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April 20122 | www.tdworld.com2
50
Vol. 64 No. 4
CONTENTS
CO
VE
RS
TO
RY
AP
RIL
201
2™
36
44
52
64
74
82
Substation Design in the Third DimensionModern design tools streamline substation work processes.
By Gene Wolf, Technical Writerf
Wired for SuccessKCP&L is retrofitting Midtown Substation with updated communications
protocols as part of a DOE smart grid demonstration project.
By Ed Hedges, Kansas City Power & Light Co., and Matthew Olson,
Burns & McDonnell
LiDAR to the RescueA severe ice storm in Russia leads to re-evaluation of ROW status and
vegetation management practices.
By Boris Mekhanoshin, JSC IDGC Holding
Raising the Standard for Customer EngagementGlendale Water & Power invests in customer outreach, gaining early and
continuous support for its smart grid project.
By Glenn O. Steiger, Glendale Water & Powerrr
Bus Bar InnovationTranspower New Zealand designs, tests and commissions a new
under-hung substation bus bar system.
By Andrew Renton, Transpower New Zealand Ltd
NV Energy Signals Demand ReductionsA decade of demand-response growth has generated benefits and
created new challenges.
By Victor Garman, NV Energy
Show Update
2012 IEEE PES T&D Conference & Exposition64
36
44
LEARN MORE TODAY:
EMAIL: Brian Furumasu at [email protected]
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POWER ENGINEERS. WIRED TO DO IT ALL.
April 20122 | www.tdworld.com4
Departments
GlobalVIEWPOINTSmart India. Rick Bush travels to Mumbai to learn about India’s strong
commitment to a robust energy future.
By Rick Bush, Editorial Director
BUSINESSDevelopmentsM Duke Energy and Progress Energy File Market Power Mitigation Plan
MM EnerNOC Expands Upon AutoDR Success in New Zealand with Move
to South Island
SMARTGridMM Team Announced for Consumers Energy’s 1.8 Million Smart Meter
Deployment
M City of Medicine Hat Chooses MeterSense for Meter Data Management
TECHNOLOGYUpdatesMM NEMA Encourages Action to Expand Meter Socket Lifespan and
Inspections
M Western Electricity Coordinating Council Contracts with Siemens PTI
for Data Collection Tool
QuarterlyREPORTPEVs Move into the Fast Lane. Edison Electric Institute is educating
utilities about the benefits of plug-in electric vehicles and working
to build and strengthen the market for them.
By Rick Tempshin, Edison Electric Institute
CHARACTERSwithCharacterA Lineman’s Legacy. Dennis Kerr uses his experience as a former lineman
in his role as co-chairman of the board of directors for the International
Lineman’s Rodeo Association.
By Stefanie Kure, Contributing Editor
StraightTALKElectronic Devices for HVDC. HVDC has flourished using silicon-based
semiconductors, but new semiconducting materials promise enormous
improvements.
By Ram Adapa, Electric Power Research Institute
In Every Issue
ClassifiedADVERTISING
ADVERTISINGIndex
10
12
16
18
22
24
96
92
95
p
CONTENTS
y
24
18
10
Quanta Services’ roots in the power industry run deep. For generations, Quanta has been the force behind the development of the power grid. As consumption of electricity rises, so does the demand for transmission and distribution contractors. Reliability is at stake.
Quanta designs, installs, maintains and repairs electric power infrastructure. The branches of our network are far reaching and ready to mobilize. With approximately17,000 employees working in all 50 states and Canada, Quanta’s growth has made the company the foremost utility contractor with the largest non-utility workforce in the country.
The nation’s premier utilities rely on Quanta’s expertise to deliver the manpower, resources and technology necessary to meet growing demand, integrate new generation sources and deliver the power and reliability consumers deserve.
www.quantaservices.com 713.629.7600 NYSE-PWR
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April 20122 | www.tdworld.com6
Editorial Director Rick Bush [email protected]
Technology Editor Vito Longo [email protected]
Senior Managing Editor Emily Saarela [email protected]
International Editor Gerry George [email protected]
Automation Editor Matt Tani [email protected]
Contributing Editor Amy Fischbach afi [email protected]
Contributing Editor Stefanie Kure [email protected]
Technical Writer Gene Wolf [email protected]
Art Director Susan Lakin [email protected]
Publisher David Miller [email protected]
National Sales Manager Steve Lach [email protected]
Buyers Guide/Marketing Services Joyce Nolan [email protected]
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Andrew Schmolka [email protected]
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of 14.4 kV through 25 kV, features PulseClClCC osing Technology™—a unique means for verifyinyinyinyinying that theh line is clear of faults before initiating a clclcloclocl sing operation. Pulseclosing is superior to convenenenenentional ope at o u sec os g s supe o to co eeee t o areclosing. It greatly reduces stresss on sy sysysteststem m m mmcomponents, as well as voltage saaags s experiencncncncn ed by customers upstream of the fault.
Scada-Mate® Swwitching System, in voltage ®
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Automation needs change and groow witth increased load, caapacity, annd
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IntelliNode™ Interface Module allows IntellIntelliNode™ Interface Module allows h a wide array of IntelliTTeam SG to work witht electronic devices new and existing intelligent
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S&C’s IntelliTeam® isn’t just automatic service restoration
ince its introduction in 1997, SS&C& ’ss InttelliTeam® Automatic ResestttotorararatititionnonnSystem has become the inindustryry’s’s sstat ndarard.d The latest versrsioion—n——
IntelliTeam® SG—is a universala solututioion n fofor imimprp oving grgridid relliaiabibibilllllilitty.It works with S&C IntelliRupter® PulseseClCloso ers,s, S Scadaa-M-Mate® aaanndnd SScaaadadadad -Mate CX™ Switches, Remote Suupervr isorry y PaPad-d-MoMooouunted GeGeearar, and d Remote Supervisory Vista® Undergroundd DDisistrtrribibibution SwSwSwS iitchgegeear. AAnd, using S&C’s IntelliNode™ Interface Modululee,e, I IntelliTeTeTeamam S SGG works with protection relays and reclossosere controlols s frfromomom otherr m mmananufufaacacturers tooo.
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elliTeamThe InteT ® DDEM Distributed Energy Management System ®
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S&C’s solutSS&C’s solutions for improved grid reliability,DSDFLW\�DDQG�HIÀFLHQF\��DQG�JULGG�JULG�FDLQFUHDVHGnclude aa wide range of supporting cation incommunicdesign, and construction and ing and engineeri
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GlobalVIEWPOINT
Smart India
Ihad been invited to India by the executives of the In-
dian Electrical and Electronics Manufacturers Associa-
tion (IEEMA). We had selected the visit to coincide with
ELECRAMA, the electrical equipment show IEEMA hosted
this January in Mumbai, India. This has got to be the biggest
event in the world focused on power delivery. Chairperson
Indra Prem Menon informed me that this show was made up
of 1,500 booths with 100,000 people in attendance.
At the opening ceremony, P. Uma Shankar, secretary, Min-
istry of Power, Government of India, provided some statistics,
stating: “The government is looking at power-sector revenue
estimates of US$56 billion from transmission, $91 billion from
distribution and $147 billion from generation.”
Prior to ELECRAMA, IEEMA hosted GridWeek Asia with
Sam Pitroda, energy advisor to Prime Minister Manmohan,
providing the keynote. Pitroda addressed the reality of a strug-
gling Indian power sector while providing plenty of opportu-
nity for hope. Pitroda, who also heads the India Smart Grid
Task Force, put it this way: “Power is our biggest bottleneck
as we approach 8% GDP growth. It is a larger challenge than
many of us realize, but I am sure all this will change as this
decade has been declared the ‘Decade of Innovation.’”
India already has two robust business segments, the IT sec-
tor and the telecom sector. By combining these two strengths
with funding from government and the private sector, Pitroda
expects to see rapid progress in meeting the challenges in the
energy sector.
In smart meters, for instance, Pitroda predicts India will
need to install 100 million meters. Toward that end, the Smart
Meter Task Force, which he also chairs, is entrusted with in-
troducing low-cost meters connected using the existing GSM
wireless communications system. “These low-cost meters will
feed critical data into the smart grids that are considered to be
the panacea for our primitive power sector,” states Pitroda.
India has a 10% energy shortage at peak, so curtailment is
common, particularly in the summer months. And with a pre-
dicted growth rate in the country of 7% to 9% per year, India
faces quite a hurdle to meet the energy shortfall while meet-
ing electricity growth targets. But this issue is being tackled,
and today, India has five separate joint ventures charged with
building more generation. To give you an idea of the tremen-
dous growth potential of the electric market, India is one of
the largest economies in the world but consumes only 4% of
the global total electricity produced.
Ashok Lavasa, additional secretary, Ministry of Power,
shared issues facing state-owned distribution companies. “The
amount of energy lost is huge, on average on the order of 27%
to 28%,” said Lavasa. I learned that the revenue losses vary
significantly by state but are typically due to poor account-
ing systems, to theft and by inefficiencies in the distribution
system. To address these issues, India is looking at smart grid
technologies to maximize throughput, increase energy effi-
ciency, and develop diverse generation and storage plans.
India cannot afford to use traditional off-the-shelf smart
grid solutions for customers who consume very little electric-
ity, so the country is looking to develop indigenous solutions
to provide cost-effective and reliable solutions. Some states
also have privatized ownership of distribution facilities, giving
private companies tremendous incentive to address inefficien-
cies. As India addresses systemic losses on the distribution
system, more funds become available to invest in the distribu-
tion, transmission and generation facilities.
On the transmission side, India’s smart grid technology
is much further along. N.S. Sodha, general manager of load
dispatch with the National Grid of India, shared the great
strides the company is taking to build the world’s first 1,200-kV
transmission grid. The National Grid of India is also installing
synchrophasers as it builds out its bulk power grid control and
monitoring system.
With the tremendous expansion going on in India, the
National Grid is upgrading to 800-kV dc and up to 1,200-kV
ac to increase corridor transfer capacity. Power Grid India is
also increasing circuit capacity with series capacitors, SVC and
FACTS devices along with high-temperature, low-sag conduc-
tors. India is also moving to GIS substations while optimizing
tower designs with taller towers and multi-circuit towers.
To address its energy needs, India is inviting global inves-
tors and global vendors to join in building out a more robust,
secure energy future. Going forward, we will continue to share
with you what that future will look like. Right now, T&D World
is working with Indian federal and state utilities along with the
IEEMA executive team to see how we might share the incredible
changes going on in India in energy. Just as India has focused its
might, first on IT and next on telecom, this giant economy is now
taking aim on energy.
Editorial Director
Rick Bush and ELECRAMA Chairperson Indra Prem Menon enjoy alighter moment together.
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April 20122 | www.tdworld.com12
Duke Energy and Progress Energy D
File Market Power Mitigation Plan
Duke Energy and Progress Energy have filed a
revised wholesale market power mitigation plan
with the Federal Energy Regulatory Commission
(FERC) as part of their proposed merger.
The plan provides more details on the notice of f in-
tent to file a mitigation plan submitted to the Nortth
Carolina Utilities Commission (NCUC) on Feb. 22..
It requests that the FERC issue orders approving
the mitigation plan, the Joint Dispatch Agreement
and the Joint Open Access Transmission Tariff withiin
60 days of the filing and no later than June 8, 2012. The companies
intend to seek final merger-related approvals fromm the NCUC and
the Public Service Commission of South Carolina prior to the July 8 prior to the July 8
merger agreement termination date.
The following are key elements of the mitigation plan:
M The FERC filing features a permanent mitigation plan with seven transmission
projects, estimated to cost US$110 million. The transmission projects significantly
increase the power import capabilities into the Progress Energy Carolinas and Duke
Energy Carolinas service areas and enhance competitive power supply options in
the region.
M The proposal features a two- to three-year interim mitigation plan with must-
deliver, must-take power purchase agreements with Cargill Power Markets, LLC; EDF
Trading North America, LLC; and Morgan Stanley Capital Group Inc. The compa-
nies will sell 800 MW during summer off-peak hours, 475 MW during summer peak
hours, 225 MW during winter off-peak hours and 25 MW during winter peak hours.
The agreements, or similar power purchase agreements, will be in place from the
date the merger closes until the transmission projects are operational.
M Potomac Economics will serve as the independent monitor of the interim power
purchase agreements and a component of the permanent mitigation plan.
For planning purposes, the companies plan to close the merger on July 1.
For more information, visit www.duke-energy.com/progress-energy-merger.
BUSINESSDevelopments
EnerNOC Expands Upon AutoDR Success E
in New Zealand with Move to South IslandEnerNOC Inc. will provide automated demand response (AutoDR) capacity for
Genesis Energy on New Zealand’s South Island. This contract builds upon EnerNOC’s
success in the instantaneous reserves market on New Zealand’s North Island and
makes it the first DR aggregator to secure this reserve capacity in the South Island.
EnerNOC will immediately begin enrolling commercial, institutional and indus-
trial energy users who can curtail usage with single-second precision in exchange
for regular financial payments. EnerNOC’s AutoDR resources will then be offered
year-round to the instantaneous reserves market, which helps to maintain reliable,
cost-effective and clean energy supply throughout New Zealand.
New Zealand has committed to making its electricity generation sources 90%
renewable by 2025. Currently, the nation’s electricity grid is served largely by
hydropower, the vast majority of which flows northward from the South Island. The
nation’s instantaneous reserves market helps to maintain reliable import and export
of electricity between the islands by regulating frequency.
For more information, visit www.enernoc.com.
India Awards I
Alstom Grid Order
for EHV 765-kV
Circuit Breakers
The Power Grid Corporation of In-
dia Ltd. has awarded Alstom Grid a
contract worth approximately 10 mil-
lion euros to deliver 64 circuit breakers
for various 765-kV substations located
at Dharamjaygarh, Jabalpur, Bhiwani,
Satna (extension), Gwalior (extension)
and Rajgarh Pooling (near Kotra).
A leader in the field of extra and ul-
tra high-voltage circuit breakers, Alstom
Grid is the first manufacturer to localize
in India the production of circuit break-
ers with a spring operating mechanism
up to 765 kV. Alstom Grid is a key global
supplier of circuit breakers in the range
of 72.5 kV to 1,200 kV.
Under the terms of the contract,
Alstom Grid will supply the design, en-
gineering, manufacture, supply, trans-
portation, unloading and on site deliv-
ery, including insurance, supervision of
erection, testing and commissioning of
the 765-kV circuit breakers and support
structures.
Visit www.alstom.com/grid.
Deregulation opens up an entirely new vista of market opportunities. NECA/IBEW
contractors can give you a leg up on competition. NECA can be an experienced
partner with a stronghold in the geographical areas you’re targeting. NECA/IBEW
represents qualified electrical and line contractors employing more than 250,000
electrical construction workers throughout the United States.
NECA/IBEW contractors have the skills and experience to be competitive in
any market. They’ve mastered the latest technologies, codes and workplace safety
standards. And they have the advantages of local know-how, reputation and an
established customer base.
With NECA and the IBEW as your partner, you’ll be able to provide local customers
with high quality products and services at competitive prices. And you’ll reach those new
markets before your competitors do.
Contact your local NECA line chapter or IBEW local union
for more information.
We can give you a leg up on the competition.
www.thequalityconnection.orgNational Electrical Contractors Association
International Brotherhood of Electrical Workers
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April 20122 | www.tdworld.com
BUSINESSDevelopments
14
Power Station Demolition Clears the Way P
for New Electricity Interconnector with Europe
y
The last remaining cooling towers and chimney from the
former Richborough Power Station in Kent, U.K., have been
demolished to make way for a new energy park. National Grid
plans to use part of the site for an electricity interconnector
with Belgium.
The interconnector is a joint project between National
Grid and Elia, the Belgian transmission system operator,
and would be the first electricity link between the two coun-
tries. It is planned to run the 1,000-MW high-voltage direct-
current undersea cable between Zeebrugge and Richborough,
a distance of approximately 130 km (80 miles).
The link would allow power to flow in both directions
and would be the third electricity interconnector connection
between Kent and Europe. The BritNed interconnector be-
tween the U.K. and the Netherlands went into operation in
2011 and the IFA interconnector to France began in 1986.
The project aims to be in commercial operation by 2018.
For more information, visit www.nationalgrid.com.
First Wind Secures F
$236 Million Financing
for Kawailoa Wind
First Wind, an independent U.S.-based
wind energy company, has obtained
US$236 million in financing for its 69-MW
Kawailoa Wind project on Kamehameha
Schools’ Kawailoa Plantation lands on Oa-
hu’s North Shore.
A subsidiary of First Wind closed a
$220 million non-recourse construction
and term loan and $16 million in letters
of credit for the Kawailoa project. Union
Bank served as Administrative Agent and
Joint Lead Arranger. Other Joint Lead
Arrangers include Bayern LB, Rabobank
and Siemens Financial Services. CIBC and
CoBank also participated in the financing.
Early construction work began on the
project in December 2011 and has pro-
gressed steadily. The project is expected to
be completed by the end of 2012.
Once complete, Kawailoa Wind will be
the largest wind energy facility in Hawaii.
The project’s 30 2.3-MW Siemens wind
turbines will have the capacity to gener-
ate enough clean, renewable wind energy
to power the equivalent of approximately
14,500 homes on the island, or as much as
5% of Oahu’s annual electrical demand.
In December 2011, the Hawaii Public
Utilities Commission approved a power
purchase agreement between Kawailoa
Wind and the Hawaiian Electric Co., which
serves more than 400,000 Hawaii custom-
ers. Hawaii state law mandates 70% clean
energy for electricity and surface transpor-
tation by 2030, with 40% coming from lo-
cal renewable sources. Kawailoa Wind will
significantly advance the state’s progress
toward these goals.
Visit www.firstwind.com.
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April 20122 | www.tdworld.com16
SMARTGrid
Vermont Utility V
Advances Smart Grid
Project with Siemens
Burlington Electric Department
(BED) has selected Siemens for the
sale and implementation of the eMeter
EnergyIP meter data management plat-
form. BED and other Vermont utilities
worked together with the state of Ver-
mont to secure Smart Grid Investment
Grant funding through the American
Recovery and Reinvestment Act.
BED is a municipally owned electric
utility that serves about 16,000 residen-
tial customers and more than 3,600 com-
mercial customers. The utility was look-
ing for a meter data management system
that could support its current needs for
billing consumers from data collected
from the smart meters, yet at the same
time be flexible enough to adjust to the
statewide functionality desired by state
of Vermont regulators.
BED’s smart grid project, like most
utilities, has taken a phased approach.
The first phase kicked off in mid-2011
with requirements-gathering workshops
to help frame the integration work. The
second phase will include meter-to-cash
functionality, advanced billing function-
ality and the ability to improve opera-
tional efficiencies through reduced truck
rolls and better outage management.
Visit www.burlingtonelectric.com.
Team Announced for Consumers Energy’sT
1.8 Million Smart Meter DeploymentSmartSynch has announced the team that will help provide the advanced meter-
ing system that will form the foundation of a grid and meter modernization pro-
gram for Consumers Energy’s 1.8 million electric customers in Michigan.
Members of the team include GE Energy, which will provide the meter hardware,
and Grid Net, which will provide the networking and metering software used by the
utility. Qualcomm will provide the mobile broadband chipsets that enable cellular
connectivity, and Verizon Wireless will provide the communications network, which
Consumers will use to remotely retrieve the energy-usage data collected by the smart
meters.
Consumers Energy’s selection of a cellular-based solution concluded a compre-
hensive process by the utility to find the best advanced metering solution for its
customers. The company’s decision to use existing cellular networks for large-scale,
high-performance smart grid communications, in lieu of building and maintaining
a private network, comes after extensive research and testing of available industry
solutions. It makes Consumers Energy, which serves more than two-thirds of Michi-i-hiic
gan across a 32,000-sq-mile (82,880-sq-km) service territory, the largest U.S. utility yty lity
to choose a cellular-based communications system for the smart meter deployment t
phase of its grid-modernization program.
Meter installation is scheduled to begin in Muskegon County in August 2012 with
installation phases continuing through 2019 across the utility’s service territory.
For more information, visit www.smartsynch.com.
City of Medicine Hat Chooses MeterSenseC
for Meter Data Management
y
The city of Medicine Hat, Alberta, Canada, has selected MeterSense, a division
of Harris Utilities, to provide meter data management (MDM) for its electric-deliv-
ery services. From billing data to outage and restoration events, from performance
monitoring to revenue protection, MeterSense collects, manages, stores and delivers
smart grid information intelligently.
The utility company — a wholly owned entity of the city of Medicine Hat — will
implement MeterSense as part of a larger advanced metering infrastructure (AMI)
smart meter project. MeterSense’s AMI and MDM capabilities will help the utility
improve the way it serves the Medicine Hat population of 61,000.
MeterSense will enable the city of Medicine Hat to meet several specific needs:
M Automate meter reading and eliminate the need for regular access to custom-
ers’ properties for meter checks
M Deliver timely and accurate bills that are based on customers’ exact usage data
rather than estimates
M Develop future conservation initiatives that are targeted precisely to the gas,
water and electricity use habits of community residents
M Provide customers with comprehensive analyses of their consumption patterns.
MeterSense is supported by automated validation routines to ensure AMI data
meets high-quality standards. The solution also monitors AMI system operations to
identify and correct problems quickly. As a result, MeterSense will enable Medicine
Hat to optimize performance on its electricity grid, and serve customers faster and
with more accurate and comprehensive data than ever before.
