & Control System Testing Capabilities
To allow performance and verification of functional testing, the Provider's
protective relays and control systems associated with the interconnection shall
have accessible sensing inputs or testing terminal blocks, or acceptable
equivalents as approved by the Transmission Owner and Balancing Authority.
Page 29
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Interconnection Standard for Railbelt Transmission Section 5
This protection is required in order to trip the interconnection circuit
breaker when the Provider's voltage level is above or below the
Transmission Owners nominal level at the point of interconnection.
a) Undervoltage protection (Device No. 27) must be set to initiate a
trip of the circuit interconnection circuit breaker when the
Provider's voltage level falls below a level approved by the
Transmission Owner. Intentional trip time delays must be
coordinated with and approved by the Transmission Owner.
b) Overvoltage protection (Device No. 59), in general, must be set to
initiate a trip of the interconnection circuit breaker, with no
intentional time delay, when the voltage is equal to or above a
level approved by the Transmission Owner.
c) Specific under /overvoltage trip settings will depend on the
location, type, and size of the interconnected transmission facility.
The Provider must coordinate with the Transmission Owner for
specific relay settings.
3. Under /Overfrequency Protection
This protection is required in order to trip the interconnection circuit
breaker when the frequency varies from the nominal of 60 Hz.
Generally, the following trip settings will be required for all facilities:
a) Underfrequency protection (Device No. 81U) will be set to initiate
a trip of the interconnection circuit breaker with delays and set
points required to coordinate with the Railbelt Underfreqency
Protection Scheme.
b) Overfreqency protection (Device No. 810), will be set to initiate a
trip of the interconnection circuit breaker, when the voltage rises
above a level approved by the Transmission Owner and the Intertie
Management Committee.
4. Intentionally Left Blank
5. Ground Fault Protection
Ground Fault Protection is required for all facilities. This protection
(Device No. 51N) senses phase -to- ground faults on the Railbelt system
and initiates tripping of the interconnection circuit breaker in order to
prohibit continuous contribution to such faults from the Provider's
facilities.
Page 31
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utalsSs Suianp XIiodoad salnaado uoilooload utalsfs llagj!gd lugl aansuo
of aapao ui Xliti3u3 s,aaptnoad otp loauuoosip o uoipooload uta lsXs
ltagtin2i moltn of paainbaa aq Sm 2utddtaZ paasissV suoilnoiuntutuoD
,f;iiiqudu3 dial aajsuu iZ •L
•s�?utllas dial puu auzagos uoiloaload
llnuj -asngd 3141 anoaddn puu nnainaa Ilugs numo uoissitusuna I,
otp `uotluaado poloouuooaalui aoj uotlurtaoglnu of aotad •uotloaload
ilnuj -asugd ao3 paainbaa st (iZ 'ON aoina(j) Sups vj a aouupodwi
JO (A19/09 'ON aoinaQ) SuiXnlaa luaaanoaano pautnalsaa- agnllOA
•saililion3
s,aapinoad agl uzoaj sllnn3 eons of uoiingtaluoo snonunuoo 1igigotd
of aapio ui aa)Iuaag ltnoaio uotloouuooaalui agl jo Ouidd soluiliui
put uzalsXs llagl!LW oql uo sllnu3 asngd -aaitp ao osngd- of -osugd sosuos
uotlooload siq L - sompon3 Ilu ao3 paatnbaa st uotloaload llnn,g -osugd
uoijaalo.id ;Jnud -asngd - 9
•sguillas dial pun
auzagos uoilooload llntj punoa2 agl anoaddu pun M3 1Aa a lings aaumo
uotsstutsunaZ oql `uoiluaado poloauuooaalui ioj uoiluziaoglnu of . 1011 d
's2utllas dial uo aaumo uoissitusuna I, gp!m oluuipa000 pun auzagos
uotloaload llnuj punoa2 oluiadoaddu un apinoad Iiugs aapinoJd O
9 u011,aas uolssgwsuv j jjaqj?vMlof prvpuvIS uoyaauuoara ;uj
Interconnection Standard for Railbelt Transmission Section 5
■ Interconnection Circuit Breaker status
2. Monitoring
Power quality monitoring will be required in cases where the
Balancing Authority determines that there is either a potential or an
indication that the output from the Provider's facility can adversely
affect the standard performance of the Railbelt electric system or the
quality of power delivered to consumers.
Depending upon the specific requirements, the monitoring system may
be required to detect and record such disturbances as waveform
distortions, electrical noise, voltage sags or swells, frequency
deviations, and harmonic distortions. The requirements for power
quality monitoring will be determined by Intertie Management
Committee on an individual basis.
V11. Operational Data Logging
All transmission facilities are required to have and maintain digital data logger
which records volts, watts, VArs, frequency, and the status of key system
elements, including the interconnection circuit breaker status operations and
relay targets. The data logger shall provide a GPS synchronized time stamp
for tracked variables, including date and time of day (HH:MM:SS). The
Balancing Authority shall have the right to review these logs, especially in
analyzing system disturbances.
V111 Export Power Control Equipment
For cases where the Provider and another entity formulate a Transmission
Wheeling Agreement, the following equipment may be necessary in
accordance with the terms of the specific contract:
1. Voltage Regulator/Power Factor Controller
The Provider may be required to utilize either an approved voltage
regulator or power factor controller in order to control voltage within
specified limits.
Where a voltage regulator is utilized for this purpose, it must be
capable of maintaining the nominal interconnection point voltage
under steady -state conditions, without hunting, and meet or exceed
IEEE standards. Where a power factor controller is utilized, it must be
capable of maintaining the power factor setting within IEEE standards.
The transmission plant may be required to follow a Balancing
Authorities specified voltage or VAr schedule on an hourly, daily, or
seasonal basis depending on the specific terms of the power purchase
Page 33
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aip �q pogolLdsip oq of si luotudmba all 3i paainbaa aq Xutu .ialuoD
loJIuOD Jannod soilizotpnV Ouiouulug atp woj3 siolvIn2w a &IIIon
Jo sotlol!ms poziioloui `sjoVaiq jo (lo.iluoo Aaosinzadns) to luoo loaiiQ
10.1Ju03 pj!21Q paaiQ •Z
•sonssi pue suoiporuisui puoiltaaado oipoads zo3 .ia;uoD lojiuoD
soili.ioulnVV SuiouUlUg alp uliM 31Buipa000 lllCus J3pinoJd X44, '10MIu03
S u0113as uoissimsuvjL Ilaqpvy jof prvpun ;S uoyaauuoa.rajuj
Interconnection Standard for Railbelt Transmission Section 5
/X. Equipment Requirements Summary
Table 5
Interconnection Equipment Requirements Summary
Equipment
Requirement
All Installations
Approved Disconnect Means
Required
In/Out Metering
Required
Interconnection Circuit Breaker
Required
Undervoltage Protection
Required
Overvoltage Protection
Required
Underfrequency Protection
Required
Overfrequency Protection
Required
Ground Fault Protection
Required
Transfer Trip Capability
Required
Phase -fault Protection
Required
Telemetry Capability
Required
Power Quality Monitoring
See Note 1
Export Power Control Equipment
See Note 1
Voice and Data Communication Capability
Required
Operational Data Logging
Required (See Note 2)
Automatic Synchronizing w/ Relay Supervision
Required
Note 1: Requirements will depend on specific contractual agreements and will be assessed on an
individual basis.
