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Program
8
8-1
(This project number has been
intentionally skipped)
8-2
Cable Parameters Software Enhancement
As part of Program 8, the
capabilities of CEPS will be greatly Expanded. The goal is to add the following
features:
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Simple ampacity
calculations
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Riser ampacity
calculations, based on new information's obtained as part of DSTAR Program 7
research
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Asymmetric neutral
currents and losses to allow more accurate evaluation of cable losses and
ampacity
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Cable-by-cable neutral
currents during faults to determine cable fault-current withstand
limitations posed by cable neutrals
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Maximum cable pulling tension
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Maximum sidewall cable pressure
Value to Participating
Utilities:
With Expanded capability of
CEPS, member utilities will be able to engineer underground distribution
systems with greater accuracy, and less engineering effort.
8-3
Capacitor Transient Currents
This project will develop
guidelines for avoiding nuisance operation of feeder capacitor bank fuses due
to switching transient and lightning duty. The guidelines will consider
factors such as:
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capacitor size
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capacitor bank neutral grounding (grounded
wye or floating wye)
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rated system voltage
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relative location of other capacitor banks
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switchgear type and performance
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overvoltage protection practices
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feeder lightning exposure
This project will include field measurements to
supplement simulations and engineering analysis, providing accurate and
realistic results. Final results will be delivered in the form of concise
guidelines, tables, and spreadsheets.
Value to Participating
Utilities:
Guidelines provided by this research will allow
member utilities to better coordinate fuses protecting feeder capacitor banks,
and minimize nuisance fuse operations resulting in voltage imbalance affecting
customer power quality and labor costs for locating and replacing blown fuses.
8-4
Primary Flicker And Impedance
This modest-sized project will expand the
present DSTAR Toolbox voltage flicker tool to calculate the impact of large
motor starting or other flicker loads elsewhere on the feeder. The tool will
allow the user to quickly and conveniently model the primary system. An
impedance calculator will be built into the tool to allow the user to
conveniently determine the impedance of a feeder section with a given
configuration and conductor size. Voltage flicker results will be output for
each specified point in the primary system model, as well as the secondary
system to which the flicker-producing load is connected.
Value to Participating
Utilities:
There is heightened interest in power quality
provided to customers, and one significant aspect of power quality is limiting
voltage flicker. Existing tools for distribution system analysis, such as
load flow programs, are cumbersome to use for this type of analysis, and are
often not available to the engineers needing to perform the flicker analysis.
This tool fulfills this need, and offers convenience and ease-of-use which
minimizes engineering effort required.
8-5
(This project number has been intentionally skipped)
8-6
DSTAR T&D Show
8-7
Overhead and Underground Total Owning Costs
Utilities often need to evaluate and compare the
system owning costs of overhead (OH) and underground (UG) distribution systems.
While some utilities base their analysis solely on installation and equipment
first cost comparison, it is recognized that there are O&M costs incurred during
the lifetime of OH and UG distribution systems that need to be considered as
well.
Deliverables:
8-8
Impact of Distributed Generation
This project will develop
"white paper" report which describes the various distributed generation
technologies and summarizes their impact on distribution system design,
operation, and protection. The evaluation will include the following topics:
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Characteristics of
"distributed resources" technologies.
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Why and where DR are or
might be applied.
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How they may affect
distribution system performance
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Impact on system
reliability
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Current interconnection
standards activities
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How DR Impacts can be
minimized
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Future concepts where DR
can be used to help the distribution system.
8-9
(This project number has been intentionally skipped)
8-10
Seasonal Loading Equivalents
The Transformer Owning Cost Software (TOCS), the
Transformer Loading Analyzer (TLA) in the DSTAR Toolbox, and many other software
packages for transformer thermal loading analysis base their representation of
annual variations in load and ambient temperature on a four season method with
typical load and temperature patterns within each season.
Should the "seasons" be summer, winter, spring, and fall ?
This project will develop
guidelines and algorithm for dividing the year into loading "seasons" which
provide best use of loading program's capability.
Deliverables:
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Develop a robust approach/algorithm for
equivalencing actual load profile/climatic data into a four season load
scenario that properly accounts for losses and transformer temperature duties.
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Implement the algorithm in Windows-based
software. This implementation may be in the form of an Excel spreadsheet with
graphic user interface enhancements or as an Access application.
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