Thanks in part to MeterSense, the city of Medicine Hat expects that its smart-
meter program will pay for itself in approximately seven years.
For more information, visit www.medicinehat.ca and www.metersense.com.
City Council Votes C
on GWP Smart Grid
Opt-Out Option
The Glendale (California) city coun-
cil unanimously voted on charging cus-
tomers a fee of US$59 per billing period
for having electric and water smart me-
ters with the radios turned off.
The fee for opting-out is assessed
because the smart meters will be read
manually by a meter reader instead of
wirelessly through Glendale Water &
Power’s system. The utility stresses the
importance of having digital meters
with radios turned off as opposed to
analog meters in order to have access to
interval data to meet energy objectives.
Less than one-half of 1% of customers
in Glendale have requested to opt-out.
Visit www.glendalewaterandpower.com.
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April 20122 | www.tdworld.com18
TECHNOLOGYUpdates
NERC Reports Loss of Reactive Power and Voltage Instability Most Likely Outcome from a Geomagnetic Disturbance
g
By Eric Rollison, North American Electric Reliability Corp.
The highly complex, interconnected North American power grid has provided a long record of reliable, secure delivery
of electric power. Industry has a long record of reliable operation and addressing natural risks that could affect reliability. It is
because of this commitment, a North American Electric Reliability Corp. (NERC) task force was formed to address solar storm,
or geomagnetic disturbance (GMD) events, which can disrupt normal power grid operations.
NERC’s 2012 Special Reliability Assessment Interim Report: Affects of Geomagnetic Disturbances on the Bulk Power System
indicates the most likely result from a severe GMD is voltage instability. The stability of the bulk power system can be affected by
changes in reactive power profiles and extensive waveform distortions from harmonics of alternating current, both from half-cycle
saturated high-voltage transformers. The potential effects include overheating of auxiliary transformers, improper operation of
relays and heating of generator stators, along with potential damage to reactive power devices and filters for high-voltage dc
lines.
According to scientists, solar coronal holes and coronal mass ejections (CME) are the two main categories of solar activity
that drive solar magnetic disturbances on Earth. CME create a large mass of charged solar energetic particles that escape from
the sun’s halo (corona), traveling to Earth between 14 and 96 hours. Geomagnetic-induced currents that interact with the power
system appear to be produced when large CME occur and are directed at Earth.
NERC’s report identifies 33 recommendations to mitigate the impact from large GMDs. NERC and EPRI have begun work on
these recommendations to provide users, owners and operators of the bulk power system enhanced knowledge and expertise to
address GMDs and ensure the grid’s continued reliable operation.
Immediate follow-on actions include updating NERC’s May 2010 GMD alert and enhancing system operator training with GMD
coursework. For more information, contact Eric Rollison at [email protected].
NEMA Encourages Action to ExpandN
Meter Socket Lifespan and Inspections
gg
As utilities move toward two-way communications for meters and remote meter
reading, the opportunity for inspection of meter sockets is expected to decline. The
interval between site visits by utility personnel could be more than 100 times longer
than current monthly schedules.
NEMA recommends that all existing meter sockets be thoroughly inspected
when new electrical meters are installed. Inspection criteria should include (but not
be limited to) indications of excessive heating, corrosion, loose connections or com-
ponents, deformed socket jaws, broken components, failed insulation, damage due
to ground settling or vandalism, or any exposed live parts. If any damage is discov-
ered, the meter socket should be replaced by a qualified electrician immediately.
For more information, www.nema.org.
ATC Builds Transmission Line in WisconsinA
A new 7.7-mile (12-km) transmission line between the Canal Substation in Stur-
geon Bay, Wisconsin, U.S., and the Dunn Road Substation in the Town of Sevastopol
has been placed in service ahead of schedule and under budget by American Trans-
mission Co. (ATC), boosting area reliability of electric supply.
The project, which was approved by the Public Service Commission of Wisconsin
in August 2010, came in about US$1 million under budget and was placed in service
nearly three months ahead of schedule. Final cost of the project is estimated to be
$15.8 million. ATC’s 10-Year Transmission System Assessment calls for an extension
of the line from Dunn Road to Egg Harbor as a provisional project for the future.
For more information, visit www.atcllc.com.
WECC ContractsW
with Siemens PTI for
Data Collection Tool
Siemens Power Technologies Inter-
national (Siemens PTI) has entered into
an agreement with the Western Electric-
ity Coordinating Council (WECC) to
deliver WECC’s Base Case Coordination
System (BCCS) planning tool.
The BCCS solution, based on Sie-
mens PTI’s Model on Demand (MOD)
software, will improve the collection and
compilation of WECC data used to build
its transmission system study models.
With the project scheduled for com-
pletion in December 2012, the BCCS
will enable WECC and its members to
streamline data collection and the case
building effort in the region. The BCCS
provides a means to create a nearly infi-
nite number of scenario cases and could
save the average WECC member an es-
timated 12 to 15 weeks of labor per year.
The centralized data base within the
BCCS solution also ensures model data
consistency, data accuracy and provides
tracking and data logging to comply
with North American Electric Reliability
Corp. standards.
Visit www.usa.siemens.com.
Supported by a global network of application experts, the Multilin 3 Series
delivers advanced system integration flexibility with robust communication
options including IEC 61850.
The Multilin 3 Series protection relays feature detailed asset diagnostic
capabilities, and a robust draw-out design to maximize uptime. Customers
rely on GE’s Multilin 3 Series to protect their essential electrical infrastructure
and critical assets.
From oil and gas and mining, to utility substations and light
rail, GE’s Multilin™ 3 Series provides advanced protection for
feeders, motors and transformers in demanding environments.
)DVW��DFFXUDWH��ÀH[LEOH�SURWHFWLRQ
g Energy
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Worldwide Tel: 905-294-6222
North AmericaTel: 1-800-547-8629
Europe/MiddleEast/AfricaTel: +34 94 485 88 00
April 20122 | www.tdworld.com20
TECHNOLOGYUpdates
CRC Partners with TextPower to Offer C
Outage Reporting via Text MessagingCooperative Response Center Inc. (CRC), a nationwide contact center and
central station, announces its business partnership with TextPower Inc., a text
messaging (SMS) business solutions provider based in San Juan Capistrano, Cali-
fornia, U.S.
By using TextPower’s SmartAlerts texting solution, CRC will enable its contact
center membership, mostly utility companies, to offer their consumers the option
to report power outages via text messaging. CRC will also use TextPower’s texting
service to verify outage restoration through text messaging.
For more information, visit www.crc.coop.
Transformers. Switchgear. Substations.
Integrated solutions. Automation. Services.
CG is a global leader in electrical products and integrated solutions.
Its products, solutions & services ranges from distribution & power
transformers, to medium & high voltage switchgear, to SCADA &
automation to complete turn-key substation EPC solutions.
CG has proven track-record of on-time delivery & completion at its
installed base of more than 20,000MW in North America, making
CG one of the most reliable and preferred equipment & solution
provider in renewable market today.
www.cgglobal.us
POWER LIFE
Visit us at IEEE,
May 8-10th 2012,
booth 643
69-kV GIS Switchyard6
Adds 200 MW
for City of Anaheim
The Canyon Power 69-kV gas-insulat-
ed switchgear (GIS) switchyard, a major
turnkey GIS project provided by ABB, is
now providing unprecedented levels of
local electricity for the city of Anaheim,
California, U.S.
This GIS switchyard interconnects
the new 200-MW natural gas-powered
Canyon Power Project in Southern Cali-
fornia to the city of Anaheim’s electrical
system. The project now provides up to
150,000 residential customers with addi-
tional local electricity to meet Anaheim’s
peak demands, particularly during its
hot summer months. The switchyard
will also upgrade local electric system
reliability, reduce Anaheim’s reliance
on out-of-state power resources and en-
hance the city’s ability to provide cleaner
energy to its customers.
The Southern California Public
Power Authority provided financing, the
city of Anaheim provided project man-
agement and ABB provided the project
on a turnkey basis, including all engi-
neering, equipment and construction
labor to design, build, test and commis-
sion the switchyard.
The city of Anaheim specified GIS on
this project because of the small space
available for the switchyard, together
with the higher reliability and lower op-
erating and maintenance costs associat-
ed with GIS equipment. This GIS switch-
yard is completely enclosed, because of
the low incremental cost of doing so and
the ability to make it completely immune
to local environmental conditions.
Visit www.abb.com.
ABB’s new 69-kV turnkey GIS switchyardprovides Anaheim’s peak power demandswith greater reliability and cleaner energy through local generating resources.
April 20122 | www.tdworld.com22
M Working with public officials, public/private entities,
automakers and other industry stakeholders to help develop
local charging infrastructure
M Developing technical standards with stakeholders for
various aspects of charging infrastructure to ensure technical
compatibility of electric drive vehicles, charging stations and
utility equipment
M Committing to transition more fleet vehicles to electric
drive as they become available and continue to meet opera-
tional needs
M Providing new rate options to customers that will encour-
age off-peak charging of PEVs
M Updating call center training to incorporate PEV knowl-
edge and issues
M Developing utility websites to provide customers with the
latest information and education about PEVs.
Garnering Support from the Utility Industry
Just as this is an important year for PEV market growth,
2012 is also a year when many electric utilities are develop-
ing or expanding their commitment to supporting PEVs. For
those electric utilities that are just beginning to promote PEVs,
EEI has produced a free booklet to help, “Utility Guide to PEV
Readiness.” The EEI guide covers the topics that every utility
will need to address to make sure PEVs get off to a fast start
in their service area: how to get up to speed, how to prepare
customers, how to identify which stakeholders to involve and
how to prepare for the charging experience.
In the guide, utilities will learn about relevant issues, benefit
from the advice and expertise of industry leaders, such as the
Electric Power Research Institute and the Electric Drive Trans-
portation Association, and discover the lessons learned by the
EEI member companies whose service areas were among the
first to get the new PEVs.
The PEVs on the road today are symbolic of the role elec-
tricity plays in powering progress. From iPads to the Internet,
electricity continues to make possible the technologies that
enable our world and our lives to be more productive and more
satisfying. In getting the marketplace ready for the new cars,
the electric utility industry is now setting the stage for electric-
ity to power even greater progress in the 21st century.t
Rick Tempkin ([email protected]) is the executive director
of retail services for the Edison Electric Institute. For more
information on the electric power industry’s support for PEVs,
visit www.eei.org.
QuarterlyREPORT
PEVs Move into the Fast Lane
By B Rick Tempchin, Edison Electric Institute
Plug-in electric vehicles (PEVs) have arrived, and elec-
tric utilities soon will be able to reap the benefits. The
Chevy Volt and the Nissan LEAF — first introduced in
limited markets in 2010 — are now available nationwide. And
most other major auto manufacturers, including Toyota, Ford
and Mitsubishi, along with numerous start-ups, will be offer-
ing a PEV model of their own this year.
This new era in electric transportation is great news for
consumers. The majority of PEV drivers will be able to make
their daily trips on battery power alone, without having to stop
at the gas station. And when PEV drivers do need to fill their
tank, they will be able to recharge their car’s battery at home,
using a stable, domestic fuel source that currently costs about
one-fourth the cost of gasoline.
In addition, PEVs will have a positive impact on the electric
power industry. Beside the opportunity for new revenue, the
PEVs create new channels for building customer satisfaction
and relationships. And in the future, this new electric technol-
ogy has the potential to connect with other emerging technol-
ogies such as smart meters, distributed generation and energy
storage to give customers a broad range of energy options.
Creating a Market for PEVs
Given the many positive attributes of PEVs, Edison Elec-
tric Institute (EEI) and its member companies are working to
build and strengthen the market for them. A primary goal is
sustaining policymaker commitment at both the federal and
state level to help PEVs become a practical transportation al-
ternative for everyone. Congress, in particular, has a signifi-
cant role to play in securing a place for electric vehicles in the
country’s transportation fleet.
The American Recovery and Reinvestment Act of 2009 pro-
vided a tax credit of up to US$7,500 for purchasing a PEV. The
tax credit helps to offset the incremental cost of these advanced
vehicles so they can reach scale production. And in helping to
stimulate sales of PEVs, the tax credits benefit America as well,
by reducing foreign oil imports and tailpipe emissions, along
with creating jobs in auto and battery manufacturing and PEV
charging station infrastructure. EEI will continue to advocate
for its extension, along with preserving and protecting the ex-
isting U.S. Department of Energy budget supporting electric
transportation technologies.
Making a Difference
At the state and local level, EEI and its member companies
are involved in supporting PEVs through many activities:
License key and serial number unique to each foot of your cable
Web-based interface provides access to ownership data 24/7
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24 April 20122 | www.tdworld.com
CHARACTERSwithCharacter
A Lineman’s Legacy
Dennis Kerr, rrInt’l Lineman’s Rodeo Association
ByB Stefanie Kure, Contributing Editor
Dennis Kerr may have retired from DTE Energy
(Detroit, Michigan, U.S.) in August 2009, but the 65-
year-old’s schedule remains busier than an electri-
cal crew helping restore power after a major storm. A former
journeyman lineman and safety trainer, Kerr serves as the
co-chairman of the board of directors for the International
Lineman’s Rodeo Association, is a long-standing executive
member with the Michigan Safety Conference and heads up
the Michigan Lineman’s Association. Despite the many hats
he wears, his preferred role is that of father and grandfather.
Raised in Bad Axe, Michigan, Kerr attended Ferris State
College, where he earned an associate’s degree in business.
After graduation, he joined Detroit Edison, which later be-
came DTE Energy.
“I hired on with the company because they were accepting
lineman apprentices,” he said. “I started out at the end of a
5-foot shovel, digging holes and setting poles.”
Just six months into his employment, however, Kerr was
drafted to the Vietnam War. Instead of joining the Army, he
enlisted in the Navy, becoming a second-class yeoman and
running a personnel office during his last year aboard ship.
“I returned to DTE in 1971 when my military obligation
ended,” he recalled. “I entered their apprenticeship program
and became a journey lineman three years later. I climbed
poles until 1982, and then moved to our technical training
center to help train apprentices.”
Kerr also worked in the company’s college professional
recruitment area and was a division instructor responsible for
the safety and training at three lineman service centers.
“Before 1985, all of our training records were kept by hand,”
he said. “I had five filing cabinets filled with paperwork. One
of my colleagues suggested we put the records into a personnel
training history system to streamline the process. It was quite
an undertaking and took a lot of effort, but it was a real plus
once we finished the project.”
Kerr next returned to corporate training as supervisor for
overhead and underground lines training and then took an
operating supervisor position at one of DTE’s service centers,
where he spent the last 12 years of his career.
Retirement has allowed the former lineman to become
even more involved in one of passions: the International Line-
man’s Rodeo. Held annually in Bonner Springs, Kansas, U.S.,
this event attracts nearly 5,000 people from all over the world.
“I’ve been involved with the International Lineman’s
Rodeo since 1987,” Kerr said. “I took teams down there to
compete and then worked as a judge. Now, I’m the co-chair of
the board of directors.”
The former lineman is also chairman of the board of the
Michigan Lineman’s Association, which puts on a rodeo ev-
ery year, and is as a chief judge for the Gaff-n-Go Lineman’s
Rodeo in Virginia. In addition, he recently stepped down as
president of the Michigan Safety Conference, a two-day safety
training event held each spring that targets workplace health
and safety issues.”
“As you can probably tell, workplace safety still is a big part
of my life,” he laughed. “I think lineman’s rodeos are impor-
tant to the utility industry because they promote safety and
skills of the trade. It is dangerous to be a lineman, and partici-
pating in these events can help decrease that risk. They’re also
a bunch of fun.”
According to Kerr, lineman’s rodeos also help raise aware-
ness of the trade — something he feels is important.
“We are suffering from a lineman shortage,” he said. “Most
high school curriculums are geared toward students who will
go on to college, but college is not for everyone. Being a line-
man takes dexterity, physical fitness and a love of the outdoors,
which are traits a lot of today’s young people possess. We need
to do a better job of promoting the trade at the high school
level, because it is a very exciting profession.”
Kerr experienced some of this excitement firsthand dur-
ing his time as a journeyman lineman, such as when he and
another member of his crew were caught in a tornado.
“We had just finished up a job so we were in our bucket
truck filling out paperwork,” he remembered. “All of a sudden,
the wind picked up and it began storming. Then, the truck
began rocking violently back and forth. It got so dark that I
could not see the guy sitting next to me. This was back before
all the weather technology existed, so we did not find out until
the next day that a tornado had passed right over us.”
These days, the father of three prefers to keep his excite-
ment mostly contained to the golf course and watching his
grandchildren’s musical and sporting events. However, he still
finds time to enjoy a little adventure.
“I recently spent a week in Florida with my son and three
of my grandkids kayaking, swimming with manatees and dol-
phins, and doing some simulation skydiving,” he said. “I am
grateful to have lived long enough to reach retirement so I can
spend as much time as I can with family and friends.”
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29www.tdworld.com | April 2012
Modern design tools streamline substation work processes.
By Gene Wolf, Technical Writer
Designing a substation using old-school techniques
eats up labor hours like a 747 sucks up jet fuel. It is
just amazing so many companies still subscribe to
those same labor-intensive approaches that engi-
neering departments were using almost 100 years ago.
Of course, some innovative utilities and engineering fi rms
are pioneering new engineering processes, but the majority
of engineering departments are designing substations manu-
ally like fi ne Swiss watches. Each substation is carefully craft-
ed: a work of art, one of a kind, an anachronism. If cars were
produced this way, everyone would be walking; the cars would
take too long to build and be way too expensive for most
people to afford.
A technological tsunami is swamping the electric utility
industry today. The smart grid is everywhere. It started with
meters. Then it moved to communications systems and load-
management software. It was not long before focus shifted to
the actual transmission and distribution grid.
Utilities added sensors, sophisticated monitoring compo-
nents and diagnostics to the equipment. Computerized pro-
tection and control systems grew. Communications came in
the form of fi ber optics and stand-alone smart substations net-
worked with other smart substations, forming smart grids.
Technology-Enhanced Engineering
This optimization is taking place in the engineering design
process, as well. Like the hardware-oriented portion of the
electric utility industry, the engineering department has a lot
of smart tools in its toolbox, but they tend to be stand-alone.
Engineers have Microsoft spreadsheets and database pro-
grams. Add computer-aided design (CAD) programs like
AutoCAD’s Inventor, Bentley’s V8i, Intergraph’s SmartPlant
3D and Power Line Systems’ PLS-CADD, and include ana-
lytical programs like ETAP, EMTP-RV and CYME. And the
toolbox is growing. However, the system is still fragmented,
disconnected and uncommunicative.
Industry-wise, utilities are stuck somewhere between the
19th century and 21th century technologically. Manual paper-
based tasks coexist with some form of computer-assisted pro-
cesses, but paper trumps technology.
Skilled designers spend their time at CAD workstations
manually making detailed construction drawings (plan views,
sections, a conduit plan, a foundation plan) one line at a time.
When the drawings are done, highly trained engineers manu-
ally count the components (length of conduit, number of insu-
lators, nuts and bolts) and fi ll out requests for purchase orders
by hand. Is this the best way to use a critical resource?
30 April 20122 | www.tdworld.com
SUBSTATIONDesign
Leading the Way
Although in the minority, a few organizations have evolved
to the 21st century. They are using digitally enabled technol-t
ogy that is connected across the enterprise, and that is the real
story with designing substations in the 21st century. Utilities t
such as Public Service Company of New Mexico (PNM), Amer-
ican Electric Power, Duke Energy, Nashville Electric Service
(NES) and Progress Energy Carolinas have realized how inef-
ficient the traditional approach was and how badly it needed
optimization.
They recognize engineering-based software is capable of
more. It can be linked to the business units of the enterprise. It
can reduce many of the labor-intensive tasks, such as entering
data automatically, and manage the project more efficiently.
They also understand something has to be done to meet the
expected crush of modernization required by the grid to meet
customer demand for electricity.
One recent survey by SBI Energy estimated that, from 2006
to 2010, globally, utilities added approximately 11,000 new sub-
stations to their systems. SBI went on to predict that, even with
the economic slowdown, roughly 8,000 more new substations
will be added worldwide between 2011 and 2015. That is about
1,600 substations per year and does not include retrofitting or
expanding all of the existing substations that number in the
hundreds of thousands globally.
Substations in the Crosshairs
It can take a couple of engineers four to six months to de-
sign a simple distribution substation (transformer, switchgear,
A virtual substation model improves public meetings and the permitting process. Courtesy of PNM.
isolation devices and feeders). Move up in complexity to some-
thing like a transmission substation, and time consumption
increases exponentially. With numbers like those, something
has to be done to simplify the engineering process.
There is no reason designing a substation cannot be auto-
mated for the most part. Take a look at the typical one-line
diagram. It does not take a rocket scientist to figure out they
are all pretty much the same.
Of course, there will be cases that require some customi-
zation, but automated substation design typically follows the
Pareto principle, more commonly known as the 80-20 rule. In
other words, at least 80% of substation projects can use pre-
defined standardized designs while only 20% or fewer will
require some form of customization. That is a pretty good pay-
back for the effort.
The solution is a standardized design. PNM developed
standard designs for its substations more than 20 years ago.
The utility recognized that by selecting a few basic configura-
tions, it could streamline the engineering process.