Note 2: A digital data logger is required; refer to Subsection 5.3.4.7 for specific requirements.
Page 35
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Interconnection Standard or Railbelt Transmission Section 5
This page intentionally left blank
Page 37
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suoi;eoiuntutuoq e;ep pua aoioA 0#9
S uoyaas uozssimsuv l llagj?PH jo prvpuviS uolxaauuoajajul
Interconnection Standard for Railbelt Transmission Appendices
APPENDIX A. INIT /AL APPLICAT /ON FOR INTERCONNECT /ON
Page 39
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saaTpua uolsszzusuml jjag1zngjo prvpun�s uopaauuoaraIul
Interconnect Standard
RailBelt Transmission
GLOSSARY
n this
For industry standard definitions of electric ry terminology and Electronic Terms,
glossary, please refer to the IEEE Standard Dictionary of Electrical
IEEE Std 100.
0
AC
The abbreviation for alternating current.
Abnormal Voltage
Voltage that is outside of the standard nominal voltage level.
Ampere (Amp)
The unit of current flow of electricity. It is the same with reference to electricity as is
the number of gallons per minute when referring to the flow of water. One ampere
flow of current is equal to one coulomb per second.
Automatic
Self- acting, operated by its own mechanism when actuated by some impersonal
influence as, for example, a change in current strength; not manual; without personal
intervention.
Automatic Circuit Recloser
(A) A self - controlled device for automatically interrupting and reclosing an
alternating current circuit t writh closed or lockout (ANSI C37.60). g and
reclosing, followed by resetting, hold
(B) A relay that controls the automatic reclosing and locking out of an AC circuit
interrupter.
Automatic Control
ical controls which provide for opening and/or closing in an
An arrangement of electr
automatic sequence and under predetermined conditions; the switches which then
maintain the required character of service and provide adequate protection against all
usual operating emergencies.
Available Fault Contribution
The maximum current that can be supplied to a fault (short- circuit).
Page 41
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paHuj oq s3amos .Tomod olgissod 111L wqi pule sao.�nos iomod algissod lit wo'ij palulosi
Slajaldwoo oq souil ao wowdinba agp ILtp luaaua.2 ut are paluua2 aq uuo uoissiuuad
eons aiojaq Iiunajd isnw goigm suoilipuoD •ajil uuuzng of snoaaSuup slum' d
Iuoi.z13310 Ile poziSaauo SIluuuou am goignn wouzdmbo jotpo io `sagol!ms `siolonpuoo
`sailer `oi Spunwid asolo ui owoo of jo igl!m IouIuoo olut auzoo of uotssiuuad
(8MRJOA0 aauvrvaB7
•11nmio hogs u jo asogi su gons `suoiiipuoo luuuougu pog!oods jopun sluazzno
5ui4uajq put `auzp paijioads u jo3 Su ituuo `Su'Vtu oslu puu suo imojio
Iuuuou npun sluanno dui uajq pup 5uihno `Sui7w jo alquduo aotnap 2uTg3jiens d
ja -yva rg jzno-q j
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`ouigrnj `jolunua2 L g oTgM z o3 pool agZ (£) `.suoTITpuoo aoinzas Supsixo aapun
alquduo si 1! goigen 3o wnwixuw agl `SIIL'm zo (VA) saaaduzu -1I0n lei WAIS XIILoidXl
`aotnap Jo `snjujuddu `3uigouw u jo Xi!ouduo ags (Z) :paivag Xlnpun 2uiwo
lnOIP!m X uuo ll!m wim u iva.uno oizaoala jo sonduzu ui luonno jo ;unouzu oq L (I )
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vssolo uogssimsuv l ;lagllvgio prvpuvls uopaauumialuj
Interconnection Standard for Railbelt Transmission G lossary
Cogeneration Facility
Equipment used to produce electric energy and forms of useful thermal energy (such
as heat or steam) - -used for industrial, commercial, heating, or cooling purposes- -
through the sequential use of energy.
Control and Protection
Control refers to the methods and means of governing the performance of the
generating facilities. Protection refers to the system of devices used to detect
abnormal operating conditions and to initiate tripping of apparatus.
Converter
A machine or device for changing alternating current (AC) power to Direct Current
(DC) power or vice versa, or from one frequency to another.
Current
The flow of electric charge measured in amperes.
F1
M
The abbreviation for direct current. As ordinarily used, the term designates a
practically nonpulsating current, such as the output of an electric battery.
Dead -End Structure
The structure on which a span of aerial conductors terminate or transition to an
underground circuit.
Demand
The rate at which electric energy is delivered to or by a system; normally expressed in
kilowatts, megawatts, or kilovolt- amperes.
Direct Transfer Trip
Transferal of a signal to trip circuit breakers at the remote end of a line.
Disconnect Device
A device whereby the conductors of a circuit can be disconnected from their source of
supply (IEEE 100 - 1984).
Page 43
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•omJ zqj uaamJaq (z)au uu guipnloui) uopoouuoo luuuoug,
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jua.i rn j j1nv j
•sagLIJlon mol pup sJuauno g2iq Xq pozilmoungo `punoB put (s)osugd
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Interc onnection Standard for Railbelt Transmissio
yiussuiy
Flicker
Impression of fluctuating brightness or color, occurring when the frequency of the
observed variation lies between a few hertz (cycles per second) and the flicker
threshold (the frequency of intermittent stimulation of the eye at which flicker
disappears).
Forced Outage
Any outage resulting from electrical equipment failure, a control systems
malfunction, a design defect, operator error, or failure of mechanical systems integral
to the electrical output of a generating facility. a breakdown of the mechanical or
electrical equipment that fully or partially curtails the electrical output of the
generating facility.
Frequency
The number of cycles occurring in a given interval of time (usually 1 second) in an
electric current. Frequency is commonly expressed in hertz.
Frequency Deviation
A change in frequency from 60 hertz caused by a temporary imbalance of generation
and load.
G
Gang- Operated
A multiple pole switch in which all poles are operated simultaneously.
Generating Facility
A plant wherein electric energy is produced from some other form of energy by
means of a suitable converting apparatus, including the generation apparatus and all
associated equipment owned, maintained, and operated by the Generation Provider.
Generator
The physical electrical equipment that produces electric power. Sometimes used as a
brief reference to a Provider.
Generator Reactive Power Capability
The amount of reactive power (VArs) that a generator can produce or absorb from the
electric system to which it is connected.
Grid
A network of conductors, generally termed `feeders', used for the distribution of
electric power.
Page 45
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cf,/ ndard for Railbelt Transmission
( ///rGI VV /s'IVVV��v •.
Interruption
The loss of electrical supply to one or more consumers or facilities.
Inverter
A device that converts direct current (DC) power to alternating current (AC) p ower.
Island
A portion of the interconnected Railbelt system that has become isolated due to the
tripping of transmission system elements. ( "Local" Island - A portion of the
transmission system, often a single line, which is isolated from the main system and
energized by a local generator.)
Islanded
Separated from the rest of the electrical supply grid.
K
Kilovolt (M
One thousand volts.
Kilovolt - Ampere (M)
The product of kilovolts times amperes. Used to refer to high voltage alternating
current systems.
Kilovolt - ampere - reactive (Mr)
A measure of reactive power that is required to regulate system voltage.
Kilowatt (kW)
An electrical unit of power that equals 1,000 watts.
Kilowatt -hour (kWh)
One thousand watts of energy supplied for one hour. A basic unit of electric energy
equal to the use of 1 kilowatt for a period of one hour.
Page 47
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Interc onnection Standard for Railbelt Transmission Glossary
N
Neutral
The common point of a star connected transformer bank, a point normally at zero
potential with reference to the earth.
Non - Utility Generation
Generation facilities that are owned and operated by a person or company other than
an electric power supply utility.
C
Ohm
The standard unit for measurement of resistance of an electric circuit; generally the
resistance to the flow of electric current.
One -Line Diagram
An electrical schematic drawing which represents the phases of a three -phase
electrical system as a single line.
Online Reliability
( 1, uo ' ) l OH
Where:
UT: Is the number of Transmission Line Trips
UO: Is the Transmission Line loading just prior to the Trip
OH: Is the number of Online Hours in the requirement period
Online Reliability is a measure of the impact to The System that transmission line
trips can have. Transmission Line trips at low loadings yields a low number as do
lines that trip infrequently.
Open - Transition Mode
A method of switching generation from one system to another without connecting the
two systems. This can be accomplished by employing a transfer switch with break
before make contacts (breaks contact with one system before making contact to the
other system).
Outage
A condition existing when a line or a station is de- energized.
Page 49
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Interconnectio Standard
Railbelt Transmi
Provider
One who produces electrical power and energy. In the context of the Interconnection
Standards, the term Providers typically refers to the owner and/or operator of
generation.
Protection
All of the protective relays and other equipment which is used to open the necessary
circuit breakers to clear lines or equipment when faults or unacceptable operating
conditions develop within the power system.
Protective Devices
Devices used to protect equipment during abnormal conditions. This would include
protective relays, whose function is to detect power system conditions of an abnormal
or dangerous nature. It would also include circuit breakers or other interrupting
devices used to protect the generator, associated equipment, and the electrical system
to which the generation is interconnected.
Protective Relay
A device whose function is to detect system faults, defective lines or apparatus, or
other power system conditions of an abnormal or dangerous nature and to initiate
appropriate control circuit action.
Provider
One who provides electrical transmission plant. In the context of the Interconnection
Standards, the term Provider typically refers to the owner and/or operator of
transmission plant.
0
Reactive Power
The component of total volt- amperes in an alternating current circuit where the
voltage and current are out of phase by ninety electrical degrees. It is measured in
units of volt- amperes reactive (VAr), kVAr, or MVAr. It represents the power
involved in the alternating exchange of stored energy in inductive and capacitive
electromagnetic fields. Although this type of power supplies no useful energy, it is an
inherent requirement for all alternating current power systems. By convention,
positive reactive power is "absorbed" by an inductance and "generated" by a
capacitance. Reactive power transferred over time is measured in VAr -hours (VArh).
Refer to Power Factor.
Page 51
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kivpuoaas
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ui paansrow si otup nano paiituisuuaj jo pasn zamod jt,a2j - ;vag puu liom jpoturgoaui
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.raMod pvad
•aamod anpORO -d aaS
(siVA) sajadiuV -11oA aa;avad
vssopo uossSZUisuvrs ipagpzvg io prvpuvls uopaauuoajajul
Interco nnection Standard for Railbelt Transmission Glossary
Separate System
A generating system which has no capability or possibility or connecting and
operating in parallel with the Railbelt system.
Setting (Protective Relay)
The values of current, voltage, or time at which a relay is adjusted.
Shared Secondary
The condition which occurs when a Provider interconnects with a local utility on the
secondary side of a distribution transformer, and other customers may also be
connected to the secondary side of the same transformer.
Short Circuit
An abnormal connection (including an arc) of relatively low impedance, whether
made accidentally or intentionally, between two points of different potential (IEEE
100 - 1984).
Single -Line Drawing
See One -Line Diagram.
Solid -State Equipment
Equipment that contains electronic components that do not use vacuum or gas filled
tubes. Discrete semiconductors (e.g., transistors, diodes, etc.), integrated circuits, or
other static components such as resistors and capacitors are used for the electrical
functioning of the equipment. Note: Equipment that uses a cathode ray tube for
display purposes, such as a television or computer monitor, may still be considered
solid -state if the other components within the equipment are solid- state.
Step -Up Transformer
A transformer in which the secondary winding has more turns than the primary, so
that the secondary delivers a higher voltage than is applied to the primary.
Stiffness Ratio
The ratio of system available fault current at the point of interconnection to the full
load rated output current of the installation.
Supervisory Control
A system by which equipment is operated by remote control at a distance by means of
some type of code transmitted by wire or electronic means.
Switch
A device for making, breaking, or changing the connections in an electric circuit.
Page 53
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Interconnection Standard for Railbelt Transmission Glossary
A change from the steady -state condition of voltage or current, or both. Transients
can. be caused by a lightning stroke, a fault, or by switching operation, such as the
opening of a disconnect, and may be readily transferred from one conductor to
another by means of electrostatic or electromagnetic coupling (IEEE 100- 1984).
Transmission Facility
Transmission plant includes all substation equipment and associated facilities used in
the transfer of electric energy from one location to another and or used to step up or
step down the voltage entering or leaving or on such facilities owned, maintained, and
operated by the Transmission Provider.
Transmission Line
A line used for electric power transmission. Distinguished from a distribution line by
voltage. Typically in the Alaskan power transmission system, lines rated 69 kV and
above are transmission lines.
Trip Indication
A display or indication that a circuit breaker has tripped. This indication can be in
the form of relay targets, annunciator alarms, sequence -of- events recorder logs,
SCADA alarms, etc.
U
Undervoltage Protection
Upon loss or reduction of voltage, the protection device which interrupts power to the
main circuit and maintains the interruption.