“Once the standard configurations were defined, tech-
nicians in the CAD and GIS department customized their
AutoCAD software with VLISP routines to create a series of
customized menus they called 3D-DASL, now available as
a plug-in for AutoCAD,” said Gathen Garcia, CAD and GIS
manager of PNM.
“The designer had only to select the specific substation con-
figuration and 3D-DASL did the rest,” Garcia explained. “The
menus produce a complete set of detailed construction draw-
ings. The best part of the process is the fact that the drawings
31www.tdworld.comm | April 2012
SUBSTATIONDesign
are 3-D, only minimal training was necessary for the designer
and the design/drafting process has been reduced from sev-
eral months to less than eight hours.”
NES reports it has been using 3-D models for many years,
too. NES is using Autodesk’s Inventor software for new substa-
tions and retrofits to existing stations. NES’s engineers have
created a library of parts or blocks for equipment and substa-
tion components. As it developed the system, NES realized it
could enhance those blocks with additional information such
as embedded standards, automated calculations and material
information.
Duke Energy also has been transforming its substation
Terrestrial LiDAR can be used in congested locations inside an energized substation without placing personnel in danger. Photo by Gene Wolf.
Terrestrial LiDAR mapping equipment in an older substation. Courtesy of Merrick & Co.
HVI produces many higher kVA AC Test Sets for
performing AC withstand testing on all types of electrical
apparatus. These include corona free sets for
performing partial discharge testing on switchgear,
bushings, breakers, motors, linemans safety
equipment/accessories, distribution transformers, etc.
(Pd equipment not availabe from HVI.) Various control
packages are available: simple manual controls,
automated and computer interfaceable controls, and
fully microprocessor based controls for complete test
automation and data collection. Contact our
sales department for more information.
High Voltage, Inc. offers a full line of AC Dielectric Test Sets up to 300 kV in voltage and 40 kVA in power.
31 County Rt. 7A
Copake, NY 12516
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(�0DLO��[email protected]
:HE��ZZZ�KYLQF�FRPHPA-5010FC1
0-50kV @ 10kVA
HPA-1010 FC3
10kV @ 10kVA
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Ideal Model for Motor
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32 April 20122 | www.tdworld.com
SUBSTATIONDesign
Global Interest
The 3-D substation design is a worldwide phenomenon.
Hydro-Québec started developing its internal 3-D CAD capa-
bilities in 2004. The utility uses software from Dassault Sys-
tèmes to build up its 3-D substation modeling system. Hydro-
Québec reports that the software allows it to join all of the
various engineering groups together to produce unique 3-D
models of its substations, which improves the quality of the
deliverables and efficiency of the engineers.
The East China Electric Power Design Institute (ECEPDI)
has made the transition from 2-D to 3-D and has designed the
world’s largest underground substation using Intergraph’s
SmartPlant 3D engineering and design software. The Shang-
hai Jing An 500-kV substation was designed to supply power
for the Shanghai World Expo. ECEPDI has been using the
SmartPlant 3D program for many years and says it increases its
productivity, especially on complex projects such as this one.
Expanding 3-D
Other technologies such as light detection and ranging
(LiDAR) are also finding their way into the optimization pro-
cess. Terrestrial LiDAR (T&D World, August 2011) has proven
to be an excellent tool for substation expansion projects. A
large percentage of existing substations were built 50 years ago
or more, and detailed drawings of the stations may be out of
date, incomplete or, worst case, missing.
Terrestrial LiDAR scanning can provide a comprehensive
survey of all the equipment, structures, foundations, bus work
and lines in the substations. In a few hours, a couple of techni-
cians can take a laser snapshot of the substation without being
exposed to any dangerous clearance issues normally associ-
ated with energized substation work.
The LiDAR 3-D model can serve as a virtual substation on
the engineer’s computer, giving the engineer the capability of
design process. The utility saw the need to link software, data-
bases and processes to reduce time-consuming manual tasks
into digitally enhanced efficient methods. The Duke system
uses 3-D digital models of the substation created by Autodesk
software using intelligent equipment blocks integrated to oth-
er business systems. Duke has automated tasks such as bills
of materials (BOM) to eliminate the need to count parts and
components manually for procurement.
The Industry Responds
Industry vendors such as Bentley Systems also have been
working along these lines. The company’s substation V8i soft-
ware offers utilities some interesting 3-D substation modeling
and integrated connections between MicroStation, Project-
Wise and ORACLE SQL databases.
Consulting engineering companies also are adapting tools
to improve their efficiency. Black & Veatch offers 3-D render-
ings with automated links to other business systems. POWER
Engineers is developing a smart one-line diagram with embed-
ded intelligence and links to instruction books, drawings and
manuals. Mike Beehler, vice president, Burns & McDonnell,
said, “Within the next five years, Burns & McDonnell expects
to see all domestic substation design drawings to be in 3-D.
Internationally, they see just about all design drawings utiliz-
ing 3-D capabilities.”
Beehler tells of advances Burns & McDonnell has made in
the area of adding intelligence to the 3-D models. “Many of
today’s equipment suppliers provide detailed drawings in 3-D.
These third-party drawings are imported into cells developed
by Burns & McDonnell, along with steel structures, founda-
tions, bolts, wire jumpers and everything else needed. The
cells will allow for complete BOM to be generated by the soft-
ware rather than have skilled designers manually count parts
and components,” he reported.
A 3-D substation model generated from AutoCAD using 3D-DASL plug-in. Courtesy of PNM.
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34 April 20122 | www.tdworld.com
SUBSTATIONDesign
single-line analyzer function. The soft-
ware is used for designing IEC 61850-
based substations. These can be complex
schemes with each intelligent electronic
device (IED) communicating with other
IEDs and the supervisory control and
data acquisition (SCADA) system. The
engineer scans a one-line diagram into
the program, and in the simplest terms,
the program recognizes the devices, as-
sists the engineer with connections and
lays out the communications system. This
program replaces all the vendor tools pre-
viously required to link IEDs and SCADA,
simplifying the process and removing
all the iterations previously required be-
tween sessions with the separate vendor
tools.
Digital Accelerators
Sophisticated software, laser scanning,
3-D digital models of substations, GPS surveying techniques,
links to business management systems and databases require
processing power, bandwidth and storage. Today’s substation
engineer can have instant access to any substation project doc-
umentation from an iPad.
A digitally enhanced optimized engineering scheme gives
automated designs, which generate the bill of materials linked
to the procurement system. Requests for quotes are created
automatically from the BOM and purchase orders are pro-
duced from the response. Project inventory is managed from
receipt to issuing to installation without data being reentered.
And that is only the beginning of 21st century technology t
streamlining the process. If it follows other transitions, it will
only get better.
Acknowledgment
The author wishes to thank PNM’s Gathen Garcia and John
Evaskovich for the graphics they provided for this article.
Companies mentioned:
AutoCAD | usa.autodesk.com/autocad
Bentley | www.bentley.com
Black & Veatch | www.bv.com
Burns & McDonnell | www.burnsmcd.com
CYME | www.cyme.com
Dassault Systèmes | www.3ds.com
EMTP-RV | www.emtp.com
ETAP | www.etap.com
Intergraph www.intergraph.com
Merrick & Co. | www.merrick.com
Oracle | www.oracle.com
POWER Engineers | www.powereng.com
Power Line Systems | www.powline.com
SBI Energy | www.sbireports.com
Schneider Electric | www.schneider-electric.com
making accurate measurements and identifying clearance is-
sues that may exist. The model also can be imported into any
of the major CAD programs available today. There, they are
rendered into a complete set of detailed as-built drawings for
the substation in only a few weeks. And if anything was missed,
the engineer can revisit it by going back to the computer and
quickly crunching some additional data points. No windshield
time is necessary; it is all in the LiDAR data cloud.
Game-Changing Technologies
Another area in which technology is changing substation
design is surveying. GPS gives unprecedented accuracy and
speed to the procedure. One utility requested a bid for the sur-
veying of a substation expansion. A traditional surveying com-
pany included five days of expenses for a crew of three in its
proposal. An engineering company using GPS surveying meth-
ods did the work in three hours with one person, and its base
price was half the cost of the traditional surveying company.
Every component in the substation comes with documen-
tation, which becomes a huge issue for storage and retrieval.
Years ago, manufacturers made the switch to digital files, but
the issue of retrieval across the enterprise is still a problem
with utilities. Merrick & Co. has an interesting approach. It
combines the 3-D LiDAR model with a panoramic visual data-
base and links to equipment databases.
In a nutshell, anyone in the enterprise with access to a com-
puter can view the 3-D LiDAR model. The panoramic photo-
graphs taken by the LiDAR technician at the time of the laser
survey can be viewed any time. If more information is needed,
the viewer can click on links to the equipment database and
see outline drawings, nameplates or instruction manuals.
Paper books, drawings and maps are limiting and no longer
needed with the digital technologies available.
Schneider Electric has developed labor-saving smart soft-
ware called System Engineering Tools, which includes a
A 3-D LiDAR isometric model of a substation. Courtesy of Merrick & Co.
36 April 20122 | www.tdworld.com
SMSMARARTTGrGridid
Wired for ucc ssKCP&L is retrofittingg Midtown Substaattioonn P&L is retrofitting Midtown SSubstationnSubstationwith updated communications protoccoollss as partt off a DDOOEE smartt griidd ddemonstrattiioonn project.By Ed Hedges, Kansas City Power & Light Co., and Matttheheww OlOlsoson, Burns & McDonnell
The smart grid may seem like a high-tech concept of
the distant future to some, but Kansas City Power
& Light is bringing it into the present with its smart
grid demonstration project. The U.S. Department of
Energy (DOE) awarded a US$24 million grant to Kansas City
Power & Light (KCP&L), to be matched by the utility and its
vendor partners. The DOE demonstration project will help
the utility gain knowledge about customer needs and usage the utility gain knowledge about customer needs and usage
patterns while improving service reliability and power delivery,
resulting in more efficient energy delivery and consumption
for an entire demonstration area within the city’s urban core.
End-to-End Demonstration
Like many other smart grid initiatives nationwide, KCP&L’s
DOE award originated with the American Recovery and Rein-
vestment Act of 2009. The two largest elements of this fund-
ing are the Smart Grid Investment Grant program and the
Smart Grid Demonstration Program. The latter focuses on
32 projects demonstrating new, more cost-effective smart grid
technologies, tools, techniques and system configurations. Of
these, half are energy-storage demonstrations; the other half,
including Kansas City’s project, are regional smart grid dem-
onstrations “to verify smart grid viability, quantify smart grid
costs and benefits, and validate new smart grid business mod-
els at scales that can be readily replicated across the country,”
according to a DOE statement.
Demonstration grants are designed to test cutting-edge
technologies or new customer pricing concepts, and the
KCP&L initiative stands out nationally as a fast-tracked,
end-to-end, fully integrated effort. KCP&L’s demonstration
includes nearly all elements commonly considered part of
the smart grid, with a heavy focus on implementing emergthe smart grid, with a heavy focus on implementing emerg-
ing standards and security measures. The utility conceived
the distribution component of its smart grid demonstration
project around an upgraded smart substation that features a
local distributed control system based on International Elec-
trotechnical Commission (IEC) 61850 protocols and control
processors. Created as a framework for the design of electrical
substation automation, IEC 61850 addresses the requirements
for interoperability of intelligent electronic devices.
Green Impact Zone
KCP&L’s demonstration project focuses on disadvantaged
neighborhoods in the Midtown section of Kansas City’s urban
core known as the Green Impact Zone. This 150-block area
has experienced economic decline and some abandonment.
As a national model for place-based investment, the Green
Impact Zone strategy aims to concentrate resources — through
Mark Adams of KCP&L, a protection and control engineer 1, programsa protective relay.
Dan Bayouth, Burns & McDonnell engineer, testing network perfor-mance in the Smart Grid Lab.
37www.tdworld.comm | April 2012
SMARTGrid
public and private partnerships — to transform homes and
businesses into a thriving, sustainable community. In addition
to housing renovations and property maintenance, efforts
include services, job training and placement, and health and
wellness programs. The smart grid serves an essential func-
tion in this transformation.
Deploying IEC 61850
One of the most significant developments for the smart
grid now is the application of information technology to help
optimize grid performance. Ideally, what this provides is more
reliable power on a grid that could evolve to be self-healing.
Soon, the grid will be intelligent enough to recognize a fault
and restore it automatically without customers having to wait
for a technician to service each individual failure. In many
ways, the smart grid is a new frontier in power — challenging
and full of opportunities for perpetual learning.
To achieve its objectives of improving service reliability,
KCP&L identified four IEC 61850-based substation automa-
tion schemes to implement at its Midtown Substation in the
Green Impact Zone:
M Automatic load transfer upon transformer lockout
M Faster clearing of the bus upon feeder breaker failure
M Backup overcurrent protection in the bus differential relay
M Cross triggering of all devices for distribution system
events.
These schemes leverage IEC 61850’s object-oriented com-
munications-centric design technologies that originated in the
information technology industry and are now being applied to
power delivery. KCP&L partnered with Burns & McDonnell
Smart meter
Web portal
Rooftop
solar panel
In-home display
Digital
thermostat
Time-of-use
pricing Electric
vehicle
Smart substation
Home area network
Smart end use
Public
charging
station
Commercial
building
Building energy
management system
Time-of-use
pricing
Rooftop
solar panel
Distributed energy
resources
School
Office
building
Smart building
Smart
distribution
Grid
management
Back office
Voltage/VAR
managementBiofuel
Solar
Smart generation
Electric
storage
Demand
response
Technologies demonstrated in KCP&L’s Smart Grid Demonstration Project.
Ethernet Communications Simplifies Substation ControlUsing a converged Ethernet network for all substation communications leverages Ethernet’s high-throughput, low-latency
and peer-to-peer communications to support multiple conversations using different protocols simultaneously on the same wire.
This simplifies substation control by allowing the network to serve as an open, standards-based communications platform to
build upon. It supports SCADA via the widely used Distributed Network Protocol 3.0 (DNP 3.0) while, at the same time, serves as a
platform for emerging peer-to-peer protocols like IEC 61850, engineering remote access and timing.
Adding switching to Ethernet made it deterministic, which was required for its use in industrial control. The switch changed the
physical layout of the network from a shared physical bus to a point-to-point star configuration. This allows for full duplex opera-
tion and the ability to queue packets in the switch. Queuing provides Quality of Service (QoS) by giving priority to time-depen-
dent applications like protection and control. Other modifications include standards based fiber interfaces and ability to support
redundant interfaces on a device at a cost-effective price point (due to its near-universal implementation in other industries).
These technology advancements at a cost-effective price point are increasing its usage in substations.
The benefits of Ethernet-based communications outweigh the training and compliance costs associated with using Ethernet
instead of serial communications. Securing Ethernet can be done more cost-effectively than securing serial communications and
provides security and not just compliance.
SMARTGrid
to assist in implementing these automation applications. As a
result, KCP&L will be able to implement schemes that restore
service automatically, reduce equipment stress and provide
information about protection events that previously were not
economically justifiable or widely deployed.
Load Transfer
The load-transfer scheme restores service to customers
by automatically closing the tie breaker upon lockout of the
transformer. The Midtown Substation design consists of two
four-position buses fed from a dual-wound distribution trans-
former. Tie buses are used for maintenance and emergency
backup of station operations when the transformer is removed
from operation. The combined load of the two buses can be
above the two-hour power rating for the transformer on many
of the buses.
In the past, a dedicated programmable logic controller
(PLC) was used at these locations to calculate the optimal
feeder configuration to transfer to the tie bus before the tie
breaker was closed. As part of the upgrade, KCP&L wanted
this logic to be moved into the relay logic, eliminating the
need for the PLC and additional wiring. This objective was
achieved through the use of automation logic in a SEL-451
relay, with the real-time event notification capabilities of
IEC 61850 generic object-oriented substation event (GOOSE)
messaging for inter-relay communications.
Project objectives were achieved by programming the feed-
er relays (SEL-751) to publish the individual feeder loads and
the total tie-bus transformer load (SEL-487) using IEC 61850
GOOSE messages. The main relay (SEL-451) subscribes to
these analog values along with status messages for bus lockout,
which triggers the scheme. The main breaker relay continu-
ally computes and publishes the optimal feeder configuration
to transfer if a fault occurs, based on each feeder’s load and
available capacity.
When each feeder relay sees the scheme-enabled GOOSE
message sent, it opens if it is to be shed before the bus tie
breaker is closed. This scheme uses the two-hour overload
power rating for the tie bus transformer, which gives the distri-
bution operator two hours to reconfigure distribution feeders,
thereby relieving the overload condition while continuing to
provide service to customers on the affected bus.
Faster Overcurrent Tripping
Implementing a communications-based breaker failure
scheme instead of relying on time overcurrent values resulted
in the faster overcurrent tripping of main and tie breakers
upon feeder breaker failure. When a feeder breaker trips, it
sends a GOOSE message to the main and tie breakers indi-
cating an operation where a stuck breaker timer is initiated.
SEL-751A tieSEL-451 mainSEL-487E
transformerSEL-487B bus SEL-751A
feedersPublishing Subscribing
Load transfer
Cross
triggering
Faster
overcurrent
tripping
Backup
overcurrent
tripping
GOOSE message flow diagram for Midtown Substation.
SMARTGrid
If a follow-up breaker-open message is not received within
this time, the main and tie breakers trip, thereby clearing the
fault. This faster overcurrent tripping scheme and subsequent
schemes reduce wear on equipment, decreasing the likelihood
of equipment failure and improving customer reliability.
Backup Overcurrent Tripping Scheme
Backup overcurrent protection in the bus differential re-
lay provides redundancy to the logic, sensors and wiring in
the feeder relays, allowing them to trip a feeder with a reclos-
ing function if the feeder relay fails to detect or clear a fault.
Intra-ringtie
Primary
systemBackup
system
RuggedCom
RSG 2100
Substation
firewall
Bus 6
relays
XFMR
relays
DMS – HMI
Siemens SICAM
PAS
Cisco
CGS 2520
Switchgear enclosure Switchgear enclosure
Switchgear enclosureSwitchgear enclosure
Control enclosure
Bus 5
relays
Bus 7
relays
Bus 8
relays
Bus 4
relays
Bus 3
relays
Bus 1
relays
Bus 2
relays
RuggedCom
RSG 2100
Cisco
CGS 2520
RuggedCom
RSG 2100
root
Cisco
CGS 2520
RuggedCom
RSG 2100
Cisco
CGS 2520
RuggedCom
RSG 2100
Cisco
CGS 2520
The Midtown Substation communications network.
40 April 20122 | www.tdworld.com
SMARTGrid
The bus differential relay uses its current circuit and sensor to
monitor the feeder, and it is programmed to send a GOOSE-
based trip message to the feeder relay, clearing the fault if the
feeder relay has not already done so.
This scheme and the previous scheme could have been
implemented using pre-IEC 61850 protection and control
designs and techniques, but they were not cost effective to im-
plement. Using the common communications bus reduces the
cost of implementing these additional schemes to program-
ming and testing. Once the schemes are initially developed
as part of this pilot, they can be used for future projects at a
marginal cost.
Cross Triggering
Cross triggering of all devices for every distribution system
event and at a specific time each day provides the engineering
department with detailed oscillography and event informa-
tion. This information explains how the protection and con-
trol functions worked under fault conditions. Previously, event
information was only available from fault recorders, which
were not cost-effective for distribution substations.
KCP&L’s design leverages the power of relays for recording
waveforms and IEC 61850 GOOSE messages to cross trigger
devices, enabling station-wide awarenesss that had been im-
possible in the past. Analyzing this information allows schemes
and settings to be optimized, providing customers with more
reliable service.
Robust Ethernet Communications
Reliable communication is required for IEC 61850 opera-
tion. As part of the pilot, the Midtown Substation was retrofit-
ted with a redundant Ethernet communications network with
hardware from two switch vendors (RuggedCom and Cisco)
for protection operation. Using two vendors allowed KCP&L to
evaluate the products simultaneously to determine which was
best suited for substation protection and control networks.
Each vendor’s equipment was used to build a ring in the
substation, and each relay has an interface connected to both
rings. The rings are interconnected at two points for redun-
dancy. The core ring was built using gigabit fiber connections.
The relays each have two 100-Mbps Ethernet interfaces used
in a hot standby configuration. Each vendor has its own pro-
prietary protocol for blocking loops from forming in the Eth-
ernet network while recovering from a link failure in less than
50 msec. In between the rings, rapid spanning tree protocol
was used to provide failover in less than 250 msec.
In addition to a protection local area network (LAN)
within the substation, a firewall was used to isolate a separate
LAN for substation automation equipment. A third LAN was
used to create a secure enclave for communication outside the
fence to an Ethernet-based wireless mesh for field device com-
munications. KCP&L was able to follow the National Institute
for Standards Interagency Report (NISTIR) 7628 standards
for smart grid security by segmenting the substation LANs.
This design also provided an operational benefit by grouping
devices by operational priority, allowing more changes to be
made to the automation LAN without consideration for sched-
uling an outage on the protection LAN.
All relays except the transformer protection relays were in-
stalled on the doors of switchgear cubicles. The fiber jumpers
Primary
system
MainAux 1Aux 2Feeder 1Feeder 2Feeder 3Feeder 4Bus tie
SEL-751A
bus tie
SEL-751A
feeder
SEL-751A
feeder
SEL-751A
feeder
SEL-751A
feeder
SEL-487A
bus
SEL-451A-5
main
P1A P1B
Primary
Ethernet
switch
RuggedCom
RSG 2100
To
control
enclosure
Fiber
distribution
panel
Backup
system
P1A P1BP1A P1B P1A P1B P1A P1B P1A P1B P1A P1B
To
adjacent
bus
Typical switchgear physical arrangement.