Uninterruptible Power Supply (UPS)
A power conditioning and supply system that provides a continuous source of power
to equipment (e.g., computer systems) during short -term power outages or surges.
V
Page 55
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BULK POWER SYSTEM FACILITY AND END
USER INTERCONNECTION REQUIREMENTS
TO THE RAILBELT TRANSMISSION SYSTEM
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XX SUPERVISORY CONTROL AND DATA ACQUISITION
SCADA ..................... .............................
XXII.
OPERATIONS .............................................................................................................
.............................
XXIII.
VOLTAGE ....................................................................................................................
.............................
XXIV. REACTIVE POWER
CONTROL ................................................................................
.............................
XXV. RESPONSIBILITIES DURING EMERGENCY
CONDITIONS ............................. .............................
XXVI. MAINTENANCE OF
FACILITIES .............................................................................
.............................
XXVII. FUTURE
MODIFICATIONS ......................................................................................
.............................
XXVIII. DELIVERY POINT POWER
FACTOR ..................................................................... .............................
XXIX. DELIVERY POINT POWER
QUALITY .................................................................... .............................13
XXX. DELIVERY POINT
METERING ................................................................................
.............................
XXXI. DELIVERY POINT AUTO -
RESTORATION ............................................................ .............................
XXXII. DELIVERY POINT
GENERATION ...........................................................................
.............................
XXXIII. DELIVERY POINT PARALLEL
OPERATION ........................................................ .............................13
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V. Intentionally left blank
VI. Responsibilities
It is the responsibility of the facility owner to provide all devices necessary to protect the
customer's equipment from damage by abnormal conditions and operations that might
occur on the interconnected power system. The facility owner shall protect its equipment
from overvoltage, undervoltage, overload, short circuits (including ground fault
conditions), open circuits, phase unbalance, phase reversal, surges from switching and
lightning, over and under frequency conditions, and other injurious electrical conditions
that may arise on the interconnected system.
It is the responsibility of the facility owner to provide for the orderly re- energization and
synchronizing of their high voltage equipment to other parts of the electric system.
Appropriate operating procedures and equipment designs are needed to guard against out
of synch closure or uncontrolled energization. Each facility owner is responsible to know
and adhere to all applicable regulations, industry guidelines, safety requirements, and
accepted practice for the design, operation and maintenance of the facility.
VII. Site Access
There are situations where some equipment that is owned by the local Transmission
Owner is located within the Customer's facility. This is often required for data
acquisition or metering. In these cases, installed equipment owned by the local
Transmission Owner will be clearly identified as such on the appropriate station
drawings, on the reference documents and at the site. Site access is to be provided to the
local utilities' employees where their equipment is located within the Customer's facility
or property.
VIII. Safety
Safety is of utmost importance. Strict adherence to established switching, tagging and
grounding procedures is required at all times for the safety of personnel and equipment.
Any work carried out within a facility shall be performed in accordance with all
applicable laws, rules, and regulations and in compliance with Occupational Safety and
Health Administration (OSHA) and prudent utility practice. Automatic and manual
disconnect devices are to be provided as a means of isolating all energy sources from any
particular element of the power system.
IX. Unbalanced Phases
Unbalanced currents and voltage are to be controlled by each party on their respective
side of the interconnection. However, it should be realized that switching devices, such as
breakers and switches, are three phase devices and can fail with only one or two poles
closed. It is the responsibility of the facility owner to protect their own equipment such as
generators or transformers from damaging negative sequence currents or voltage.
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loauuoosip polmodo iiuri? e XIILIOIC I `aoinap 2uiInlosi sigZ •uopoauuoojajui jo juiod agl
lE paljnIsui aoinap �?uiJVIosi uL 3ALq jsnw Xaiaogpnd 2uiouvlrg Fool agp ,�q pollowoo put,
pmuodo Xlalos jou are jugj wolsXS luoiijoolg ilogIiL,2I agj of 2upoauuoonjui soij!pou3
•sIoauuoosip zo
sagoiims poumo .zasn pug Wv jo puage palpool aq Ilugs siouuojsuwj luouno put 02n1I0n
Suuajauz s,aaump uoissiuzsutJZ fool agZ •aoinap Suildnualui Xitwijd u g2no ql uzajs,�S
luoiMoIg jlogiiv2I agp of paloauuoo oq jsnw Xliliou3 2upoauuoonjui agZ •olquopouad
su iuiod uoiloauuoozajui aga 01 asolo SU papinoid aq pinogs juauzdinbo 2?uij;)I;) w
-juiod ams agl air uopoouuooaalui jo juiod agj put digsiaumo
. II!povj jo 32utgo agl �Ilvnsfi •pogi.iosap XIrealo aq of si uoiloauuoonjui jo juiod ;DqL
u0113auuoaja;ul 3o Juiod -X
Reliable station and breaker arrangements will be used when there are new or substantial
modifications to existing Railbelt System switching stations affecting transmission lines
rated at or above 69kV.
XII. Structures
Transmission and substation structures for facilities connected to the Railbelt
transmission system shall be designed to meet the National Electrical Safety Code
(NESC). Substation bus systems shall be designed to comply with ANSI/IEEE Standard
605, IEEE Guide for the Design of Substation Rigid -Bus Structures.
XIII. Grounding
Each interconnection substation must have a ground grid that solidly grounds all metallic
structures and other non - energized metallic equipment. The transmission line overhead
static wire (if installed) shall be connected to the substation ground grid.
All transmission line structures must be adequately bonded and grounded to control step
and touch potential in compliance with the NESC, and to provide adequate lightning
performance. All ground wires and bond wires must be adequately sized to handle
anticipated maximum fault currents and duty without damage.
Transmission interconnections may substantially increase fault current levels at nearby
substations and transmission lines. Modifications to the ground grids of existing
substations and static wires of existing lines may be necessary. The interconnection
studies will determine if modifications are required and the scope and cost of the
modifications. Such costs will be borne by the end user.
The neighboring utility must have an effectively grounded transmission system.
XIV. Intentionally left blank
XV. Insulation Coordination
Insulation coordination is the selection of insulation strength. Insulation coordination
must be done properly to ensure electrical system reliability and personnel safety. Basic
Surge Level (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.
XVI. Ratings
The proper rating of facilities is the responsibility of the owner of those facilities. Ratings
of facilities must conform to the requirements of the Alaska Railbelt Facility Standards.
•sanssi nillo ou suq aaumo uoissiwsuuj L Irool
aql papTnoid p3zi2nm aq of uotloauumiolui zip liuuad of numo uoissiwsuu.IZ Iuool
aql mollu Bugs aaliturwoD ;uawz& anjolul `poilddt Xpoonoo uaaq anWq s2utalas
XRIa.z aniloalord zip puu `Injssaoons oju sisal asagl jj - sisa l gons ssoultm of ig2ij oql
anRq IlUgs pun Outlsaa gons jo oopou algruosuaa papinord ag hugs .sumo uoissiwsuril
aqZ •.zaumo uolssiwsuLjjL Fool oql of alg idaoou lauuosrad po!j!lunb q pouuojrad
oq hugs luowdmbo anrloalord liL, 3o sisal Imopounj `uoporulsuoo 3o uoijaldwoo oql 1d
•suopullnlsui autos joj pazmbw si diii aajsuu.r1 V
•Iuowdmba annoaiozd oqi of zamod ajolsoi of uoilov 3jvip3ww1 a�fuj Iltgs oqm saaumo
sopilloq oqj Xq SUIJOIiuour aIouraa JOJ papino.rd aq Isnw uurIv 321631I0n.Mpun ud •saotnap
i3uiddua Ile aluaado of Xliouduo gSnoua gjim pazis aq of si Xiallug aqL •suoiluisgns
IIU JU Paptnoid aq Ism Ioaiuoo pue Ouiddun ao3 aoinos aamod hoijuq aftzols DC[ d
•suorjuzapisuoo og!oods
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sli Iiuzgns hugs uzalsXs jIaglir2i aqp glim lollurud ui paluaado aq of si goigm XIglou3 gong
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paziu ildo su llam SU `saornap 2upicuipi000 uaamIoq .�I!A1I!suas ojunbapu aoj apinoid Isnuz
u21s3p aqj, •uoimlord 3o auoz uan12 v urgpim drgszaumo jo juiod aga jo apis gons uo pasn
aq Ism luauzdmba 2up rj z ojgtjuduzoD - soured oml uaamlaq uotloaloid jo auoz uourruoo
r oiugs Xuuz suulsXs i3mod ftuiofpd - wolsXs x3mod paloouuoojui oql uo pozillin
oq of aje suzalsXs futrealo jjnu3 puv sXvlar aniloalozd Ianal uoissiuzsuR .11 `apnz2 XIII!Ifl
ui njag aetlaaJOJd - IIIAX
•poziwiuiw Xilliquis wojs�s of saouonbasuoo
asaanpn glim s3n1jBW3jjR u2 1sap JIB ui paaapisuoo aq o azu luouodwoo wolsXs
uorloaloid L jo 31riodo of aanl!Lj aq; gptm sllnn3 asugd aargZ •IauuLgo uoilvoiunuzuzoo
jo `ioVojq `,Knlaa aniloaloid `.rauuojsuuaj luauno u jo aznlrej snoauulInwis agl
glim jInvj walsSs L 3o 2uinolo sopnloui srq jL •Iuouodwoo walsXs uopoaioid u jo alujado
of ajnl!Lj aql glim slinuj punoa2 of ouil alSuis joj algvis aq Isnw wolsXs aamod aqZ
•slInvj asngd .3ojgi IIv 3o Ouinolo Imuou aoi
paureaumw aq of si �Iipgvls jolvmua2 pun woisXS •slozluoo oilmolnu jo uoijundo joiju
uorjuaolsar pidvj 3o alqudno pue sliuril Xouo2jowo sli uiglrm oq hugs wzjsfs oql `parmbar
aq kour slmojio uoissrursuLjl jo 2uiuodo ao/puu pool jo uotldnualui polloaluoo aligm
;ianaaS uials S pun jiltg MAX
When connection a Developer's project to The System, all additions or changes required
on the Railbelt Electrical System shall be installed by the local Transmission Owner at
the Developer's expense. All additions or changes to relay and control equipment
required at the point of interconnection shall be paid for and installed by the Developer.
Entities connecting to the Railbelt transmission system shall investigate and keep a log of
all protective relay actions and mis- operations as required by the Railbelt in compliance
with these standards.
Entities connecting to the Railbelt transmission system must have a maintenance program
for their protection systems. Documentation of the protection maintenance program shall
be supplied to Railbelt, the NPCC, and NERC on request. Test reports as outlined in the
maintenance program are to be made available for review by Railbelt and the NPCC. At
intervals described in the documented maintenance program and following any apparent
malfunction of the protection equipment, the entity shall perform both calibration and
functional trip tests of its protection equipment.
XIX. Transmission Reclosing
The Railbelt Electrical System operator may automatically and manually test its
transmission lines following breaker operations for system faults. This is required to
minimize customer outage time and maintain system stability. Manual reclosing and
sectionalizing may also occur. Interconnected facilities must not interfere with the
Railbelt's operator's ability to quickly restore transmission lines following system faults.
Any entity wishing to interconnect with the Railbelt Electrical System must address the
implications of automatic reclosing in their design.
Automatic reclosing on interconnected transmission lines between utilities will be
handled on a case -by -case basis. Transmission interconnections between utilities may be
restored from either direction depending upon the reclosing practice agreed by the
utilities involved.
XX. Meterin
Metering equipment may be located at either end of the transmission line but should be
installed at the station closest to the change of ownership per the requirements of the
local Transmission Owner.