41www.tdworld.comm | April 2012
SMARTGrid
running between the cubicles from relay to switch are subject
to more fatigue than normal designs for jumpers. As a result,
a crush-resistant jacket from the Optical Cable Corp. was
specified to cover the jumper. Coloring the jackets red or blue
simplifies identification of the two separate rings. The same
jacket was used on a 12-fiber multimode jumper with mechani-
cal transfer push-on/off (MTP) connectors used for cabling
between the various breaker lineups and the station control
house.
To fan out the MTP connector into little connectors, a pre-
terminated cartridge was used to provide 12 little connectors
on the front and a MTP connection on the back. Two 12-fiber
jumpers were run to each switchgear, pro-
viding redundant connectivity. Using a
hardened pre-terminated fiber system re-
duces outage duration by eliminating any
field terminations and special training
for the electricians performing the relay
replacement. The hardened cable elimi-
nates the need for inner ducts to identify
and protect the fiber cables, allowing
them to be installed in the cable trays and
trenches with other control cables.
Primary operator monitoring and con-
trol of the substation will be through a cen-
tralized distribution management system
(DMS) and a local SICAM PAS controller
from Siemens in the station. The SICAM
will communicate with the relays using
the IEC 61850 manufacturing messaging
specification (MMS). During the pilot, se-
rial communications will be maintained
to each relay from the substation remote
terminal unit to support dual communi-
cations with the relays from the existing
energy management system (EMS).
This second channel will provide
backup capabilities for substation control
based on a proven technology from the
existing utility operation systems. This
will allow flexibility with the manage-
ment of the DMS during the pilot. Such
an approach also simplifies the security
measures required to maintain secure
communications with the EMS, which is a
North American Electric Reliability Corp.
(NERC) critical infrastructure protection
critical asset.
Local clocks in each switchgear lineup
will provide time coordination to the
relays. Once precision time protocol is
supported in relays, a single network-
connected clock could be used to provide
time coordination through the redun-
dant fiber Ethernet connections, elimi-
nating additional wiring.
Ready for IEC 61850?
Deploying IEC 61850 requires coordination and cross-
training from at least four areas of the organization: protec-
tion and control, information technology, security and com-
pliance, and maintenance. By forming a cross-functional team
that leverages each organization’s expertise, the collective can
work efficiently and effectively, and make decisions about what
technology to deploy.
Establishing a combined lab where equipment can be
staged and tested is key to educating all affected departments
on the new technology. It also can be used to validate both the
equipment and the design in a controlled environment before
42 April 20122 | www.tdworld.com
SMARTGrid
it is installed in the field. Burns & McDonnell’s Smart Grid
Lab was used to test communications and relay settings during
design while KCP&L was developing its own lab.
Beyond the Fence
In addition to using IEC 61850 for communications within
the substation, KCP&L plans to implement the MMS protocol
outside the substation for supervisory control and data acquisi-
tion (SCADA) communication between the field devices and
substation-based distribution automation controller and the
DMS. Initially, field devices will be deployed using distributed
network protocols, which will be converted to MMS protocols
as it becomes available in field device controls.
Using an IP mesh network in the field reclosers, capaci-
tors and fault indicators provides a low latency wideband
communications path for beyond-the-fence communication.
This capability paves the way for future improvements, such
as high-speed bus transfer schemes using GOOSE messages in
the field area network. These messages could be used to iso-
late faults and close tie switches, transferring the load in real
time and, thereby, eliminating momentary outages, which are
becoming a bigger concern for customers.
A Smart Grid Future
IEC 61850 is often considered for new substation construc-
tion, but this project showed that it brings the same benefits to
an existing substation. Using IEC 61850 in a retrofit applica-
tion allowed KCP&L to retain its existing wired controls and
test the standard while retaining the existing protection and
control design. Once the final bus is complete in 2012, KCP&L
will benefit from the values of the increased information pro-
cessing in the station.
KCP&L’s demonstration project is modernizing power de-
livery in its demonstration area by leveraging the knowledge
and capabilities of information processing to restore service
and protect equipment from failure. Deploying new technolo-
gy, especially in a traditional utility environment, is filled with
challenging growth opportunities that require innovation,
teamwork and vigilance.
Acknowledgements
The authors would like to acknowledge Dave Rucker and
Tim Hinken of KCP&L, and Chad Stilwell and Meghan Lyons
of Burns & McDonnell for contributing to this article.
Ed Hedges ([email protected]) is manager of smart grid
technology planning at Kansas City Power & Light. He is respon-
sible for developing near- and long-term technology plans to
guide the development of KCP&L’s vision for the future energy
distribution network or smart grid. He is the lead technology
planner for KCP&L’s Department of Energy-funded regional
smart grid demonstration project. Hedges earned a BSEE
degree from the University of Illinois. He is a registered profes-
sional engineer in Wisconsin.
Matthew Olson ([email protected])
is an associate project manager in the
T&D division at Burns & McDonnell. He
has worked to deploy IEC 61850 and pack-
et-based utility networks supporting the
smart grid, and has 10 years of experience
designing and managing the deployment
of private communications networks.
Olson earned BSEE and MSEE degrees
from the University of Tulsa and is a reg-
istered professional engineer engineer in
Kansas and New Jersey.
Companies mentioned:
Burns & McDonnell
www.burnsmcd.com
Cisco | www.cisco.com
Kansas City Powel & Light
www.kcpl.com
North American Electric Reliability Corp.
www.nerc.com
Optical Cable | www.occfiber.com
RuggedCom | www.ruggedcom.com
Schweitzer Engineering Laboratories
www.selinc.com
Siemens | www.siemens.com
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44 April 20122 | www.tdworld.com
VEGETATIONManagement
LiDAR to the RescueA severe ice storm in Russia leads to re-evaluation of ROW status and vegetation management practices.By Boris Mekhanoshin, JSC IDGC Holding
From Dec. 25, 2010, to Jan. 10, 2011, several regions of
Russian, including the city of Moscow and the sur-
rounding district, were affected by an unusual mete-
orological event. Freezing rain resulted in a coating
of glazed ice on overhead line conductors and towers as well as
the crowns of trees located close to the rights-of-way (ROW)
through forests. The ice glaze accumulated to a thickness of
25 mm to 30 mm (1 inch to 1.2 inches) in some parts; in the
Ulyanovsk and Samara regions, the thickness was 35 mm to
40 mm (1.4 inches to 1.6 inches), exceeding, by a factor of four
to seven, the estimated rate of ice accretion for that of previ-
ous events.
Under the enormous weight of the ice, tree branches
clashed with overhead line conductors, causing ground faults,
broken conductors and damaged towers, which led to wide-
spread power outages in the three regions. The aftermath
of the freezing rain that damaged thousands of kilometers
of power lines and hundreds of towers left some 500,000
residents in the Moscow district without electricity for a long
period of time.
Widespread Network Damage
The overall picture of disturbances from this event oc-
curred in the Moscow, Nizhny Novgorod, Smolensk, Tver and
Pskov regions. There were three separate occasions, each last-
ing three hours, when the outages occurred at 133 master sub-
stations on the 35-kV and 110-kV networks and 10,330 outages
at 10/6-kV transformer substations.
The JSC MOESK distribution utility identified 273,000
fallen and dangerous trees, of which 232,000 were adjacent to
the 35-kV to 220-kV overhead lines and 41,000 were adjacent
to the 6-kV to 10-kV overhead lines. In total, 38 master substa-
tions on the 35-kV and 110-kV network and more than 3,500
10/6-kV transformer substations were temporarily shut down
in the Nizhny Novgorod, Smolensk, Tver and Pskov regions. It
should be noted the technical breakdowns were restricted to
the 110-kV to 6-kV distribution networks.
Russia’s United Electric System transmission systems, sub-
stations, relay protection and automation systems remained
undisturbed throughout this period. According to published
data, 470,000 people were without electricity for two to three
Extreme ice loading caused a tree to fall on this 110-kV transmission line.
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46 April 20122 | www.tdworld.com
VEGETATIONManagement
days while some localities, with se-
verely damaged overhead line feed-
ers, were without power for nearly
two weeks. The three peak distur-
bances and breakdowns occurred
during the period when the freez-
ing rain was at maximum intensity.
Breakdown Cause
The main causes of the wide-
spread power outages in the Moscow
region were trees falling on power
lines and their crowns touching the
conducting parts of transmission
lines because of the weight of accu-
mulated ice. Ice accretion is caused
by anomalous meteorological con-
ditions: sudden warming, long-term
super-cooled liquid precipitation
(freezing rain), and intensive icing
on trees and along overhead lines, conductors and towers.
Based on research conducted in the United States, the average
time of freezing rain is 2 hours to 4 hours for humid regions,
whereas the Russian weather data for freezing rainfall in the
Moscow region for this event lasted for 14 hours, exceeding
the monthly average rate of adverse weather by four to seven
times.
The primary cause of the massive loss of electricity sup-
ply was insufficient ROW clearance for power lines routed
through forests that belong to a special category of protected
69 70
5949
300
2222
217
178165 162
152
145131
111
97
88
74
5853
61
8591 92
63
4231
16 13 12
6
116
84
37
17 12
4 22 0 0
5
22 24 27 3 3 31 1 1
8,5
145,8
110
110,5
91,5
50
39
22 12,2 9,55,3 3,6 3,6
1228
4542 37
8,4
2,10 0
0
358
588
382
334
247
31
164
251273 297
424
464
562
690
648
621
153
256270
311384
394
255
282
0
50
100
150
200
250
300
350
06-
00
12-
00
18-
00
23-
00
10-
00
20-
00
12-
00
06-
00
23-
00
07-
00
22-
00
06-
00
18-
00
06-
00
11-
00
12-
00
21-
00
08-
00
14-
00
12-
00
16-
00
14-
00
20-
00
16-
00
20-
00
0
100
200
300
400
500
600
700
800
55
223
12/26 12/27 12/28 12/29 12/30 12/31 01/02 01/03 01/0401/05
01/0601/07 01/09
01/08
Electricity supply limitation was terminated Jan. 7, 2011.
Nu
mb
er
of
ou
tag
es (
tho
usan
ds)
Nu
mb
er o
f rep
air c
rew
s
Involved repair crews
Tripping OHL 35-220 kV
Tripping substation
Tripping citizens
Date for outage count and crew deployment
Week 1: Dec. 26-31, 2010 Week 2: Jan. 1-9, 2011
01/01
Number of tripping and repair activities during two weeks with freezing rain.
0
20
40
60
80
100
120
140
160
180
2008 2009 2010 2011
(January to April)
Overh
ead
lin
e o
uta
ges p
er
year
Total number of the overhead line
emergency tripping
Successful automatic reclosing
Unsuccessful automatic reclosing
Automatic reclosing disconnected
Years
The number of overhead line outages per year in MOESK‘s eastern grid.
forestry in the Moscow region. Long-term discussions about
forest usage rules and the requirements of the electrical instal-
lation rules had prevented utilities from adequately maintain-
ing the ROW. In August 2011, new legislation was approved
that allows adequate ROW to be created and maintained for
each voltage class.
To assess the extent of the technical breaches caused by
freezing rain, results based on a special analysis of sample data
of overhead line outages for the period from 2008 to April
2011, provided by the Eastern Electricity Grid department of
All of the above.��������������������� ������� ��������&#)� �'�##(�"��!#��&"�� ��(&��� � #��'�&�%)�&�'���$#*�&�) �"�*��&����
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Clamp MeterA B Oscilloscope C Data Logger D Power Meter
48 April 20122 | www.tdworld.com
VEGETATIONManagement
MOESK, were examined. The data confirmed the total num-
ber of overhead line outages in 2008 and 2009 were similar,
whereas the number of outages in 2010 increased by a factor
of three. This was caused by falling trees as a result of peat and
forest fires in the Moscow district in July 2010 to August 2010,
plus the faults due to ice accretion in December 2010.
The former rules for ROW specified 29 m (95.1 ft) for
35-kV to 110-kV overhead lines and 37 m (121.4 ft) for 220-kV
overhead lines, but the average height of the trees bordering
ROW was at least 25 m (82 ft). When these trees fall, they can
damage conductors, ground wires and sometimes even the
The typical result of ice accretion on trees too close to lines is a predict-able meeting of vegetation and line.
supporting towers. With insufficient width of ROW, it was dif-
ficult to undertake vegetation management, whereas regional
officials of the Federal Agency for Forestry Affairs had been
raising objections and assessing penalties for the clearance of
dangerous trees in the ROW. Now, with the new rules in place
for ROW, utilities can maintain adequate clearances.
Since the emergency situation in December 2010 and Janu-
ary 2011, utilities have continued to remove trees, cutting
crowns and branches in close proximity to overhead line con-
ductors. They have already removed more than 40,000 trees
from the overhead line corridors. To further improve the reli-
ability of supply, there is a planned expansion of the use of
insulated conductors for the 1-kV to 35 kV overhead lines.
LiDAR Surveys
Airborne laser survey (ALS) of overhead lines is now widely
used by utilities for updating the as-constructed documenta-
tion and monitoring the in-service condition of all overhead
line components. This includes conductors, ground wires,
towers, line insulation and the various buildings and struc-
tures located near the ROW.
JSC IDGC Holding regularly requests its 13 regional utili-
ties to employ ALS for infrastructure surveying. Vegetation
management is one of the main subjects of these surveys in
regions where large areas are covered with forests or other veg-
etation. For example, some territories in the southern regions
of Russia are covered with reeds and cane 3 m to 4 m (9.8
ft to 13.1 ft) tall that can disturb overhead line works during
drought and fire-danger periods.
The results of ALS are successfully used to verify the
technical condition of overhead lines and vegetation density
within power line corridors, as well as to determine the nature
of the crop, height and location to within accuracy of 0.01 m
JSC IDGC HoldingJSC IDGC Holding, a company operating in the electricity sector of the Russian Federation, comprises interregional dis-
tribution grid utilities (IDGCs /RDGCs) in addition to a large number of other companies. In total, there are 97 subsidiaries of
IDGCs/ RDGCs in 69 constituent entities.
The 13 JSC regions of the holding operations operate the distribution grid that comprises overhead lines at 10 voltage levels
from 0.4 kV to 220 kV. The key distribution grid statistics for 2010 indicate an installed substation capacity of more than 401,000
MVA and overhead distribution lines totaling 1,920,584 km (1,194,072 miles), of which 1,508,015 km (937,080 miles) operate in the
0.4-kV to 20-kV voltage range. Hence, IDGC Holding ranks among the world’s largest electricity utilities in terms of the length of
network and the total population (127.46 million) served in an area of 7.8 million sq km (3.0 million sq miles).
JSC MOESK is the second-smallest JSC region. It supplies the population of 17.143 million living in the city of Moscow and
the Moscow region through distribution lines that extend some 148,640 km (92,365 miles).
ROW Width for Overhead Lines with Bare Conductors
Nominal voltage (kV) ROW width in meters (feet)
to 1 2 (6.6)
1 to 20 10 (32.8)
35 15 (49.2)
110 20 (65.6)
150, 220 25 (82.0)
300, 500 30 (98.4)
49www.tdworld.comm | April 2012
VEGETATIONManagement
ance. Information on the area and type of trees and shrubs to
be cleared enables maintenance costs to be estimated.
Some of these surveys come back showing the ROW re-
quired a large volume of work because between 41% and 75%
of the territory was occupied with trees and bushes between
1 m to 10 m (3.38 ft to 32.8 ft) tall, while the specified conduc-
tor ground clearance should not be less than 6 m (19.7 ft).
This is the reason why vegetation causes phase-to-earth shut-
downs especially in summer, when the air temperature rises to
40qC (104qF) and above, and the clearance between conductor
and earth or vegetation decreases by between 0.5 m to 0.8 m
(1.64 ft to 2.62 ft).
(0.4 inches). Alternative methods of overhead line patrolling
do not determine the clearances between the conductors and
vegetation with such accuracy. Vegetation identified by the
ALS in ROW must be removed in accordance with recently
approved legislation.
Detecting Damaged Conductors
Tall trees that fall on overhead line conductors in many
cases cause short circuits and damage conductors internally
and externally. Defects of the outer conductor strands can be
easily noted during conventional inspections. To detect inter-
nal damaged strands, a nondestructive testing (NDT) device
has to be used.
The magnetic head is applied to detect any damage to the
steel wire core strands. The eddy current head also is used
to determine broken aluminum strands and any decrease in
the conductor cross-section. An ongoing program to test the
conductors on all spans where trees fell during the winter of
2010/2011 is currently in progress.
Estimating Vegetation Management
The results of ALS to determine vegetation management re-
quirements is used by utilities to determine the type of trees or
shrubs to be cleared and the area of the ROW requiring clear-
Result of ALS processing, the yellow denotes vegetation that needs to be cleared from the ROW (left). A span of double-circuit overhead linewhere each tree is taller than the phase conductors (right).
The NDT device inspecting damaged conductors.
Maximum Permissible Current for 110-kV Overhead Lines “TPP 21 – Novobratcevo” in Different Weather Conditions
Conductor:150 kcmil ACSR
Admissible continuous current, Amperesat an ambient air temperature, °C
Wind speed, m/s -5 0 5 10 15 20 25 30 35 40
0.0 370 340 260 230 190 140 60 0 0 0
0.5 490 460 390 350 310 270 210 140 0 0
1.0 570 540 470 430 380 330 270 200 50 0
2.0 680 640 570 520 470 410 340 260 130 0
5.0 880 830 750 690 630 550 470 370 230 0
50 April 20122 | www.tdworld.com
VEGETATIONManagement
Ground Clearance
Another result of the JSC IDGC Holding overhead line
ALS showed a signifi cant number of violations for line specifi -
cation parameters. The extent of the violations in terms of the
conductor to ground clearances on some 110-kV overhead line
spans showed 5.5 m (18 ft) of clearance, which was less than
the required value of 7 m (23 ft). The excessive conductor sag
was caused by creep, which is typical for aluminum conductor
steel-reinforced conductors exposed to the mechanical over-
loading of the freezing rain that caused abnormal conductor
elongation.
Companies mentioned:
JSC IDGC Holding
www.holding-mrsk.ru
OPTEN Ltd.
www.optensolutions.com
A Satisfactory Condition
Central Russia experienced a sequence of abnormal weath-
er conditions that started with an anticyclone in the summer
2010 that caused numerous forest and peat fi res. In turn, this
weakened tree roots, causing instability. This contributed
to the aftermath of the freezing rain in December 2010 and
again in January 2011, which resulted in serious damage to
the overhead line networks in Russian regions, including the
Moscow district.
The situational analysis subsequently undertaken con-
fi rmed the main contributing cause of the disturbances was
the unsatisfactory condition of the over-
head line ROW. ALS proved to be a
highly effective means for planning veg-
etation management, offering fast and
high-accuracy detection of the ROW
requiring clearance. Furthermore, the
survey database offers the opportunity
for distribution utilities to make an
economic appraisal of the measures to
restore the ROW for overhead lines to a
satisfactory condition.
Acknowledgement
The author would like to acknowl-
edge the technical assistance and sup-
port received during the preparation of
this article by Vladimir Shkaptsov and
Konstantin Konchenko at OPTEN Ltd.
Boris Mekhanoshin (Mekhanoshin-Bl@
holding-mrsk.ru) started his career in
fi ber-optic communications at the Mos-
cow Power Engineering Institute. He then
worked for the chair of Radio Transmis-
sion Devices and has been involved with
fi ber-optic technology until he joined
ORGRES, where he established the fi rst
fi ber-optic systems laboratory for the
Russian electric power industry. In 1992,
he was appointed deputy general direc-
tor of ORGRES. He was then president
and CEO of OPTEN Ltd., a company
specializing in design and construction of
communication networks and overhead
lines. Mekhanoshin joined JSC IDGC
Holding in 2010, where he was appointed
technical director and deputy general
director. He also is an individual member
of CIGRÉ.
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52 April 20122 | www.tdworld.com
CUSTSTTTOMOOOMOMMMERREEREE EnE gagageementt
Glleeeeeennnnnnnddddaalle WWWWWWWaaaaattttttteeeeeeeerrrrrr &&&&&& PPPPPPoooooowwwwwwwwwwweeeeeerrrrrrr invvveessttttsss iiinnnnnn ccccuuuusssssttttttooooooommmmer oooouuuuuuuutttttrrrreeeeeeeeaaaaaaacccccccchhhhhhh,,,, gggggaaaaaaaaiinniinngg eeeaaarrllllyy aaaaaaannnnnndddddd cccoonnttiinuous support , gg g y ppffor its smaart grid project. By Glenn O. Steiger, Glendale Water & Powerrr
In 2011, Glendale Water & Power (GWP) completed instal-
lation of more than 120,000 smart electric and water me-
ters, one of the utility’s largest projects, which started in
2009. The municipal utility in Glendale was one of the
fi rst U.S. utilities to connect and integrate all of its electric and
water customers using smart grid technology.
Some of the other fi rsts included being the fi rst city in theSome of the other firsts included being the first city in the
nation to sign a Department of Energy (DOE) grant for US$20
million that helped accelerate the installation of the smart
meters and also being one of the highest-ranking utilities by
the smart grid maturity model. GWP scored 5s for breaking
new ground by having an industry-leading innovation strategy
and organizational structure in its smart grid project. These
are two of the most important domains to ensure a successful
project as measured by the California Energy Commission’s
Energy Research division.