XXI. Supervisory Control and Data Acquisition ( SCADA)
Each installation needs to be evaluated separately for SCADA requirements by the Local
Utility because of the many possible contractual agreements and interconnection
configurations. The following data, at a minimum, is to be provided. MWh delivered,
MVArh received, MVArh delivered, Voltage, Current, +/- MW, and +/- MVAr, breaker
qi!m palnpogos puu pmuipz000 aq isnuz aouuualulM pauuuld •xsta It, uzalsXS IVOIJIoalg
ilagl!u2I aqi jo Si!p t,duo jo X1tITquijai aqj aot,ld jou saop Imp jouum u ui pauuo3rad
aq llugs wzlsXS luouioalg iIagITu2I ;DIP of pajoauuooaajuT sQlj!j! 3o aouuuajulvw
•satlTlTouj p3133uu00jaluT 3o uot;uzado zo `i?uijoliuow `uopoaioid
aqj joajja igSiw wqi wotudinbo aatnaaS Jo Ino Xuu Inogt, olguopouid su uoos su paTjIlou
aq of sT .sumo uoissiwsuujL luool 3q1, •sainp000id put saopowd ,izjsnpui Xiil!ln juaprud
ql!m aout,pr000u uT pauTmim oq of a.ru mc)IsXS JOmod )ling oq; uo saTjTITot i?ululofpd
satlIRM Jo aauuualul N •IAXX
•.iowuado uralsXS .sumo uoTssimsuu.11
luool oqj Xq pajowip st pool zasn puo aonpai jo `Ino io u1 saijTlTou3 gojims `.ramod
anrIot,aa isnfpu Ilugs jowaado Xl!lTouj age `suoTj!puoo ,�ouaj?.zauza 2?utanCl - jowmado wolsXS
zaumo UOISSTuzsuu.r 1, Iuool aql ql!m 31vwpl000 puu avoTunuzruoo of pajmbaa am uori?az
ilaglTu2I all uT swzlsXs uoTsslwsuuJI aql of pa13auuo3zaluT saTiTiTot,3 jo sioluaado IIV
suo.1. uoj aua .iautg aujinp sailillglsuo sag •AXX
3 Iuulg I3 Iluuollualul •AIXX
3Iuulg I3aI Iluuoilualul •IIIXX
•uzaisXs Iuoimaig jiagiTu2i aqi uo Xl!lTquTlaa zo smolt
.ramod `saSu110n PQJJR Xlasaanpu pinom jugj 2ulgollms Xuu 5uiuuo3aad aaojoq iojaiado
uzalsXS .iaumo uolssltusut,JZ Iuool oqi ,ijpou Isnw uulsXS Immoaig iIaglTu?I aql of
2uiloauu0o.zaluT sompouj jo si u odo •.iowuodo wolsXS .sumo uoTsslwsuurZ Iuool aql 3o
lt aoud inogl!m wolsXS luoTmaig Ilogpv - d aqa loajju Xlasaanpu XL'W Iugl Jo W31sxS
iuoT. mig iloglTud agp jo suomod sozTRzauo -op jo sozT2zauo jugj 2uTgollms Cut, uuo3.r0d
1ou Isnuz uzalsXS Iummalg IlogipuX aql of fuiloauuooaaluT s jo ioviodo aqZ
sar�TlTou3 paIoauuooraluT
of zn000 sa .Wut,go uagm papTnoid aq of aau sw1aiSuip pawpdn •1sanbaa uodn zojj! nuoD
luauz02t,ULM aTualul aqi of pagsiwnj aq isnw swaiii rp auTl ouo uzaisSs juaunD
suopmla O •IIXX
- airs ioafoad gouo ju paiinbaa
aq Ilugs `aadolanaQ aq; Xq aoj pTt,d put, `iaumo uoTssimsuuj 1, pool aql ,�q pasugaind (ITufl
lt,uTuu;DJL alouzag) fl L woisXs (uoij!smbod t,IuQ put, IOJIUOD XJosTnaadnS) VVQdDS d
•swau o.unboi asogi
iaaw of podolanap oq IITm su0Tsop oTjToadS •sw;DisXs uoTjuoTuntuwoo/uolluuuojuT sno
q .3nojgl sap and snor.run 01 paptnozd aq of paau Xuw ujup sigZ •suoil!sod gaiTms put,
the local Transmission Owner. The local Transmission Owner's switching and safety
procedures shall be strictly observed when maintenance is performed on an
interconnection.
XXVII. Future Modifications
Any changes that affect an interconnection must be reviewed in advance of such
modification. These include modifications to the metering or protection scheme as well
as associated settings after the interconnection project has been completed. Information
about expected increased load flows or higher fault currents levels due to system changes
must be provided in a timely manner to the Local Utility.
XXVIII. Intentionally left blank
XXIX. Delivery Point Power Ouality
Generation of harmonics should be at a level that will not degrade the performance of the
Railbelt Electrical System.
XXX. Intentionally left blank
XXXI. Intentionally left blank
XXXII. Intentionally left blank
XXXIII. Intentionallv left blank
A Reserve Capacity Planning Criteria
A -1.1
1.1.1 Each Load Serving Entity is expected to maintain responsibility to provide
capacity for its own firm load. As part of such responsibility, shall
maintain or otherwise provide for annually, Accredited Capability, in an
amount equal to or greater than its maximum System Demand for such
year plus the Load Serving Entities' Reserve Capacity Obligation, as set
forth in Subsection A- 1.1.2.
1.1.2 The Reserve Capacity Obligation of a Load Serving Entity, for any year,
shall be equal to thirty (30) percent of the projected Annual System
Demand of that Load Serving Entity. The Reserve Capacity Obligation of
the Load Serving Entity may be adjusted from time to time by the Intertie
Management Committee.
1. 1.3 The Intertie Management Committee may determine the annual
Accredited Capability for each Load Serving Entity.
B Responsibility for Operating Reserve
B -2.1 Operating Reserve
2.1.1 Each Load Serving Entity and Generation Owner shall provide, or contract
for, Spinning Reserve and Non - Spinning Reserve as required by Section
B -2.2 of this Article equal to or greater than the Operating Reserve
Obligation of the party. As soon as practicable, but not to exceed four
hours, after the occurrence of an incident which uses Operating Reserves,
each Utility Participant shall restore its Operating Reserve Obligation by
the procedures determined by the Intertie Management Committee.
2.1.2 The Operating Reserves, Operating Reserve Obligation, System Reserve
Basis and Allocation calculations may be modified or adjusted from time
to time by the Intertie Management Committee.
2.1.3 The System Reserve Basis (SRB) is equal to the Largest Generating Unit
Contingency of the system or other such value as determined by
engineering studies.
B -2.2 Total Operating Reserve Obligation
2.2.1 The Total Operating Reserve Obligation at any time shall be an amount
equal to 150 percent of the System Reserve Basis of the Railbelt Electric
Grid
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peol So!l!lug ogj anoiddu pue nnainaz Ilegs ooillunuoD juotua2uuvW
oiliowl aqZ - wolsXs jjogpw8 agp ut sjoajja 2uipeosuo ao uopupw2op asnuo
lou pue Kl!jigejs wolsXs umiumw of se zauuew u gons ui anzasa -1 2uiuuidS
jo luomimbaa oql 133uT of paddo.Tp oq ueo puol pajjoaluoo Iugl aanssu
Ilugs urej2oid guippags pool oqZ •wLjBoad 2uippogs peol polloaluoo
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ouil ail ao ;DV-I Salpuzg `ojdutexo ioj) anaasaa 2muuids uo suoijoi.Tisai
.TO (SSgg puL SO'IIS `ajdumxa .Toj) soomos Taglo pue panjonut U13IS iS
DIP 3o puuuTaQ S W31 SSS p011023JUT aql pine UJOISSs aniloodsaa aql ui gull
uo shun fupuaaua2 IIu jo XI!pqudeo tau Dip jo ums zip womlaq aoua opp
aql se JueIsui U OAl2 Xuu w palelnoluo aq jjegs an.TasoW 2uiuuidS tuolsKS I't
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g1liolul Dip Xq pouiuualap uoTju2TIgO 3njas3N OupezadO lino, oql
jo a2uIuaoaad iugl aq llegs Xi!lug uu 3o uotlui?ilgo anzasag 2utluzad0 oq.L I'£'Z
sanzasQH 2utjuaadO jo uotluoojjV £'Z
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agp Xq po2uego zo po!ppow aq XuuT uoTloos sigp ui polpoods upajiao OU £'Z'Z
•sjozIuoo zouaan02 oiliewolnu 3o uopou g2no.Tgl `.�INomb
.io `poijod inoq -oml u .To3 ft,�Iddns Sisnonuiluoo jo ajquduo si jiun
DIP Iugl (ANW) peol jo junoum uznuzmm jugj paaoxa lou Ilugs 1I •q
, mojaq (q) ump .TaivaB aou atuil
.relnoilmd Xuu IL ouigouuz oqi uo pool zip uugl ssol aq jou Ilugs 11 •e
:vIjol .To Oulmollo3 oql
Aq pauiuualap aq Ilegs sanzaso -d 5upendO .zo3 .ii!pquduo jiun SupenuaO Z - Z - Z
•anaasa -1 SuiuuidS -uolsl Pm pautMUIPW
aq jjegs uoijLSijgp o uaso -d Supundp Iulod, Dip jo aouujeq aq.L Z I - Z - Z
•SISUg anJasaW UJOjS iS aqj JO
luaond OOI 01 Juajenmba junoure uu uugl ssal aq lou Ilugs uoijrSijg0
an.Tasmd 2upendO juloZ Dip jo uotliod 3naasa21 SuiuuidS gqZ I.1 -Z -Z
2.4.3 The Intertie Management Committee may establish procedures to assure
that the Operating Reserve is available on the systems of the Participants
at all times. Whenever an entity is unable to meet its Operating Reserve
Obligation, that entity will, within two hours, advise its Balancing
Authorities and make arrangements to restore its Operating Reserve
Obligation.
2.4.4 Prudent Utility Practices shall be followed in distributing Operating
Reserve, taking into account effective utilization of capacity in an
emergency, time required to be effective, transmission limitations and
local area requirements.
2.4.5 An entity may arrange for one or more other entities to supply part of, or
its entire, Operating Reserve requirement.
2.4.6 In an emergency, any Generator Owner, upon request by its Balancing
Authority, shall supply to such Balancing Authority part or all of its
Operating Reserve up to the full amount of its Available Accredited
Capability. An entity experiencing an emergency is not required to
maintain its Operating Reserve Obligation. There shall be no obligation of
an entity to supply Operating Reserve if the requesting entity is not
making full use of its own Available Accredited Capability.
2.4.7 The Intertie Management Committee may assign penalties for non-
compliance with sections A and B.
C Responsibility for Regulating Reserve
C -3.1 Regulating Reserve
3.1.1 Each Balancing Authority shall provide, or contract for, Regulating
Reserve as required by Section C -3.2 of this Article equal to or greater
than the Regulating Reserve Obligation of the party. Regulating Reserve
may not overlap reserves dedicated for Spinning Reserve. Regulating
Reserve (both up and down) is required to compensate for uncertainty in
forecasting and is established during the Unit Commitment planning
process, and as such the BA may then utilize their reserve as required
during the course of the day. If a BA exhausts its Regulating Reserve,
they are required to procure or commit additional reserves immediately.
C -3.2 Regulating Reserve Obligation
3.2.1 The Regulating Reserve Obligation for each Balancing Authority shall
initially be set by the Intertie Management Committee.
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ju sainsrom aagpo aainbaa io anaasag 2upuln2ma s,dg r osuajoap/asRazoui
o; lg2lj aul sanaasaz aalaiaTmoD juouza &,urW 311zalul aql £'Z'£
'mw jo3o ui isoinu otp of do popunoi aq Ipm p3julnoluo os suoijvSggo
anaasa -a 2uijloInB3g ail,I, ' i SdD sIi ui uotIUinap o� aip Xq anaasag
2upvjnSag juazmo sli Suisvaaoap /2uisua.zoui q anjasag Suijgn2ag
,Sop!aoipnV 2uiourlug qmn . ppow Ilion aajjtuzuxoD juowo2uuuw aivajul
a ll `paliduzoo are soilsirlis Sdo pua iLok zip aai3u `sisuq Iunuue ut, u0 Z'Z'£
Exhibit B 1: Spinning Reserve Components
Spinning Reserve Obligation will be allocated to the entities based the following 5
criteria, Largest Unit, Served Load, Unit Reliability, Spinning Reserve Response, and
Operating Inertia. An entities' multiplier for each of the components shall be determined
as follows:
1. Largest Unit: This component shall be calculated as the ratio of an entities'
Largest Generating Unit Contingency (LGUC) as compared to the sum of the
Largest Generating Unit Contingencies of all the entities. The Largest Generating
Unit Contingency will be based on the maximum capability of those units when
operated at temperature corresponding to the average monthly temperature for
that region. An example of a Generating Unit Contingency is a combined cycle
unit; the loss of the combustion turbine will precipitate the loss of both the CT as
well as the waste heat unit. If entities share a unit, an entities SHARE of such a
unit could qualify as their LGUC if they have no unit(s) that are larger. This
component may change whenever the average monthly temperature changes or an
entity changes its LGUC.
For the purposes of this section, a wind farm, or similar collection of generating
units that use a non - dispatchable fuel supply is a Balancing Authorities'
regulating issue. The Farm does not constitute a LGUC. As buss faults and line
faults are rare; single points of failure in these assets do not constitute a LGUC.
A single point of failure in a fuel supply that may result in the loss of multiple
units does not constitute a LGUC.
SpinLU = LGUC / Yi(LGUCi)
2. Served Load: This component shall be calculated as the ratio of an entities
Served Load (an entities energy requirements including transmission losses and
interruptible loads, but excluding economy energy sales; during the peak hour) as
compared to the sum of the Served Load of all the entities. The load value used
will be for the current month from the previous year.
SpinSL = SL, / Yi(SLi)
3. Unit Reliability: This component shall be calculated from the sum of the output
of each of an entities unit trips as compared to the sum of the output of all unit
trips in the system as collected for 4 consecutive quarters, one quarter lagging.
Minimum countable deviations are loadings greater than 10 MW. In the event
there are no recordable deviations, the other spinning reserve components will be
pro rata scaled to make up for this component. This component shall be evaluated
quarterly.