But, back in 2008, when GWP fi rst introduced its smart
grid business plan to the city council, the entire project was
expected to take approximately fi ve years. In 2009, the util-
ity applied for and won the DOE grant. Then, in 2010, GWP
completed its proof-of-concept phase, testing out 1,000 elec-
tric and 500 water meters. Smart meter installation started in
P expectslate 2010 and was completed by September 2011. GWP
e meters,to be fully functional in all aspects pertaining to the
ther thanincluding meter data maanagement, in two years rat
fi ve years.
Keeping Customers Enngaged
Customer engagement is an extremely important aspect of aspect ofCustomer engagemennt is an extremely important
any smart grid project. Keeping information fl owing to cus-
tomers, along with engaging and involving them as much as
possible, is key to a successfully adopted project. Customer
engagement and outreach were a top priority for GWP on its
smart meter project. To get customers to be early and continu-
ous supporters of the project, GWP had to educate and inform
them of the benefi ts of the technology and how they, specifi -
cally, would benefi t from it.
Explaining complicated subject matter such as the smart
grid is not an easy thing to do. Customers wondered why GWP
needed to modernize the infrastructure; in their minds, every-
thing was working just fi ne. GWP’s fi rst task was to let custom-
ers know and understand how the utility had not kept pace
with the electric and water industry, and that keeping up with
the times was crucial. GWP’s aging infrastructure had not
One of the key elements of the smart grid is this smart meter.“Coffee in the Park” is one of the GWP customer outreach eventsheld to communicate smart grid benefi ts.
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54 April 20122 | www.tdworld.com
CUSTOMEREngagement
changed much in the last 100 years.
It was time to implement change
and start showing the benefi ts.
Having learned from the mis-
communication mistakes of inves-
tor-owned utilities, GWP did not
want to make those same mistakes;
it wanted customers on board from
the get-go. From the beginning,
GWP reached out to customers
through town hall meetings and
direct-mail pieces. The local media
also were engaged to cover the proj-
ect so as to inform and educate cus-
tomers of what was coming and how
the smart meters and smart grid
would benefi t them.
Every project milestone was pub-
licized. Prior to installations, cus-
tomers received a letter about the
coming installation and why it was necessary. They received
brochures and bill inserts on frequently asked questions. GWP
gave the city council and commission frequent project status up-
dates. The utility also created a stakeholder advisory committee
made up of city residents and business owners who met with the
utility on a monthly basis and shared their insight and informa-
tion on the project, and provided input on outreach materials.
All customer outreach, including the utility’s external news-
letters, website and social media sites, had a special section
devoted to this project with progress constantly being high-
lighted. GWP also attended every community event sponsored
by the city, distributing smart grid educational materials and
Smart meter installation is a “process step” that is preceded by considerable customer outreachactivities.
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CUSTOMEREngagement
answering questions. The utility hosted “Coffee in the Park”
events on Saturdays and Sundays for six months and invited
customers to come and discuss the project and its benefi ts.
The purpose was to go to the customers to engage and edu-
cate them on the new technology.
Smart Grid Maturity ModelGlendale Water & Power’s (GWP’s) smart grid meter project received the highest customer score of all smaller utilities and
among the highest customer scores of all 93 utilities that responded to the Smart Grid Maturity Model (SGMM) survey. The survey
was facilitated by the California Energy Commission’s Public Interest Energy Research division, through a project called Defi ning
the Pathway to California’s 2020 Smart Grid for Publicly Owned Utilities.
According to the survey’s fi ndings, Glendale achieved the highest maturity level of all utilities surveyed in the areas of strategy,
management and regulatory, and organization and structure. GWP’s smart grid maturity level is more advanced than most other
utilities, and it is a pioneer in developing a corporate-level smart grid strategy. The utility’s overall strategy focuses strongly on its
customers. These results stem from GWP having laid down a strong foundation for the smart grid project.
The SGMM is a management tool that helps utilities plan smart grid implementation, prioritize options and measure progress.
Developed by utilities for utilities, the model is hosted by the Software Engineering Institute as a resource for industry transforma-
tion with the support of the U.S. Department of Energy and input from a broad array of stakeholders.
The SGMM measures utilities in eight domains from strategy implementation to societal and environmental responsibility.
GWP scored the highest maturity level of 5 for breaking new ground and having an industry-leading innovation in the strategy
and organizational structure of its smart grid project — two of the most important domains that will ensure a successful project
down the line.
As utilities are underway to modernize their electric grids, they have to strike an appropriate balance between all the hype and
the real progress they are making. Findings from the SGMM and Software Engineering Institute can help utilities to determine
their progress and where to focus their efforts to achieve their goals.
Extensive outreach is a defi nite must for any utility pursu-
ing a smart grid project, because keeping customers in the
know, along with giving them information and progress up-
dates, will help them eventually adopt and adapt to the new
technology, and the many changes it will bring them.
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58 April 20122 | www.tdworld.com
CUSTOMEREngagement
A Frame Up
With all of the smart meters now installed and functioning
properly, and the data making its way in, customers need to
be given the options about how to see their usage. Plus, they
need to know how to use the information their new smart me-
ters are providing to help them make wiser energy and water
choices.
Glendale is entering the second phase of its smart grid proj-
ect, which consists of customer-facing programs.
The utility is looking into expanding its thermal
storage program through a partnership with Ice
Energy, future pricing plans, in-home devices and
demand-response programs. Giving this power to
customers is one of the most beneficial parts of a
smart grid system.
Interestingly, an important part of this proj-
ect came together by chance for GWP when a
company approached the utility. At a 2009 con-
ference, CEIVA, a digital-frame producer whose
CEO lived in Glendale and worked in Burbank, a
neighboring city, asked if its digital frame could
work with the smart meters to display usage in-
formation inside the home. This was not just any
regular digital frame. The frame stores pictures
in a cloud and people upload pictures to the
frame through a pin number or the Internet. The
frame displays the stored pictures.
GWP and CEIVA worked together on installing a ZigBee
chip in the frame. GWP is currently piloting the frame with
about 50 customers. The frame connects to the smart meter
using the ZigBee chip and displays the customer’s electric and
water usage in near real time. GWP owns five channels out
of the 40 on the frame. The five different channels display
energy and water usage, information on GWP programs and
Communications is the underpinning of the smart grid.
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60 April 20122 | www.tdworld.com
CUSTOMEREngagement
services, and a city of Glendale channel. The rest
of the channels are private customer pictures. Af-
ter the pilot, GWP plans to provide frames to all
customers.
Energy Reporting
GWP also has been piloting Opower’s home
energy reports with 25,000 customers. These re-
ports include a summary of the customer’s home
energy usage compared to 100 random homes of
the same size within a 2-mile (3.2-km) radius. The
report ranks customers on their energy usage and
provides information on energy usage over the last
two months in graphs so customers see their daily
average and when they used the most energy. On
the back of each report are customized tips to help
customers save energy.
GWP recently expanded this program to cover
all customers except those who are on medical
equipment discounts. The reports now incorporate
smart meter data and give customers a more detailed view of
their energy usage, still ranking them and comparing them to
100 random homes of the same size.
Customers also are given access to the Opower home en-
ergy report website, where they can go online and see a near-
real-time energy comparison, drill down to charts with their
energy usage and calculate their next utility bill.
In early 2012, Opower partnered with the Natural Resourc-
es Defense Council and Facebook to produce a new social me-
dia application customers can join and upload their energy
report information and ranking, and create communities to
help each other save more by using all the information on
their Opower report. GWP and four other
utilities across the nation are piloting this
program.
Thermal Energy Storage
In the last few years, GWP has part-
nered with Ice Energy to launch the
nation’s fi rst cost-effective, utility-scale
distributed energy storage project install-
ing Ice Bear units. This project, along
with other smart grid projects, will help
GWP to continue delivering reliable,
competitively priced electric service in a
sustainable and environmentally friendly
manner.
The Ice Bear reduces the energy used
to cool a building during peak (after-
noon) periods. Currently, GWP offers this
program to all commercial customers at
no cost to building owners. This technol-
ogy works with existing air conditioners
and reduces the energy to cool buildings
by 5% or more over the life of the unit.
Additional benefi ts of this technology
are the reduction of carbon fuel use and
greenhouse-gas emissions. It also pro-
vides cooler air to a building than tradi-
tional air conditioners, helping building
tenants to control their cost and improve
their work environment.
GWP employees receive training on Tropos GridCom system.
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62 April 20122 | www.tdworld.com
CUSTOMEREngagement
The Ice Bear is a proven piece of equipment similar in size
and appearance to a building’s existing heating, ventilation
and air conditioning (HVAC) system. When connected to the
HVAC system, the Ice Bear creates and stores ice at night with
an off-peak rate and efficiently delivers that cooling the next
day using the same duct work and fan of the current HVAC sys-
tem. The building is cooled exactly as before but without run-
ning the HVAC system’s compressor during more expensive
and environmentally damaging peak daytime hours. GWP has
installed 163 Ice Bears in Glendale and hopes to install 1,000
more as the smart grid project progresses.
The Future
GWP is now looking at an overhaul of all its systems. It is
documenting existing system architectures and will propose
a road map to achieve the desired endpoint. Software for dis-
tribution automation will be selected as part of this process.
Distribution automation will take the longest amount of time
to complete.
The foremost result of moving toward the smart grid is to
give customers new tools to better manage their energy and
water use, and make informed choices that would not have
been possible with traditional meters. Through future in-
home displays and the Internet portal, customers will have ac-
cess to their usage to help them conserve and participate in
different pricing plans that better fit their lifestyles.
Meter reading will be done remotely, and outages and
service problems will be pinpointed much faster, allowing
quicker service restoration. There are already early examples
of how this modernized grid benefits customers. And there
will be many more examples as deployments progress.
Glenn Steiger ([email protected]) is general manager r
and CEO of Glendale Water & Power (GWP). Under his
leadership, GWP was the first utility in the nation to receive
U.S. Department of Energy stimulus funding for its smart grid
initiative and has achieved one of the highest percentages of
renewable power within California. He currently serves on the
Board of Public Power Inc. (an APPA subsidiary), is president of
the Southern California Public Power Authority and is a board
member of the Western Electric Coordinating Council.
Companies mentioned:
California Energy Commission | www.energy.ca.gov
CEIVA | www.ceiva.com
Glendale Water & Power
www.glendalewaterandpower.com
Ice Energy | www.ice-energy.com
Natural Resources Defense Council | www.nrdc.org
Opower | www.opower.com
Software Engineering Institute | www.sei.cmu.edu
ZigBee | www.zigbee.org
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64 April 20122 | www.tdworld.com
STATIONStructures
Bus Bar InnovationTranspower New Zealand designs, tests and commissions a new under-hung substation bus bar system.By Andrew Renton, Transpower New Zealand Ltd
In 2005, Transpower New Zealand, the transmission sys-
tem operator and owner of the New Zealand national
grid, was faced with the need to expand a site-restricted
220-kV substation while improving access and reducing
cost. The design had to meet several requirements:
M Improve maintenance access to installed equipment
M Reduce the site’s visual impact
M Use standard air-insulated switchgear (AIS) transmission
line and substation hardware
M Comply with seismic and electrical clearance design
standards
M Reduce construction and maintenance costs
M Lower the risk of failure
M Reduce type and number of components and hardware.
In addition to complying with the transmission system op-
erator’s (TSO’s) design standards for electrical, mechanical
and environmental parameters, detailed consideration was
given to alternative switchyard bus bar configurations. This
has resulted in the development, testing and approval of a bus
bar configuration that satisfies all the design criteria while
offering improved access to equipment and a reduction in
costs.
Existing Design Standards
Traditionally, Transpower would use one of two 220-kV
bus bar configurations. First is the rigid-rigid configuration.
In this configuration, a rigid main bus is above and at a right
angle to a rigid transverse bus. The buses are comprised of
tubular aluminum bus bars supported by post insulators on
individual steel posts with concrete-pad foundations. Jumpers
of flexible stranded conductors with compression fittings are
used for the bolted connections between the bus sections and
from the bus sections to the switchgear. Second is the rigid-
flexible configuration. This configuration is similar to the first
configuration with its rigid main bus except it uses stranded
aluminum conductors supported on ground-mounted post
insulators instead of a rigid transverse bus bar.
New Bus Bar Design
To improve access and reduce costs, Transpower opted to
remove the steel posts supporting the flexible transverse bus
sections, leaving the conductor to be supported by phase-to-
phase insulators suspended from the main bus bar.
Although this new rigid-flexible design with suspended
phase-to-phase insulation satisfied all the design criteria,
Transpower had to conduct further detailed design checks to
ensure all short-circuit and seismic forces could be accommo-
dated. Due to time pressure on the original project, this work
could not be completed so a separate project was established.
Research and development undertaken by Transpower and
its engineering partner Electropar, a subsidiary of Preformed
Line Products, subsequently revealed no similar bus designs
The completed high-voltage under-hung bus bar system provides improved access while reducing cost, time and visual impacts without affect-ing safety or system performance.
67www.tdworld.comm | April 2012
STATIONStructures
were commonly used at transmission
voltages. The determination was that,
with suitable selection of components,
it should be successful.
Component Selection
To reduce the need for specialized
components and hardware, and to min-
imize costs, a 200-mm (7.9-inch)-diam-
eter, 6-mm (0.24-inch)-wall-thickness
standard tubular main bus was selected
with current and fault ratings of 4,500 A
and 200 kA per 3 sec, respectively.
Based on a unit cost of NZ$150/m
(US$105/m), the tubular bus was 50%
more expensive than the normal 140-
mm (5.5-inch) bus at NZ$100/m (US$70
m). However, as the length of the bus
bar required was considerably reduced,
this design feature produced a savings
of approximately 30%.
The acceptable current and fault rat-
ings of an all-aluminum conductor are
the main reasons Transpower selected this conductor for the
transverse bus. The conductor has a fault rating of 36.2 kA per
3 sec, and normal and emergency current ratings of 1,290 A
and 1,550 A, respectively.
Conductor Deflection
The static deflection of the 200-mm main bus was
31 mm (1.2 inches) before the insulators were added. The
400-kV composite insulators, complete with grading rings,
each weigh approximately 46 kg (101
lb). This increased the mid-span deflec-
tion over a 13-m (43-ft) span to some 60
mm (2.4 inches), a value comparable to
the existing design standards. The pro-
posed use of the stranded-conductor
transverse bus suspended from the main
bus by composite insulators was checked
to ensure the phase-to-phase and phase-
to-earth clearances during a short circuit
would not be compromised.
A Business Case
A multi-staged business case consid-
ering the advantages and disadvantages,
cost and benefits was undertaken to jus-
tify further investment in the detailed
design and testing required to turn the
concept of the new bus bar configuration
into reality.
The three disadvantages identified
were the perceived risk in using phase-
to-phase insulation within substations
and on bus bars; the replacement of
composite insulators up to 25 years ear-
lier than ceramic insulators; and the use
of a heavier main bus and supports.
The greatest safety hazard was the in-
crease in the perceived risk of a bus bar
Bus Bar Design Standards
Electrical ratings and requirements
Nominal operating voltage 220 kV
Maximum operating voltage 245 kV
Lightning impulse withstand level 1,050 kV
Maximum operating current 4,500 A
Fault currents and duration 25 kA, 31.5 kA and 40 kA per 3 sec
Environmental characteristics
Maximum ambient temperature 30°C (86°F)
Maximum continuous conductor temperature 80°C (176°F)
Maximum short time conductor temperature 250°C (482°F)
Minimum wind velocity 0.6 m per sec (2 ft per sec)
Relative conductor emissivity 0.5
Pollution level Heavy/very heavy
Minimum creep distance 25 mm per kV (0.99 inch per kV)
Seismic loads Australian/New Zealand standard 1170 and IEEE 693
Electrical clearances, spacings and distances
Minimum distance phase-to-phase and phase-to-earth 2,100 mm (83 inches)
Minimum height live conductors to ground level 4,540 mm (179 inches)
Minimum vertical maintenance distance 4,600 mm (181 inches)
Minimum horizontal maintenance distance 3,600 mm (142 inches)
Minimum bus bar height above ground level 5,540 mm (218 inches)
Minimum rigid bus bar center line spacing 3,600 mm (142 Inches)
Minimum vehicle bus bar approach distance 4,600 mm (181 inches)
Minimum vehicle height 3,400 mm (134 inches)
An example of prior construction using a rigid main bus and flexible transverse bus both mount-ed on post insulators with steel supports.
STATIONStructures
fault due to failure of the phase-to-phase insulation. However,
as bus bar protection schemes quickly remove a fault, the risk
was considered less onerous than a close-in transmission line
fault fitted with auto-reclose equipment.
There are several significant advantages of adopting phase-
to-phase insulation:
M�Reduction in site footprint by 15% to 25%
M�Use of standard substation and trans-
mission line components
M�No compromise of industry’s standards
on clearances and equipment spacing
M�Improved access for maintenance due
to fewer constructions
M�Reduction in the visual impact through
fewer structures
M�Improvement in system reliability and
maintenance through reduction in the num-
ber of components
M�Reduction in construction times and
substation cost.
Cost Comparison
The new design incorporates larger main
bus bars and supporting structures, but the
increased cost is more than offset by the sav-
ings accrued from the reduction in struc-
tures, foundations, insulators and ancillary fittings as well as
the reduced civil, mechanical and electrical site labor costs.
Conservative estimates of the savings attributable to the use
of the proposed design base indicate a savings of approximate-
ly NZ$30,000 (US$21,000) per switchgear bay. This savings is
likely to be closer to NZ$100,000 (US$70,00) if the reduced
site area savings, such as land purchased, civil works and ca-
Tests on HVUBS bus ensure that phase-to-phase and phase-to-earth clearances are notcompromised and under-hung phase-to-phase insulator mechanical loads are not exceed-ed at short-circuit currents up to 63 kA.
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© 2012 by the Edison Electric Institute. All rights reserved.
70 April 20122 | www.tdworld.com
STATIONStructures
bling, are taken into consideration.
In early 2008, having successfully
presented the commercial and op-
erational case, approval was granted
to proceed with the first stage of the
design and testing program.
Design and Testing Program
The new design known as the
high-voltage under-hung bus bar
system (HVUBS) comprised stan-
dard Transpower and Electropar
components, including the bus
work, clamps, fittings insulators,
structures and foundations. As a
new design, it was vitally important
to ensure the electrical and me-
chanical properties were adequate.
Electropar subcontracted design
consultant Beca to undertake the
static analysis of each component to
ensure the HVUBS met all service conditions, such as short-
circuit, seismic, wind and snow load events.
On completion of this analysis, Beca arranged a third-party
review of the results using AECOM and TransGrid, the TSO
for New South Wales, Australia, to validate the design concept.
The full-scale testing program had two main objectives:
M To ensure the structural integrity of the components,
especially the composite phase-to-phase insulator
M To confirm the electrical performance and safety clear-
ances were not compromised.
Bus configuration cost comparison, traditional versus HVUBS with and without transverse bus switchgear connections
0
20,000
40,000
60,000
80,000
100,000
120,000
Rigid/
rigid
post
Rigid/
flexible
post
Rigid/
flexible
under-hung
Main/transverse bus configurations and support
New
Zeala
nd
do
llars
Foundations
Insualtors
Support posts
Buswork and conductors
Rigid/
rigid
post
Rigid/
flexible
post
Rigid/
flexible
under-hung
No switchgear connected
to bus bar
Old
Old
NewNew
Switchgear connected
to both sides of bus bar
72 April 20122 | www.tdworld.com
STATIONStructures
The global availability of commercial high current test
laboratories able to fulfill the fault current tests and accom-
modate a 15-m by 15-m by 10-m (49-ft by 49-ft by 33- ft) test
rig was very limited. In June 2009, the Powertech Laboratory
in Canada was selected for testing and it arranged for local
contractor Mott Electric to construct standard Transpower
foundations, and erect the support structures and bus work at
the test laboratory.
The combined Electropar-Transpower-Mott Electric team
was responsible for installing the HVUBS in the laboratory.
Then Powertech was able to complete the comprehensive test
program during a period of five days with fault levels up to
63 kA. The data analysis confirmed the proposed design was
feasible and none of the structural or electrical design limits
were exceeded.
The HVUBS has been deployed at a new 220-kV breaker
and a half station, Drury, near Auckland and is presently be-
ing installed at another new 220-kV station, Pakuranga. Drury
has been in service for almost a year, with
the benefits of the new system accruing as
expected. The most favorable benefit be-
ing the additional openness and space it
affords within the switchyard for mainte-
nance. The system also is designed to be in-
stalled at 110 kV at a new switching station
that makes use of disconnecting circuit
breakers as another step to remove equip-
ment and reduce cost while improving ac-
cess and safety. The redevelopment of the
existing110-kV Karapiro Substation will be
the first brownfield installation where the
HVUBS will enable older sites to achieve
the same increased safety and maintenance
distances of new sites while removing lega-
cy equipment and design constraints.
The design, development, testing and
in-service deployment of the HVUBS has
shown it does not compromise either phase-
to-phase or phase-to-earth clearances, it
meets all the load cases, and it delivers net
financial, safety, maintenance and environ-
mental benefits.
Ready for Use
Transpower gained a significant amount
of intellectual property and knowledge
about the process and system, and is
happy to share this with other TSOs. Al-
though the use of phase-to-phase insula-
tion is not new, this particular applica-
tion relied on a combination of modern
materials and analysis tools, with the ul-
timate success of the project due, in no
small part, to the dedicated efforts of a team
assembled from across the globe.
Andrew Renton ([email protected]) is a
qualified electrical engineer with more than 24 years experi-
ence working for transmission and distribution utilities and
government agencies in New Zealand and Australia. Presently,
Renton manages a team of substation, overhead line and cable
professionals as Transpower’s asset development engineering
manager.
Companies mentioned:
AECOM | www.aecom.com
Beca | www.beca
Electropar |r www.electropar.co.nz
Mott Electric |c www.mottelectric.com
Powertech Laboratory |y www.powertechlabs.com
Preformed Line Products | www.preformed.com
TransGrid | www.transgrid.com.au
Transpower |r www.transpower.co.nz
Photo of HVUBS in 220-kV Drury Substation shows rigid main bus on post insulators with under-hung composite insulators supporting flexible transverse bus.
Fundamental Change7KLV�IXQGDPHQWDO�FKDQJH�LQ�KRZ�WR�WKLQN�RI�SRZHU�UHTXLUHV�D�VLJQL¿FDQW�FKDQJH�
in how power distribution grids are designed and how they are operated. The
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transforming their ageing power grids into state of the art smart grids. The
digitalization of the existing power equipment allows the power companies
to prepare for a new power distribution future with more alternative energy
sources as well as different load patterns from electrical vehiclessources as well as different load patterns from electrical vehicles.
The DISCOS®�6\VWHP�IURP�3RZHU6HQVH�LV�D�PRGXODU�DQG�UHWUR¿WWDEOH�V\VWHP�IRU�VXSHUYLVLRQ�RI�WKH�SRZHU�GLVWULEXWLRQ�QHWZRUN��
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able to get control over your grid and make it smart!
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Reusable Power DistributionAgeing assets and a greater array of renewable energy sources are pushing power distribution companies to digitalize their infrastructure through smart grid technology.
sensethepower.com
74 April 20122 | www.tdworld.com
DISTRIBUTIONManagement
NV Energy Signals
Demand ReductionsA decade of demand-response growth has generated benefi ts and created new challenges.By Victor Garman, NV Energy
Las Vegas, Nevada, has a well-deserved reputation
as the embodiment of excess consumption, from its
myriad buffets to its lavish pool parties. Las Vegas
also is gaining a reputation for shaping how and when
energy is consumed through its innovative use of demand
response (DR). The large-scale deployment of DR has brought
operational challenges to NV Energy, the investor-owned
utility that serves the Las Vegas valley. NV Energy has met
these challenges with practical, repeatable solutions.
Thanks to DR, NV Energy has the ability to reliably reduce
more than 140 MW of residential and small commercial air
conditioner load. There are more than 70,000 air conditioners
in the Las Vegas valley at more than 50,000 homes of custom-
ers who are currently participating in a voluntary DR program.
When the outdoor temperature rises to between 104°F and
108°F (40°C and 42.2°C), a pager signal can be sent to some or
all of the 70,000 air conditioners. Once signaled, the air con-
ditioners increase their setback by 4°F (2.2C°), causing them
to ramp down consumption, thus dropping the system load by
more than 140 MW. When called upon, these DR curtailments
produce measurable, consistent reductions in demand on the
distribution system.
The Challenges
NV Energy did not grow to 140 MW of DR overnight.
NV Energy has been growing its base of participants in its air
conditioning load-management program for nearly 10 years.
As a consequence, the utility manages a portfolio of DR con-
trol devices from a cross-selection of vendors (for example,
Carrier, Honeywell and so forth). Each vendor has its own pro-
prietary software headend, which resides in a corporate data
20 MW5,120 MW
5,000 MW
4 p.m. 6 p.m.
5,254
5,282
5,082
4,982
4,882
4,782
4,682
4,582
Time
Dem
and
(M
W)
All air conditioners simultaneously curtailed for an emergency at 4 p.m.Within a few minutes, 120 MW of consumption were shed and stayedoffl ine until 6 p.m.
76 April 20122 | www.tdworld.com
DISTRIBUTIONManagement
center or on the cloud and communicates to the DR device
using the manufacturer-specific language of the device.
Keeping the data in each software headend updated is a
challenge. For example, when a customer leaves a DR program,
it is critical to update the software headend to stop sending
dispatch signals to curtail consumption to the customer’s DR
device. The data can be updated manually through a graphi-
cal user interface within the software
headend, or it can be updated automati-
cally using a software interface. However,
updating the data manually is costly from
a labor perspective and error-prone.
A second challenge to maintaining a
portfolio of DR devices is managing the
wireless communications systems used to
signal the curtailment. DR devices can-
not be dispatched if the communications
system is malfunctioning or unavailable.
Communication with stand-alone ther-
mostats and load-control switches is done
through a pager network. Home area net-
work (HAN)-based DR devices, such as in-
home displays (IHDs), are controlled over
the Internet. There are plans to commu-
nicate with IHDs using the meter network
later in 2012. All of these communications
systems experience a diversity of issues that must be monitored
and managed for the dispatch signal to be sent out and, more
importantly, received whenever needed.
A third challenge related to DR device portfolio manage-
ment is losing communication between devices in the HAN.
Obviously, this challenge is unique to DR control through
a HAN and is not relevant to the stand-alone thermostat or
CSE
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Cannon/
Yukon
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Comverge
LMS
Carrier
LMS
CSE
one-way
switch
Cannon
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switch
Comverge
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switch
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NV
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Each device vendor has a proprietary load-management system and communicates over adifferent communications medium.
Join SEL for the
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78 April 20122 | www.tdworld.com
DISTRIBUTIONManagement
load-control switch. For example, a meter can stop commu-
nicating with an IHD, thus causing the IHD to stop function-
ing correctly. The IHD also can lose connectivity with other
HAN devices, such as a thermostat or lighting control. When
this happens, the functionality of the device can be reduced in
some way. For example, when disconnected from the IHD, the
thermostat may lose the ability to change program set points.
This challenge is important to manage from a customer’s per-
spective. Consequently, the connectivity between devices in
the HAN must be actively monitored and managed.
A fourth and final challenge related to DR device portfolio
management is reporting. NV Energy has significant report-
ing requirements both to manage the operations of DR pro-
grams as well as program oversight. For example, NV Energy
is required to periodically report data to the Public Utilities
Commission of Nevada regarding the cost-effectiveness and
efficacy of its DR programs. To show that building DR capacity
is more cost-effective than building a peaker plant, data must
be assembled and processed from many disparate systems. Ag-
gregating and providing operational and regulatory reports
from many different systems is a challenge.
Operator Confidence
A DR resource does not have value if it cannot be reliably
dispatched. To be dispatched as a reliable resource, DR must
meet the challenge of developing confidence in system or grid
operators. Operators must have confidence the DR resource
will behave as forecasted. To create and maintain operator
confidence, an accurate forecast must be available each day for
every dispatch algorithm so the operator knows exactly how
the DR resource will impact the system load.
A dispatch algorithm might be, for example, to dispatch all
air conditioners at 4 p.m. and bring them all back to normal at
6 p.m. An alternative dispatch algorithm would be to dispatch
a subset of the air conditioners at 3:30 p.m., another subset at
4 p.m. and so on. These different dispatch algorithms produce
different load shapes on the system grid and each algorithm
has a different cost per megawatt-hour.
An in-home display shows energy consumption from an AMI meter,An in home display shows energy consumption from an AMI meterwhich is updated several times per minute, and also displays the current of electricity per hour and indoor/outdoor temperature (left). The pro-grammable thermostat (right) communicates wirelessly to the in-homedisplay using ZigBee HAN.
79www.tdworld.comm | April 2012
DISTRIBUTIONManagement
A second element of providing operator confi dence is a real-
time feedback loop that a DR resource is reducing demand as
expected. Unfortunately, most metering systems transmit data
too slowly to be used to provide near-real-time feedback. This
feedback can be provided using supervisory control and data
acquisition (SCADA) because this is collected fast enough; the
data updates every 1 sec to 60 sec, providing near-real-time
feedback.
The Customer Side
DR programs also introduce customer service and fi eld ser-
vice challenges. NV Energy customer service representatives
(CSRs) are trained to enroll a customer in a DR program or
to assist with other DR customer service inquiries. Customers
may call CSRs regarding the operation of their devices, DR
program rules or the dispatch of fi eld services staff for repairs.
Tracking notes for each customer interaction is a challenge, as
is managing customer service request queues, such as schedul-
ing a repair service request with a customer.
Once a customer enrolls in a DR program, a fi eld services
vendor, managed by NV Energy, installs an IHD and a pro-
grammable communicating thermostat (PCT) at the custom-
er premise, confi gures the IHD and PCT based on customer
preferences and demonstrates basic device usage. Assigning
and tracking fi eld work, or work orders, is a signifi cant chal-
lenge further complicated by the fact NV Energy uses multiple
fi eld services companies. One such complication is that NV
Energy must have processes in place to assign fi eld services
work to the least-cost, highest-quality company that has avail-
ability matching the customer’s availability.
The Solution
The solution to many of these operational challenges can
be provided by change management and appropriate software.
After a careful review of existing in-house systems, NV Energy
published a request for proposal in late 2009 to purchase soft-
ware that would meet these requirements. There were no solu-
tions on the market that met the requirements out of the box.
However, UISOL, now part of Alstom, had a software prod-
uct developed for the wholesale energy market (usually inde-
pendent system operators and other power pool entities) that
had similar features needed by NV Energy. So, NV Energy
partnered with UISOL to implement a commercial product
for the retail utility market. That product is called the De-
mand Response Management System (DRMS) by NV Energy
and branded as DRBizNet by UISOL. The product was imple-
mented using funds from a smart grid investment grant that
was part of the American Recovery and Reinvestment Act of
2009.
The DRMS reduces the impact of the challenges previously
described. Specifi cally, the DRMS integrates with software
headends to keep data synchronized between systems, monitor
DR communications and provide reports. It provides forecasts
and near-real-time displays to system operators. The DRMS
also manages the activities of the DR CSRs and fi eld service
contractors using service request queues and work orders.
The fi rst production release of the DRMS was in October
2011. Being a prudent utility, NV Energy fi rst released the
DRMS to a limited audience of employees. The limited release
is now about to be expanded to include a few hundred custom-
ers. If that goes as expected, plans are to install up to 3,000
new devices per month throughout the rest of 2012.
An Exciting Time
NV Energy’s leadership in the DR market will continue to
push the frontiers of what is feasible. In 2011, NV Energy was
able to reduce its system operating reserve requirements be-
cause of DR. Going forward, the utility expects to improve the
value of DR by optimizing dispatch algorithms, paying market-
based incentives and expanding the footprint of devices that
can participate in DR curtailments to include pool pumps,
variable-speed motors, batteries, lighting controls, smart ap-
pliances and the like.
Many other utilities are now interested in DR because of
the infl ux of smart grid projects. It is an exciting time to be in
the DR fi eld.
Victor “Tor” Garman ([email protected]) is a project
manager at NV Energy with a focus in demand response and
distributed energy. He has worked in the utility industry for
seven years and is a certifi ed energy manager. Garman received
a bachelor’s degree in mathematics and computer science from
Vanderbilt University’s school of engineering in 1996.
Editor’s note: This material is based upon work supported
by the Department of Energy under Award Number DE-
OE0000205.
3:30 p.m.
4,600
4,560
4,500
4,460
4,400
4,360
4,300
4,260
4,200
4,160
6:30 p.m.
Time
Dem
and (
MW
)
75 MW
Air conditioners were dispatched in three groups — 3:30 p.m. to 5:30 p.m., 4 p.m. to 6 p.m. and 4:30 p.m. to 6:30 p.m. — to avoid paying peak energy prices.
Companies mentioned:
Carrier | www.carrier.com
Honeywell | www.honeywell.com
NV Energy | www.nvenergy.com
Public Utilities of Nevada | pucweb1.state.nv.us/pucn
Uility Integration Solutions | www.uisol.com
BOOKS
Book Smart Just Got Smarter.New! Introducing Transmission & Distribution World�ERRNV��1RZ�\RX�FDQ�À�QG�ERRNV�with the very latest Power Utility information and make your purchase online.
Get books on systems, engineering and Code. Shop for handbooks on bushings, monitoring systems and transformers.
You’re just a click away from TDW’s comprehensive book store. Visit BuyPenton.com. Click on the Electrical Systems, Energy & Construction link.
Read on.
ELECTRIC UTILITY OPERATIONSLife Line 80D | Safety Talk 80F | Live-Line Work 80L | Acoustic Emission Testing 80P
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2012
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80D April 20122 | www.tdworld.com
ELECTRIC UTILITY OPERATIONSELECTRIC UTILITY OPERATIONS
LIFELine
M Born in Sidney, Nebraska.
M Married to Tina for 15 years and has a 13-year-old son, Sam.
M Enjoys golfing, fishing, doing outside activities and spending
time with his family.
M His favorite boss is his current supervisor, Dave Clark at Xcel
Energy in Boulder, Colorado. Dave was a lineman at one time,
and as long as he does his job, he treats him like gold.
M Can’t live without his rubber gloves, hard hat, safety glasses
and hot sticks.
M Describes himself as hard working, very safe and outgoing.
His coworkers call him “The Governor,” because he likes people
and knows just about everyone.
Early Years When I was a little kid, I saw linemen climbing poles, and
I decided that I wanted to pursue line work for a living. In
1973, I had the opportunity to work as a ground apprentice for
Highland Electric Cooperative in Sterling, Colorado. In this
position, I framed and set poles, performed overhead work
and did a lot of climbing.
After three years, I went to work for Intermountain Rural
Electric in Sedalia, Colorado. I worked for the company for
six years before making journeyman in 1979. In 1983, I began
working for Longmont Power and Communications in Long-
mont, Colorado. I served as a lineman until 1994, and then
I was promoted to foreman and eventually to crew leader. I
worked for that company for 26 years before I retired.
My wife told me that I couldn’t retire before her, so I then
went to work for Xcel Energy in 2008 as a journeyman line-
man, and I’ve been with the company ever since.
Day in the LifeMy work day starts at 7 a.m. at the Boulder service center.
During an informational meeting, my three-man crew gets
orders to do service upgrades, pole changes or underground
splicing for cable repairs. During our workday, we serve the
mountains, hills and plains within Xcel’s service territory.
One of my favorite things about working as a lineman for
Xcel Energy is that every day is different. For example, right
now, we are replacing some 1950s-era wood poles that were
broken in 80-mph to 90-mph winds.
While I’ve done a lot of interesting projects for Xcel over
the last few years, one of my most memorable jobs was back in
2010. My crew built a double-circuit 795 wire and dedicated
feeder circuit for the University of Colorado in Boulder. It
was a lot of hard work, but because it was team effort, it went
together really well. We were on the project for three or four
months, and we reframed the poles, strung large wires and
energized a circuit.
Safety LessonWhen I worked for the Rural Electric Association, we had
a tailboard before starting our work for the day. During this
meeting, we were instructed to stay out of the primary. Un-
fortunately, one of our coworkers got into the primary, was
burned, and then fell off the 40-ft pole and on to a chain link
fence. We performed CPR and he survived, but he had to go
through a lot of rehabilitation due to a brain injury.
After that accident, I learned the importance of never tak-
ing shortcuts. You always have tomorrow to do the job. Also,
when you’re a lineman, you can’t bring any of your troubles
from home to the job site. You need to keep your mind on the
job, and if something doesn’t feel right, then you just shouldn’t
do it. There’s no looking back if you have an accident.
Memorable StormA storm that I’ll never forget was a tornado in Windsor, Col-
orado. All the crews came in from Denver, Colorado. When
we arrived, we would see one house standing and another one
down on the ground. It was incredible that there weren’t any
fatalities. There were a lot of distribution lines down, and it
took a team effort to get everything back up in the air. We were
there for 10 days.
Challenges and RewardsI think the biggest reward of being a lineman is working
with great coworkers and trying to learn something new every
day. In my opinion, the most challenging aspect of this job is
working in 80-mph winds. It’s tough to get our customers back
on when we have the large feeder poles down.
Plans for the FutureIf I had a choice, I would definitely go into the power indus-
try all over again. I wouldn’t change a thing about my career
choice. It’s rewarding to get people’s lights back on. As long
as I stay healthy, I want to retire at 65, stay in touch with the
trade, and then maybe work for an inspection company for
utilities.
Randy ZaleskyXcel Energy
Xcel Energy’s Randy Zalesky replaces a pole that was broken during a recent storm.
briefing. Through advanced planning, we can keep our crews
safe in the field by preventing any unnecessary incidents or
injuries.
3. Wear rubber gloves and ground lines. Not too long ago, “the
right thing to do” was to de-energize a 12-kV or 4-kV line, then
work it as dead with no rubber gloves or grounds. It was a firm
shade of gray, and many distribution line workers chose this
path. Instead, linemen should take care to wear their personal
protective equipment at all times.
4. Report near-misses. When working storms, most utilities
schedule morning briefing sessions with their crews before
they go out into the field. They discuss the number of outages,
their goals for the day and near-misses. And, in storm work, ev-
eryone shares, because hazards are extreme and no one wants
anyone to get injured. But when the storm is over, our line
workers will return to their routine. Oftentimes, the linemen
are reluctant to share the near-misses.
Field superintendents and crew leaders should make every
morning like a storm report. Take five minutes to pull crews
together to review the day, discuss any changing conditions,
identify goals for the day and ask for near-miss reports.
Remember, there is a difference between “safety is the right
thing to do” and simply doing the right thing. In our business,
it can mean the difference between life and serious injury or
death. To keep you and your crews safe, try to always do the
right thing, follow the rules, wear rubber gloves and ground
lines, plan your work and report near-misses. While productiv-
ity is important, safety should always come first.
SAFETYTalk
ELECTRIC UTILITY OPERATIONS
By Matt Forck, SafeStrat
Matt Forck ([email protected]), a certified safety profession-
al, worked as a meter reader and journeyman lineman, and was
a member of his utility’s safety staff. Today, as the president of
SafeStrat, short for Safety Strategies, he speaks and consults
on utility safety. Learn more at www.safestrat.com.
Many utility leaders have adopted the slogan:
“Safety is the right thing to do.” I believed firmly
in this slogan until a serious incident made me
reconsider this approach.
A three-person line crew was working to change out a cross-
arm on a three-phase 12-kV circuit. One of the linemen got
too high and put his shoulder in the middle phase as he was
moving the neutral. Unfortunately, he wasn’t wearing rubber
gloves, and the middle phase wasn’t adequately covered. His
injuries were serious and significant, but lucky for him and his
family, he survived.
If you asked his crew members, they would tell you that they
were absolutely doing “the right thing.” On this job, the work
needed to be done quickly because the crew was working over-
time to restore power to customers. They cut major corners
by failing to follow even the most basic of rules, but they were
trying to do the right thing by working rapidly.
After this event, I drew a new conclusion: I discovered that
safety is not simply the right thing to do, but rather, safety is
doing the right thing. In transmission and distribution work,
this is usually cut and dry. It’s measured by rules, planning,
actions, hazard evaluations, energy source controls and more.
Below are four areas where safety is doing the right thing.
1. Follow all rules. In the spring of 2003, I was doing a safety
audit on a seven-person line crew. I noticed that the linemen
were taking some risks, so I stopped the job. I called everyone
together and told the crew they needed to change the way
they were performing a certain task. I was told that they didn’t
need to change because they were doing the work the way
they had always done it. We then pulled out the safety manual,
and I referenced the section, which clearly told them to do it
another way. They acted astonished and asked how long that
this particular rule had been in the manual. I replied that it
had been in the last safety manual revision, which dated back
to 1983.
Over time, linemen may grow complacent because they’re
used to doing things their way. To keep them safe, conduct
regular inspections of the job site and make them accountable
for not following the rules outlined in the safety manual.
2. Plan your work and work your plan. Within the OSHA stan-
dard for electrical line work, OSHA specifically requires job
planning and tells us what to discuss, including hazards as-
sociated with the job, the safety rules that we’ll need to fol-
low and any special precautions. We also need to cover energy
source controls and personal protective equipment. Finally, if
the job or conditions change, we need to schedule another job
Safety is Doing the Right Thing
Jason Selix, a lineman with Stearns Electric Association, dead-ends wire in Richmond, Minnesota.
April 2012 | www.tdworld.com80F
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Bluebonnet Linemen Battle Texas Wildfire Battle Texas Wildfire Field crews and contractors work to restore power after one of the most destructive fires in the state’s history.p
By Melissa Segrest, Contributing Writer
For more than two weeks last September, 1,350 men
and women came together to battle the flames that
burned more than 34,000 acres of Bastrop County
in Texas. Racing alongside, working tirelessly were
about 80 Bluebonnet Electric Cooperative workers and 450
hired contractors; the co-op’s other 208 employees helped
members throughout the emergency efforts.
Asplundh and McCoy Tree Surgery crews, led by Bluebon-
net workers, cleared trees endangering power lines, chipped
trees and hauled away debris. Area construction crews from
Line Tech, Richardson and T&D were hard at work, also. The
Bluebonnet crews cut off power in advance of the firefighters
to keep them, emergency workers and residents safe. They
opened fuses and breakers on power poles and remotely cut
power at substations from the control center.