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(!x/5)`3 / ( = a IOuidS
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imp ao3 suopu2ilgo uids x3mol ui llnsoi Ipm walsXs aql 113auaq of puai gotgm
`VAW tad sliun .ugineaH •sliun ,VAW zad,, ui popodau oq Ipm emivaul siomiouo2
gong •Iaags (ol do joeq uo) 2wpodaa uids sappuo ue uo paziuougouXs pue gull uo
aq of umogs si Iiun aql wqj .moq goea zo3 paziuoNmu s pue ouil uo paaapisuoo aq
Ipm sluun gqZ •poziuoago"s pue ouil uo pue palunoo aq o � o uegp uaHig aq
lsntu iiufl •32euane 2utlloi tpuotu ZI 2ui22?el tpuouu auo a osn llim suoijelnoluD
•saliguo atp IIe jo eilzaui leoiaolsig aql 3o tuns atp of pauedtuoo se epuati Ieoiuoisig
solIpua ue jo oilm atp se palelnoleo oq Ilrgs luouoduzoo sigjL :eiljaul 2uijezadO •S
( ?duuj2RIS)`3 / 3 duzj2RIS = O NNSuidS
sJuana Jo .uaqutnu aql si u azagm NUS3 / ( aS/ - I = o dwiNdS
•uotje2ilgo sappua ue of osuodsai jo joel pajeadau uo
osodtut ueo oou!uuuuo0 luotuaSeurw ailialul alp Imp uoiloues xluo aql paiapisuoo
oq jou pinogs uids jo luouodutoo ?1215 oqi ui ;mwoui ud •aOeaane SuulloJ
tpuotu Z 2uissel gjuouu auo e oq Ipm posn poivad oqs •poivad aql .iano pouuuuns
aq hugs uotlelnoleo Bons goeg •DfID I stualsXs otp Xq papinip poddiui jegj
jiun oqj Suplej fq poleos uoijefilgo sappua ue si uoijvSilgo poleos oqZ •iipazo e
aq jou llim uoiingij;uoo uanO •aReuane aldtuis e eun pouiquuoo aq Ipm suoumBolui
oml ags o. ui llnsau a uimgo of uoi�egilgo otp Xq papinip aq Ipm linsai powi2owi
goeg •oouegmisip aql JOIF salnulw 01 pine spuooas 06 uaamlaq uiuSu put `poizad
puoogs 06 IePiui ue .zano asuodsaa sli pue uoijei?ilgo Qg -Id:)S soililuo ue uoomlaq
Xouaiotjap aqj (uoilvAolui Iepiozadeui se XIolumooe se iseal Je) 2uileusalui
Xq paaelnoleo aq llim anuasaa Sumuids sauIiIua ue Jo ssauanisuodsai oqZ •sjuana
ile pue sappuo oql Ile jo asuodsa21 anaasa2i SuiuuidS Ieoiiolsiq aga jo tuns oql
of paiedtuoo se uoije2ilgO anzaso -d SuiuuidS uagi sli Xq poleos asuodsa2l waosa2I
2uiuuidS Ieoiaolsiq s3ppuo tm jo tuns oql jo oijeu otp put (I) uoipoajuad uaamlaq
aouatajjip aql se palelnoleo oq llegs juauodwoo sigZ :3suodsa21 anzasa2i fuituuidS 't,
sluana Jo uagwnu aql si u aaagm [('21fl) u 3] 13 / 3 (2lfl) u 3 = 3 2IfluidS
•w;DlsXs paloatuuooaalui oql uo stuolgozd i,ouaguuiuoo uag$iq uo ` ,C ` io
lInsw agl are goigm sdiri iiun uo `uids jo saoinos u3g10 Xq AA W uoj A#,w Sn poNoeq
are goigm sliun Suilsal jo sdiii `suopoofaa pool palnpagos apnloui jou op sdiai liufl
Exhibit B2: Spinning Reserve Obligation
Spinning Reserve Obligation for an entity will be calculated summing the weighted
Spinning Reserve Components of each entity, and multiplying this by the System
Reserve Basis as follows:
SRO = ( A *SpinLU + B *SpinSL + C *SpinUR + D *SpinSRR + E *SpinOI * SRB
Where the weighting factors are:
A = 30%
B = 30%
C =20%
D =10%
E= 10%
An entity has the obligation to participate in the various components per their activities
pursuant to Table T1. An Excel worksheet shall also be developed to further explain the
interrelation of the components.
Table T1 NERC entities matrix.
Spin
Entity Function component
Balancing Authority
SRR
Compliance Enforcement Authority
X
Distribution Provider
X
Generator Operator
X
Generator Owner
LU,UR,OI
Interchange Authority
X
Load - Serving Entity
SL
Market Operator (Resource Integrator)
X
Reliability Coordinator
X
Planning Coordinator
X
Purchasing - Selling Entity
X
Reliability Assurer
X
Resource Planner
X
Standards Developer
X
Transmission Operator
X
Transmission Owner
X
Transmission Planner
X
Transmission Service Provider
X
Time Error Correction Procedure
Purpose:
Interconnection frequency is normally scheduled at 60.00 Hz and controlled to that value.
The control is imperfect and over time the frequency will average slightly above or below
60.00 Hz resulting in mechanical electric clocks developing an error relative to true time.
This Standard specifies the procedure to be used for reducing the error to within acceptable
limits of true time.
Applicability:
Balancing Authorities, Interconnection Time Monitor
Definitions:
Balancing Authority (BA) — The entity responsible for integrating resource plans ahead of
time, maintaining load- interchange - generation balance within a Balancing Authority Area,
and supporting Interconnection frequency in real time.
Balancing Authority Area — An electrical system bounded by interconnection (tie -line)
metering and telemetry, where the Balancing Authority controls (either directly or by
contract) generation to maintain its Interchange Schedule with other Balancing Authority
Areas and contributes to frequency regulation of the Interconnection.
Frequencv Bias Setting — A value, in MW /0.1 Hz, set into a Balancing Authority's AGC
equipment to represent a Balancing Authority's response to a frequency deviation.
Interchange Schedule — The planned energy exchange between two adjacent Balancing
Authorities.
Alaskan Interconnection — Any one of the Alaskan utilities connected by transmission line
operating above 35KV.
Interconnection Time Monitor — An entity that monitors Time Error and initiates and
terminates Time Error Corrections.
Leap Second — A Leap Second is a second of time added to Coordinated Universal Time
to make it agree with astronomical time to within 0.9 seconds. Historically, Leap Seconds
are implemented as needed on June 30 or December 31 St . ( National Institute of
Standards and Technology)
Time Error — Accumulated time difference between time based on Interconnection
frequency and the National Bureau of Standards time.
Time Error Correction — An offset to the Interconnection's scheduled frequency to correct
for accumulated Time Error.
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1.10. After the premature termination of a manual time correction, a slow time
correction can be reinstated after the frequency has returned to 60 Hz or
above for a period of ten minutes. A fast time correction can be reinitiated
after the frequency has returned to 60 Hz or lower for a period of ten minutes.
At least one hour shall elapse between the termination and re- initiation
notices.
1.11. Time correction on reconnection. When one or more Balancing Authorities
have been separated from the Interconnection, upon reconnection, they shall
adjust their time error devices to coincide with the time error of the
Interconnection. The Balancing Authorities shall notify the Interconnection
Time Monitor they are ready to receive the necessary adjustment to time error
as soon as possible after reconnection.
1.12. Leap Seconds. Balancing Authorities using time error devices that are not
capable of automatically adjusting for Leap Seconds shall arrange to receive
advance notice of the Leap Second and make the necessary manual
adjustment in a manner that will not introduce an improper Interchange
Schedule into their control system.