Within a few hours of the fires starting, the company evacu-
ated its headquarters and brought its alternate control room
on-line. Almost immediately after the fires started, Bluebon-
net began implementing its power-restoration plan. Its focus
was on making the area safe and restoring power as quickly
as possible. Because of this, the utility was able to completely
restore power to all areas affected by the fires within three
weeks, nearly two weeks earlier than originally estimated.
Coordinating Crews
The utility devoted countless hours to training and prepar-
ing its responding agencies to follow the National Incident
Management System. This system is a model for managing a
massive disaster, one that requires help from multiple agencies
and jurisdictions.
The fact that all partners in the firefighting effort worked
within that system was key to the organized, coordinated re-
sponse to the fire, said Mike Fisher, the coordinator of the
Bastrop Office of Emergency Management. At the peak of
activities, more than 1,200 responders and electric workers
were coordinated safely and effectively by its local, regional,
state and federal partners.
As quickly as flames were extinguished, Bluebonnet’s crews
The haze of smoke hung heavy in the air while Bluebonnet ElectricCooperative crews coordinated efforts to cut power in advance of the firefighters’ assault on the September wildfires.
Lineman Brandon Johnson charts the day’s activities duringthe efforts to fight wildfires and restore power. In addition to recording activities on paper, Bluebonnet’s crews used cut-ting-edge technology to communicate to those in the fieldand plan for the next day’s response.
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and contractors began the difficult work of restoring power.
They removed downed lines and burned transformers, and
replaced poles. Crews removed burned trees and debris. Blue-
bonnet deployed 120 right-of-way/debris removal crews, 70
crews to chip and haul away burned trees for recycling, and
another 23 crews to restore power.
In his opinion, Fisher added, that cooperation was “a won-
derful and historic moment for all that participated in what
may be the most severe and tragic wildfire event in central
Texas history.” Bluebonnet had 4,338 meters along more than
200 miles of power lines in the burned area.
Restoring Power
The co-op began getting requests from members to recon-
nect power almost immediately, even if only to power a motor
home parked next to a destroyed home. The power was back
on to everyone three weeks after the blaze began.
On Day 1, at the same time Bluebonnet
Electric Cooperative’s headquarters in Bas-
trop was being evacuated and an alternate
control room was being set up in another
location, crews were in the field, cutting off
power to keep first responders safe.
The field crews de-energized locally and
remotely, said Eric Kocian, the manager of
electric operations and engineering, who
has been at Bluebonnet for more than eight
years.
At the backup site, planning began. Gen-
eral Manager Mark Rose and COO Matt
Bentke took the lead in keeping members
and the media informed, working with emer-
gency officials and organizing upcoming
field operations.
The wait to be allowed into the burn zone,
which eventually totaled more than 34,000
acres, gave Bluebonnet’s teams time to plan
how to best tackle the massive effort of
removing potential dangers and safely restoring power.
Thanks to the co-op’s rigorous emergency-management plan
and disaster training, decisions were made swiftly. Calls went
out to right-of-way and construction contractors from across
the region and state.
Executing the Plan
On Day 4, Bluebonnet crews were given access to enter part
of the burn zone, and they quickly realized more help was
needed. Eventually, more than 450 contractors worked along-
side 80 Bluebonnet employees in the field. The next day, the
entire burn zone was opened up to the field workforce. At that
point, it became more clear as to who was doing what, and
as a result, everyone got better organized. They followed the
Southern Incident Command Team’s lead, dividing the burn
zone into three areas. They also streamlined the chain of com-
mand so that three superintendents, one for each area, were
Bluebonnet Lineman Gets Married During Fire Restoration
A wildfire that raged through Bastrop County, Texas, didn’t put a stop to apprentice
lineman Jeffrey Bolding’s plans to marry his girlfriend, Brittany. On his wedding day, he
was helping his crew to restore power.
The couple first postponed their wedding because they wanted the focus to be
on helping the town of Bastrop. Several of their family members were in town as fire-
recovery volunteers, however, so the couple decided 24 hours before the original date
to get married on Sept. 10, 2011. Clad in jeans, a work shirt and dirty boots, Jeffrey took
his 30-minute lunch break to wed Brittany in front of 50 friends and family members
before returning back to work in his crew truck.
The Bastrop County Complex fire was one of the most destructive wildfires in Texas
history, destroying thousands of homes, killing two people and inflicting about $325
million of insured property damage. Fire officials reported that high winds toppled trees,
which fell on to power lines at two locations. As a result, the lines created sparks, which
ignited the dry grass, according to newspaper reports.
Photos by Sarah Beal, Bluebonnet Electric Cooperative Inc.
Apprentice linemanJeffrey Bolding dips hisnew bride, Brittany, for a kiss outside theBastrop County Courthouse.
Brian Peters, an apprentice lineman in Bluebonnet’s Red Rock service center, got acrash course in emergency work. He had been on the job just a few months when the fires began. With a helicopter dropping water to battle the nearby blazes, he and other crew members were checking boxes to make sure power was off.
ELECTRIC UTILITY OPERATIONS
www.tdworld.com | April 2012 80K
reporting to a single superintendent, who reported directly to
the COO.
It was, of course, not business as usual. Normally an engi-
neering employee in the co-op’s line-design group maps out
where and how poles, lines and other equipment are placed,
then construction crews head out to follow their plans.
To be more effective and efficient, line-design group mem-
bers were teamed with construction workers. The pairing
allowed form and function to merge quickly.
Throughout the process, advanced technology played a
crucial role. It allowed the co-op to quickly establish a techno-
logically strong alternate control center. Advanced mapping
systems guided crews into burn zones. GPS technology in the
trucks made the crews’ locations available at all times. Mobile
data software allowed line-design workers in the field to elec-
tronically communicate what materials would be needed the
next day.
Communicating with the Community
On Day 5, Bluebonnet technicians placed a map of the
burn zone on the co-op’s website and overlaid it with a color-
coded map estimating when power would be restored to differ-
ent areas. The map, available to members and the public, was
updated daily for the next 18 days, through Sept. 26. It gave
members specific information at a time when specifics were
often in short supply.
The map was posted at every news conference and at evacu-
ation shelters, and picked up by the media on a daily basis,
Rose said. It also served as a valuable resource to emergency-
management officials when they were deciding which areas
were safe for residents to re-enter and when.
Detailed information and hundreds of updates were posted
on Bluebonnet’s Facebook and Twitter pages. Member service
centers extended their hours, and representatives worked with
members without power and, in many cases, without homes.
The company’s other employees stepped in to maintain opera-
tions for the roughly 90% of Bluebonnet members who were
not directly impacted by the fire.
With every passing day, crews made increasingly accurate
estimates of time for repairs and cleanup. Daily huddles,
nightly conference calls, and regular discussions with emer-
gency-response experts and community representatives kept
everyone informed and coordinated.
“I think the main thing was that our guys wanted to restore
power as safely and quickly as they could. That’s their job, day
in and day out. It was a big and tragic event, but their focus was
the same,” Kocian said. “They were working 16-hour days, but
safety protocols kept them to strict deadlines for when it was
time to stop and rest.”
Bluebonnet’s emergency-response plan is a living docu-
ment, and every day the technicians are at some level of their
emergency-response plan. On a normal day, they are at level
one, but having that plan in place helps the entire organiza-
tion know what to do in case of an emergency.
Reconnecting Meters
Two weeks after the fire, work began to shift to reconstruct-
Companies mentioned:
Asplundh Tree Expert Co. | www.asplundh.com
Bluebonnet Electric Cooperative
www.bluebonnetelectric.coop
Line-Tec Inc. | www.linetec.com
McCoy Tree Surgery | www.mccoytree.com
T&D Solutions | www.tdsolutions.com
ing or providing new service for members who had lost homes.
The crews had been restoring power and clearing right-of-way.
Then dozens of work orders came in from members request-
ing technicians to reconnect their meters, creating a second
wave of activity. As such, Bluebonnet set a goal of getting the
jobs built in three days after the member requested it.
“One of the things that helped more than any was the field
crews seeing there was a light at the end of the tunnel,” Kocian
said. “Once you start getting power back on and you can see
the finish line, motivation grows stronger.”
As the days passed, work became increasingly efficient and
power was restored ahead of schedule. Crews worked 252 miles
of line in the burn zone. The last power outage was restored
19 days after crews began working in the burn zone, two weeks
earlier than estimated.
Hundreds of members who lost their homes have asked for
power to be restored. An estimated 1.5 million trees died or
are expected to die. By the end of October, more than 42,000
cubic yards of debris had been removed for recycling. More
than 1,000 poles have been replaced.
Throughout the restoration effort, the linemen had a hero
mentality when it came to restoring power, Kocian said. The
field crews received a lot of compliments from the members,
and those kind words made all the hard work worthwhile,
Kocian said.
Melissa Segrest ([email protected]) is a contributing
writer for Bluebonnet Electric Cooperative.
Doug Grimm, a Bluebonnet lineman, walks through a scorched area with an extender stick that is used to work on high powerlines.
ELECTRIC UTILITY OPERATIONS
April 2012 | www.tdworld.com80L
Linemen Specializein Live-Line Workin Live Line Work
pp
KT Power line crews work on energized linesto save utilities both time and money
g
in the field.
By Jeff Tiernan, William Tiernanand Dick Rieker, KT Power Inc.
About 14 years ago, it was rare for most electric util-
ity companies to work on energized lines. Pennsyl-
vania Power and Light (PPL), however, hired KT
Power to work live on a two-week project, and as a
result, the utility saved $7 million.
The Waddington, New York-based power line maintenance
company now works with PPL Electric Utilities to change insu-
lators and arms and switch overalls on 500-kV lines. KT Power
also performs work on PPL’s 230-V circuits, C-tag poles and
structure replacements. Because the utility has more work
than it can handle, it often turns to KT Power to maintain the
69-kV and 138-kV lines. In addition, the company performed
nearly 600 structure changeouts and worked several storm
outages last year.
Along with helping PPL, KT Power has spent the last 14
years performing live-line and high-voltage construction and
maintenance. In the beginning of the business, live-line work
had yet to become a common occurrence in the industry. In
fact, even today, the company is one of the few that can claim
energized work as its specialty.
The family-owned and operated company often helps elec-
tric utilities to save money in situations where they have to de-
energize a line in order to perform work. Because there are
some obvious risks, the company, which employs 40 linemen,
makes safety its top priority.
Focusing on Safety
KT Power employs common barehand techniques when
doing live-line work, including the use of conductive suits, spe-
cialized boots, protective socks and gloves interwoven with mi-
croscopic stainless-steel fibers. The barehand suits and gloves
ensure that the linemen are bonded to the bucket so every-
thing is at an equal potential.
Periodic inspections and testing of all live-line equipment
is maintained to ensure it meets the standards. KT Power pur-
chased many of the hot sticks and related tools from Hubbell/
Chance, and these are tested and cleaned every day to main-
tain optimum performance.
Most of the linemen are qualified by KT Power’s on-the-job
training to do barehand and hot stick work. Training ensures
that every job and task is reviewed and discussed prior to do-
ing the work. At the job site, the crew reviews the scope of the
project during the tailboard meeting. The safety consultant
and supervisors then analyze the work being performed to en-
sure that the linemen are maintaining live-line clearances.
The linemen wear flame-retardant clothing, including
hooded sweatshirts, long-sleeved work shirts, trousers, winter
jackets and bibs from suppliers such as Riverside Uniforms,
Carhartt and Tyndale. In addition, the linemen are required
to wear safety glasses, steel-toed boots, leather gloves and
proper safety gear, including flame-retardant harnesses. On a
Diversified Product Development and KT Power collaborated todevelop a phase lifter specifically for work on an energized 345-kV line for National Grid USA.
ELECTRIC UTILITY OPERATIONS
www.tdworld.com | April 201280M8181
ELECTRIC UTILITY OPERATIONS
daily basis, the linemen inspect all of their personal protective
equipment for durability.
Investing in New Equipment
The company also goes beyond typical precautions, con-
stantly seeking new ways to enhance safety and efficiency.
KT Power prides itself on being innovative, and in the last 13
years, it has gone from one bucket truck to 172 pieces of li-
censed equipment, such as 105-ft track machines and several
100-ft barehand-rated bucket trucks.
One of KT Power’s track units is an Altec AH100 bucket
truck mounted on a 2010 Prinoth Go-Trac 3000, rated for
500-kV work. This unit is part of KT Power’s fleet of 15 bucket
units.
Certified for 765 kV is a 168-ft Altec AC38 boom truck on
a 2007 International 8×6 chassis. This unit has the Diversified
Product Development insulated boom and The Von Corp.’s
boom current monitor.
Two of the company’s general digger derricks, which are
mounted on an Oshkosh chassis, each have a 500-kV insulated
boom for work on energized lines. KT Power has another 2012
digger derrick with an Altec DT80 that has been converted to
use in jobs requiring barehand work.
All of this specialized equipment is used in a combination
to dig and set poles, to hold conductors, and to erect the poles.
While the linemen sometimes employ barehand work methods
on new construction projects, the majority of the maintenance
and upgrade work is done energized. In some cases, it’s nec-
essary for the linemen to do the work the old-fashioned way,
even though they have so much equipment available to them
to get the job done. They then climb and rig off the structure
to perform the task required.
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ELECTRIC UTILITY OPERATIONS
April 2012 | www.tdworld.com80N
Searching for Product Innovation
KT Power never stops exploring ideas that help the field
professionals achieve their work in a safe and effective man-
ner. Those types of fresh ideas are almost a necessity in an
industry that increasingly encounters new demands. But while
ideas themselves are plentiful, utility companies often lack the
means and expertise to properly execute them.
Recognizing they needed help to bring some of their ideas
to fruition, KT Power turned to Diversified. Working primarily
in the power line utility niche, Diversified specializes in taking
a company’s initial idea and bringing it to a higher level of
function and design. In most cases, the firm will also manu-
facture the finished unit.
For example, Diversified supplied KT Power with two in-
sulated work platform (IWP) units, one mounted on a boom
truck and one designed for a track carrier derrick. Each IWP
is rated to 765 kV, which is the highest allowable voltage in the
United States.
As the country’s energy grid is enhanced and expanded,
the electrical industry is expected to move toward more ef-
ficient and more economical 765-kV transmission systems.
The cost to construct a typical 765-kV line is roughly a third
of what’s required to build the multiple 500-kV or 345-kV lines
capable of carrying the same amount of power. Utility compa-
nies, in turn, will need the proper equipment to adapt.
The higher voltage rating on the Diversified IWP will be
critical to the company’s future projects. KT Power, however,
has already noticed several advantages for the platforms out-
side of voltage capacity. For example, the platforms have an
extensive reach. Operators can get 165-ft working height out
of the IWP where they only get 100 ft with a bucket truck. As a
result, the IWP makes many tasks easier and safer.
Since the IWP essentially acts as a crane and as a bucket
truck, it frequently enables KT Power’s crews to bring in one
piece of equipment rather than two. This has been an advan-
tage on jobs involving mountainous terrain. In these projects,
equipment access can become a logistical challenge.
The IWP also offers certain design advantages. For exam-
ple, it has a clean boom with no wiring, no fiber optics and no
hydraulics. Because it’s one sealed piece of fiberglass, it doesn’t
require any maintenance. However, a bucket truck has about
five or six different components that can require attention.
In conjunction with the two IWP units, KT Power also uses
three Diversified man baskets, including one single-man bas-
ket, a 4-ft-wide two-person basket and a 6-ft-wide two-person
basket. Diversified also supplies the radio control systems for
operation of each IWP.
Most power companies are still using platforms with fiber-
optic controls, but KT Power has found that the radio con-
trols work more smoothly. In fact, the company is considering
switching over some older bucket trucks to radio controls to
eliminate past problems.
Lifting Phases
Another innovation brought to life through the collabora-
tion between KT Power and Diversified is a 500-kV-rated phase
lifter that was developed specifically for a job performed for
National Grid USA. The project, which originally began in
early 2007, entailed the changing of 139 single-circuit steel lat-
tice towers into two- or three-pole deadends, all of which was
to be done while National Grid USA’s 345-kV line remained
energized.
The equipment allowed the workers to come in from un-
derneath and hold the conductor, as opposed to coming over
the top with sticks hanging from a crane. The lifter provided
a significant advantage in areas where there wasn’t enough
Specializing in live-line work, KT Power goes beyond typical pre-cautions to seek new ways to enhance safety and efficiency.
Rated to 765 kV (the highest allowable voltage in the UnitedStates), Diversified’s insulated work platform has enabledKT Power to improve equipment utilization.
www.tdworld.com | April 2012 80O
ELECTRIC UTILITY OPERATIONS
Companies mentioned:
Airgas | www.airgas.com
Altec Industries | www.altec.com
Carhartt | www.carhartt.com
Diversified Product Development
www.diversifiedproduct.com
Hoffman Boots | www.hoffmanboots.com
Hubbell Power Systems | www.hubbellpowersystems.com
International Truck and Engine Corp.
www.internationaltrucks.com
KT Power Inc. | www.ktpower.com
National Grid | www1.nationalgridus.com
Oshkosh Corp. | www.oshkoshcorporation.com
Pennsylvania Power and Light | www.pplweb.com
Prinoth | www.prinoth.com
Riverside Uniforms | www.riversideuniforms.com
Tyndale | www.tyndaleusa.com
The Von Corp. | www.voncorp.com
overhead clearance to get outside and above the conductor —
areas where the only access was from underneath. Addition-
ally, the lifter could hold the conductor and move it out of the
way while a field crew tore a tower down. The tool has been
extremely versatile.
The phase lifter also simplified the setup process. The field
crews were able to hold and move the conductor out of the way
with existing trucks in their fleet. As such, it was much easier
than bringing in a large crane and having to rig a lot of sticks
to hold the conductor.
The phase lifter provided the efficiency boost KT Power
was looking for, allowing crews to safely complete the Nation-
al Grid USA job six months ahead of schedule. It proved to
be one of the latest in a long line of successes for KT Power,
which has gone to great lengths over the years to uphold its
reputation — not only for tackling high-voltage live-line work,
but for performing such jobs all over the county and even
overseas.
Jeff Tiernan ([email protected]) is the vice president
of KT Power. He has been in the industry for 30 years and been
with KT Power since 2005. Before that time, he worked as a
journeyman lineman for contractors and utilities. He graduated
in 1986 from his apprenticeship program and is now a field
supervisor.
William Tiernan ([email protected]) is president of
KT Power, which was founded in 1998. After starting his career
with 15 years at the New York Power Authority, Tiernan became
project superintendent for construction of a 765-kV line that
ran from New York into Canada. He then moved to the Western
United States in 1977 to attend every live-line school he could.
Shortly thereafter, he started his first company, which he later
sold in 1988.
Dick Rieker ([email protected]), a supervisor and trainer
for KT Power, has more than 40 years of linemen industry
experience, working worldwide in 18 various countries.
7/2+�
3!&%2
In transmission and distribution, nothing beats Bronto aerials for safety, efficiency & productivity s�Working heights over 340 ft.
�s Horizontal reach over 102 ft.�s�Platform capacity to 1500 lbs�s Insulated & non-insulated models
For more information: ��������� �����s�WWW�BRONTO�FI
ELECTRIC UTILITY OPERATIONS
April 2012 | www.tdworld.com80P
ASTM Supports
Aerial Device SafetyAerial Device Safety
pppp
Standards association discovers that acoustic emission testing can protect linemen and extend the life of its vehicles.
g pg p
By William C. Veal, ASTM International
Linemen who maintain transmission and distribution
lines and towers often work in a fiberglass bucket or
boom that stretches from 45 ft to 150 ft in the air. As
such, safety is paramount. Any serious, undetected de-
fects in aerial personnel devices, commonly known as bucket
trucks, could have catastrophic results.
Acoustic emission (AE) inspection is part of a comprehen-
sive preventative maintenance program for utility fleets to
extend the life and reliability of their equipment. AE testing
is designed to discover degradation of the insulated portions
as well as detect defects in the metal components caused by
fatigue or overloading, said Frank Petrasek, principal engineer
of Georgia Power Co. AE can alert inspectors to the location
of defects that are difficult or impossible to visually inspect,
explains Keith McPherson, a North Carolina-based engineer
with Altec Industries.
The concept of using the science of AE testing to evaluate
the condition of fiberglass-reinforced plastic (FRP) has been
around since the 1970s, but employing it to check the in-ser-
vice condition of bucket trucks in the utility industry began in
the 1980s.
AE inspection is based on the fact that materials under
stress emit sound waves. When captured by the proper equip-
ment, sound waves can be evaluated based on their strength,
or amplitude, and their location within the bucket truck. Al-
though additional methods can be used to assess the safety
and soundness of other components
of a bucket truck, AE is the only cost-
effective, non-destructive method for
checking FRP components.
Simulating Field Conditions
During an AE test, load, pressure
and other stressors are applied to
simulate the way a device or structure
is used in the field. Inspectors stress
the device slightly beyond a user-des-
ignated rating that is always less than
the designed maximum capability
engineered by the manufacturer but
above what the device experiences
in the field. Since the inspector’s test
load is always below the manufactur-
er’s designed maximum load, there’s
no danger that the acoustic test will
compromise the components of the
device being tested.
If inspectors find evidence of any
damage or defect that might be in-
creasing, they evaluate the amount of
emissions and/or their rate of growth
Acoustic emission test on bucket of a material handler with the jib and boom ready to betested.
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ELECTRIC UTILITY OPERATIONS
April 2012 | www.tdworld.com80R
based on requirements in published test standards, and de-
cide whether the device or structure should remain in service,
be repaired or be replaced.
Improving Vehicles’ Reliability
Linemen appreciate the additional visual and acoustic in-
spections because it adds another set of “eyes” on the vehicles
they depend on. As a result, they have more confidence in
their vehicles and their own safety. The utilities that partici-
pate in this program inspect their vehicles on a regular basis.
They often use load testing, which is monitored by AE under
controlled conditions, along with thorough visual and other
non-destructive inspections.
Once linemen understand the importance of the acoustic
testing process for vehicle safety, they often are interested in
what was found. Many times, they will give the inspectors clues
about areas that need to be further investigated.
At the same time, the inspections help the fleet managers
in their decisions on life extension of the vehicles and the at-
tached aerial booms. In many cases, maintenance schedules
of the vehicles benefit because problems may be discovered
early. In addition, repairs can be scheduled at regular mainte-
nance intervals, eliminating excessive downtime for the crews.
Inspections are usually performed during off hours or sched-
uled downtime hours to eliminate disruption for the crews.
AE inspections are usually performed during evenings and
weekends when the crews are not scheduled. In areas where
fleet mechanics are scheduled in shifts, most problems iden-
tified by the acoustic inspections can be handled before the
vehicles are needed the next day.
Revising Standards
The first test standard for field use of AE inspection of
aerial personnel devices was F914, Test Standard for Acoustic
Emission of Insulated Aerial Personnel Devices without Sup-
plemental Load Handling Attachments, published in 1985. It
was developed by Subcommittee 18.55 of ASTM Committee
F18 on Electrical Protective Equipment for Workers, which in-
cludes representatives of the utility industry, safety consultants,
manufacturers of aerial devices and AE testing organizations.
ASTM Contemplates Certification Program for Aerial Device Inspectors
In order to assist owners and users of aerial devices in developing individuals proficient in the ASTM test standards relating to
aerial devices, ASTM is considering developing a certification program that focuses on its three existing aerial lift standards. Here’s
what you need to know about the standards and proposed testing program.
1. The applicable standards. The three standards are: F914/F914M-10 Standard Test Method for Acoustic Emission for Aerial
Personnel Devices without Supplemental Load Handling Attachments; F1430/F1430M-10 Standard Test Method for Acoustic Emission
Testing of Insulated and Non-Insulated Aerial Personnel Devices with Supplemental Load Handling Attachments; and F1797-09e1
Standard Test Method for Acoustic Emission Testing of Insulated and Non-Insulated Digger Derricks. These standards are under the
jurisdiction ASTM subcommittee F18.55 on Inspection and Non-Destructive Test Methods for Aerial Devices.
2. The difference between certified versus qualified employees. Generally, utility fleet, utility contractor groups and inspection
service agencies have the ability to hire and maintain personnel certified for acoustic emission inspection. The American Society for
Non-destructive Testing (ASNT) has a personnel certification program developed for employer-based certification in the recognized
non-destructive examination (NDE) classifications for Level 1 and 2. This program, known in the industry as ASNT TC-1-A, contains
minimum recommended requirements for each level of certification and a certificate of completion, furnished when all requirements
are met. The actual certification level is administered through the employer as part of their quality assurance program. However, a
“certified” individual using this process may not necessarily be a “qualified” individual. Verification that employees are qualified for
specific NDE inspections still rests with the employer.
3. The need for objective testing. Acoustic emission (AE) has always been recognized as an inspection discipline that is extremely
operator dependent, especially as it relates to aerial lift inspection. Because of the inherent design of an aerial device, which includes
internal cables, sheaves, pulleys, hoses, pins, hydraulics, and a host of noise-inducing equipment, it is difficult for the inspector to filter
out non-relevant acoustic signals and focus only on relevant ones. Also, baseline acoustic signatures of one manufacturer’s device
compared to another may be different. These factors cause aerial device AE inspection to be more subjective and dependent on an
operator’s experience as he interprets the test data more so than in other types of AE inspection.
4. Review of current training. The ASNT personnel certification process in TC-1-A for AE touches on all of the possible AE
inspection methods. These methods include inspecting pressure vessels, underground piping, tank cars, and above ground storage
tanks, etc. Because classroom instruction hours and length of examinations must be limited, this certification process lacks specific
focus and detail on any one method. An individual is given an overview of how AE can be used, knowledge of the basic principles and
theories, and it touches on data interpretation for various methods. The current certification process does not necessarily “qualify” an
individual to inspect aerial lifts or interpret the type of test data received from such inspections. Developing qualified inspectors still
remains an employer responsibility.
5. The proposed program structure. If users and inspection agencies agree that a limited certification program would assist their
efforts to develop qualified individuals in aerial lift inspection and would be interested in having their personnel attend ASTM training
programs, the association could then move forward to create a program specific to the ASTM aerial lift standards. This will not replace
the basic ASNT AE certification. In fact, the ASNT AE certification would be a prerequisite for attendance in the proposed training.
ASTM would provide both classroom and hands-on field training, with both general and specific examinations. In addition, utilities
could give the graduates a certificate of successful completion, which could be used through their quality-assurance procedure to
create a limited certification in aerial device inspection.
ELECTRIC UTILITY OPERATIONS
www.tdworld.com | April 2012 80S
The first standard was followed in 1992 by
F1430, covering material-handling insulated
aerial devices; and in 1997 by F1797, concern-
ing insulated digger derricks that bore holes
and set posts. In subsequent years, each test
standard has been reviewed and revised sev-
eral times. In fact, AE data interpretation
techniques, test equipment and field experi-
ence have evolved to the point where the word
“insulated” has been removed from the stan-
dards, since AE is now used to evaluate the
metal components of devices as well as insu-
lating components. Additionally, ASTM Sub-
committee F18.55 has developed acceptance/
rejection criteria, which are now included in
the latest revisions of test standards.
Discovering Defects
In accordance with ASTM standards for
AE inspection, utilities and testing organiza-
tions have found cracks in the FRP booms of
aerial personnel devices, damaged material-
handling jibs, or winches on bucket trucks, and problems with
hydraulic holding valves. They’ve also uncovered inadequate
lubrication of pins and bushing and epoxy de-bonding at met-
al to FRP interfaces, resulting in repaired or replaced equip-
ment and enhanced safety for workers.
Additionally, AE inspection has been used to inspect aerial
devices after suspected damage. For example, if a bucket truck
experiences an overload caused by using the winch to pick up
an object beyond its rated load, AE testing can determine if
any significant damage has been done, McPherson said.
Inspection results are commonly grouped by the severity
and location of the acoustic activity, and are defined in three
ways:
M� Being an acoustic activity or a visual sighting severe
enough to remove the truck from service and requires further
investigation and repair
M�Being an acoustic activity or a visual sighting usually
caused by a known problem such as internal cables out of ad-
justment and can be scheduled for attention at a later time
M�Being no activity requiring attention.
To ensure a thorough inspection, ASTM standards also
dictate the use of other non-destructive test methods that
should be used in conjunction with AE, notes Jerry Tanner
from Diversified Inspections/ITL. These include ultrasonic
inspection, magnetic particle inspection, liquid penetrant and
dielectric testing where high ac or dc voltage is used to ensure
that the FRP section does not conduct electricity.
Recognizing the Benefits of Testing
Since the first ASTM standard was published, AE testing
has uncovered defects that might have cost lives or injuries if
gone undetected. It also has saved money by detecting defects
that, going unnoticed, would have cost more to repair later.
In addition, having testing standards ensures consistency in
testing and data collection, allowing any consultant or test-
ing agency to get similar results, said Tanner of Diversified
Inspections/ITL.
But regardless of the inspection method used, inspectors
should be certified and have years of experience testing and
interpreting data for specific devices or structures. In fact,
inspectors using ASTM standards are required to be certi-
fied under The American Society for Non-destructive Test-
ing (ASNT) guide to employer-based personnel certification
(ASNT TC-1A). ASTM International is also considering a pro-
gram for personnel certification specific to its published test-
ing standards for aerial devices.
AE testing has made great strides in its ability to locate
and evaluate defects in both FRP and metal components of
aerial devices for the utility industry. AE testing is now also
used to detect leaks and other defects in underground piping,
railroad tank cars, pressure vessels and aboveground storage
tanks. In the hands of trained, competent personnel, it is an
invaluable tool for maintaining the increasing complex inven-
tory of equipment in utility fleets, the pulp and paper industry,
power generating plants and many other industries.
William C. Veal ([email protected]) is a retired fleet test
coordinator from Georgia Power Co. and has been working with
acoustic emission since 1987. He is the chairman of ASTM F18.55
subcommittee, which developed the ASTM standards for aerial
lift inspection using acoustic emission. He has been with ASTM
since 1990.
Companies mentioned:
Altec Industries | www.altec.com
ATSM International | www.atsm.org
Diversified Inspections/ITL | L www.diusa.com
Georgia Power Co. | www.georgiapower.com
Acoustic emission test on a small bucket is sometimes referred to in the utility in-dustry as a trouble truck.
"
PRODUCTS&Services
ELECTRIC UTILITY OPERATIONS
Insulated Tool Kit
Klein Tools is now offering a utility-insulated 13-piece
tool kit with roll-up case.The tools exceed IEC 60900 and ASTM F1505standards for insulated tools and are clearly marked with the offi cial 1,000-V rating symbol. Two layers of insulation provide
protection against electricshock.
The light,compact, soft roll-up carry
case provides protective storage with custom-fi tted pocketsfor each tool. The tools that are included are D2000-9NE-INS,D2000-28-INS, D2000-48-INS, D203-8-INS, 602-4-INS, 602-6-INS, 602-10-INS, 603-3-INS, 603-4-INS, 603-6-INS, 63050-INS,D502-10-INS, and1570-3LR-INS. The kit includes a padded, adjustable shoulder strap.Klein Tools | www.kleintools.com
Cross-Arm Bracket
The Sherman & Reilly Fastrap Universal Cross-Arm Bracket is a tool that is used to mount any XS-100-style stringingblock to any common cross-arm,,regardless of its sizee andregardless of materiials.
The Fastrapembodies a new approachto an industry-standard system.By employing an adjjustable strap to a sturdy base, commbined with aratchet-level tightner, the Fastrap bracketer the Fastrap bracketcan be mounted and dismounted in less than half the time, with far less fuss and fumbling, and be far more securethan an ordinary bracket.
The Fastrap is complete in itself, requiring no other toolsto mount or dismount. Because it is a single model thataccommodates any common size of cross-arm or material,the Fastrap is likely the only cross-arm bracket that needs tobe carried. It is compatible with nearly all distribution-type blocks, and one model fi ts all cross-arm sizes.Sherman & Reilly Inc. | www.sherman-reilly.com
y pDA Reliability Improvement Solutiony p
GE announced the release of its End-to-End Fault Detection, Isolation & Restoration (FDIR/FLISR) system, a complete distribution automation solution that enables utilities to improve the reliability of their distribution network.This solution is capable of detecting power system outagelocations and automatically sectionalizing and reconfi guringdistribution circuits to restore power to as many customersas possible. The new FDIR/FLISR advanced distribution
automation system often can reduce typical customer outagetime from hours to under a minute, as well as improve autility’s SAIDI and SAIFI reliability indices.
This solution from GE includes the Multilin D400 DA,a substation-based FDIR system that can automate up to 20 distribution feeder circuits; the Multilin DGCS Switch Controller; the Multilin DGCR Recloser Controller; and the MDS Wireless Communications Network, which seamlesslywork together enabling easy deployment across the distribution network.
This solution is scalable and can be rolled out incremen-tally across the system, providing utilities with the fl exibility for staged deployments as their network requires. This dis-tributed substation and fi eld intelligence solution providesadditional reliability with the ability to restore local parts of the network even when wide-scale problems such as loss of backhaul communications to the control center occur.GE Digital Energy | www.gedigitalenergy.com
Cordless Drill
The Milwaukee M18 FUELDrill Driver features up to725 in/lb of torque. Thenew Milwaukee, designedand built POWERSTATEBrushless Motor, providespower and torque to completethe toughest of applications. The motor delivers up to 10 times longermotor life for maximum durability.
Powered by the RedLithiumbattery pack, the Drill Driverdelivers up to 50% more run-time than the competition. The M18RedLithium batteries providelonger battery life, withmore than fi ve times morerecharges than leading competitors. A batteryfuel gauge displays remaining charge for less downtime.
The product features REDLINK PLUS intelligence,which provides total system communication with overload protection. The M18 FUEL Drill Driver comes with the new multi-voltage charger, so users can charge all M12 and M18 batteries with one charger. A new contoured soft grip gives users the ultimate comfort during prolonged use. The M18FUEL Drill Driver comes with an all-metal ratcheting lockingchuck for maximum grip, bit retention and durability. Toolfeatures an LED light and is compatible with RedLithiumcompact and XC battery packs.Milwaukee Electric Tool Corp. | www.milwaukeetool.com
Flame-Resistant Rain Jacket
Bulwark’s I-Visibility fl ame-resistant rain jacket HRC2 features non-conductive, durable hardwear, 2-inch refl ectivestriping, two patch pockets and a vented back with “D” ringaccess. It also has take-up tabs on the cuff and is waterproof.The fabric is made of 10-oz polyurethane on a knit fl ame-resistant treated cotton. To care for it, users simply wipe itwith a soft cloth, warm soap and water, and let it air dry.
The arc rating APTV is 19.0 calories/cm² EBTAS 28calories/cm², and it is rated at ANSI 107-2010 Class 3 Level2. It also meets ASTM F 1891-06 ARC and fl ame-resistantspecifi cations as well as ASTM F 2733 fl ash fi re hazardspecifi cations. Bulwark | www.bulwark.com
April 20122 | www.tdworld.com
ELECTRIC UTILITY OPERATIONS
dock. The latch has a built-in keyed lock for theft deterrence. Onthe front of the dock, a LED Power Switchhas beenincorporated to allow the user to hot dock the computer without having to power downthe computer.
The CF53 docking station has two power-supply options available: external Lind auto adapter (sold separately) and a factory-installed internal 120-W Lind power supply. Certifi cations and testing include RoHS, FCCand Vibration Testing - MIL-STD 810G 514.5. The dockinghandle is tested to 10,000 cycles and SAE Standard J1455Crash Test (pending).Gamber-Johnson | www.gamberjohnson.com
gHot Stick Bagsg
Bashlin’s protective hot stick bags are made from coated polyester material and feature a snap-button closure. Theyare 4 inches wide. Users should order the bag according tothe length of the stick and size, as indicated with the stick description. The bags are available in a variety of sizes: 30,45, 60, 65, 75, 80, 100, 125 and 130 inches.Bashlin Industries Inc. | www.bashlin.com
Gloves
stown Glove Co.’s TouchScreenYoungse features capacitive materials onGlovehe index and middle fi ngers andth
thumb, thereby allowing usersto operate touchscreen devices— such as an iPad, touchscreen monitor or Smartphone — all
while wearing gloves. The glovesappropriate for both resistive andare
acitive screens. By getting a form-capat glove, users can take advantagefi tof the freedom to operate
touchscreens while keeping their hands safe and protected.Youngstown Glove Co.
www.ytgloves.com
gDocking Stationg
Gamber-Johnson, an ISO 9001:2008 certifi ed manufacturer of rugged docking stations and vehicle mounting, introduces a docking station designed for the Panasonic Toughbook 53.
The new CF53 docking station was designed to maximize the space available inside the vehicle by using a small docking station footprint. Using rugged aluminum, thedocking station weighs 6.5 lb without a power supply and7.5 lb with an internal power supply. Using the same docking mechanism as the company’s CF19 docking stations, userscan simply insert the computer and push the latch closed to
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ELECTRIC UTILITY OPERATIONS
yWork Vehicle Accessoryy
The CabinGuard helps to separate the back of the cabfrom the driver’s space. It assists in meeting OSHA and MSHA regulations for in-cab cargo containment. The fl oor-to-ceiling barrier fi ts between the front seats and the back of the cab. Optional steel shelving is available. The product comes with an optional rear door lock kit for Chevrolet/GMCextended cabs to increase security for valuables.mobileDUZ | www.mobileduz.com
gScoring Toolg
The Banana Peeler AdjustableBlade Semi-con ScoringTool is designeddto work with0.75-inch to 1.10-inch OD cable. The adjustable blade semi-con scoring tool has a scoring depth from 1 mil to 90 mils (0.025 mm to 2.286 mm). The tool is for “strippable” semi-con
URD cable shield, and users can score the circumference andlength with one hand. The spring-loaded blade assemblyensures consistent scoring depth. The tool also features aTefl on-coated cable guide. The unique cartridge adapts toout-of-round cables, and the semi-con is cleanly removedwith no damage to underlying insulation. It measures 9.32inches long and weighs 12.92 oz. Ripley Tools | www.ripley-tools.com
Bolt Wrench
The REC-SB is a battery-operated shear bolt wrenchespecially designed to torque down and shear the shearbolts for electrical connection use. The tool features a unique shape to reduce its length for easy access to tight spaces. It has 48 ft/lb of torque and features variable speeds up to2,200 rpm.
The shear bolt wrench is designed to work with shear bolt underground connectors. It can handle the connection of twoto eight services in hand holes and offers a variable speed to2,200 rpm with a 0.5-inch square drive. Its short body lengthis suitable for tight-space applications. The battery and tool have a fi ve-year warranty, and the wrench can handle 48 ft/lbof torque. The tool can go in forward or reverse and weighs 5 lb with the battery. It measures 13.75 inches by 7 inches by3 inches. Huskie Tools | www.huskietools.com
Universal Attachment
The Double-Header Universal Attachment tool allows users to attach two different universal tool accessories tothe same stick. The tool maximizes speed and convenience because linemen can simply twist the stick instead of changing the accessory. The product is made of aircraftaluminum for maximum durability and minimum weight. The attachment includes two thumb screws.MADI, LLC | www.madillc.com
April 20122 | www.tdworld.com80V
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ELECTRIC UTILITY OPERATIONS
Fall Protection
Buckingham harness and bodybelt combinations aresuitable for individualsworking where both fall protection andwork positioning are required.
Any lineman’sbody belt can be permanently attached to a harness by meansof stitching or by web loops. If the user wants aa belt that can be removed, dBuckingham offers quick-connect nylon clips attached to theharness that keep the body belt in place.
The Model 619891 harness and ErgoBelt combinationincludes an ‘H’ style harness and a 4200 Buck ErgoBelt. The harness is connected permanently to the Buck ErgoBelt upper section through tunnels built into the belt. The harness is not sandwiched between the user and the belt, providinggreater freedom of movement.
The harness features a sateen liner on belt and shoulderpads, grommet leg straps, adjustable chest strap with quick-connect buckle, and rescue loop and dorsal attachment that can be used for pole-top rescue.
The ErgoBelt features a stabilizing strap, removable lumbar pad, plus buckles to connect to the lower seat sectionproviding an extra set of dee rings if desired.Buckingham Manufacturing | www.buckinghammfg.com
gWinding Resistance Meterg
The Tettex 2293 from Hipotronics incorporates a fast andhighly advanced procedure to measure winding resistance.A simple one-time-connection system, together with thesimultaneous winding magnetization method, drastically reduces measuring time.
The simultaneous winding magnetization methodguarantees fast and reliable measurements, even on large power transformers with delta windings on the low-voltage side, where stable measurements can be seldomreached, using traditional winding resistance measurementinstruments. In addition, the new demagnetization functioneliminates the magnetic remanence in the core after the application of a dc voltage. The full graphical interface with a 7-inch touchscreen guides the operator through the testprocedure. The unit visualizes each test cycle and displaysthe results graphically or in list format.Hipotronics | www.hipotronics.com
Transformers
Standex Electronics’ Current Sense Transformer (CST)allows utilities to monitor time-of-use and invoice those customers who are driving the need for increased capacitywith higher rates, thereby altering demand.
Standex CST transformers are applied on circuits withcurrent that is too high for direct monitoring. Current inthe monitored circuit produces a reduced but proportional current in the Standex CST, which is then monitored bymeasuring instrumentation. This serves to isolate the measuring instrumentation from the monitored circuit. Standex Electronics | www.standexelectronics.com
www.tdworld.comm | April 2012 80W
ELECTRIC UTILITY OPERATIONS
PartingSHOT
Photo courtesy of Puget Sound Energy
ELECTRIC UTILITY OPERATIONS
April 2012 | www.tdworld.com80X
A snow and wind storm knocked out power to 450,000 of Puget Sound
Energy’s 1.1 million electrical customers from Jan. 18 to 23, 2012. This storm
inflicted severe damage to the utility’s infrastructure by bringing down power
lines and poles. When the snow and ice melted, it caused a landslide, which
damaged three homes.
To restore power as quickly as possible, Puget Sound Energy called
upon several companies from the Western United States and Canada. In
this photo, a crew from Valley Power Lines Contracting out of Surrey, British
Columbia, works together to transport a wood pole on Jan. 22. The team was
working on a project to restore lines in Renton, Washington.
www
.hyundai
-elec.com
There are a lot of imitations, but only one genuine masterpiece.
Hyundai Heavy Industries’ world renowned ship building skills and
state-of-the-art technologies will benefit you with circuit breakers that
are genuine masterpieces of electrical systems.
Genuine Masterpiece -HYUNDAI CIRCUIT BREAKERS
Email [email protected] / [email protected] / [email protected]
Vacuum ContactorVacuum Circuit Breaker
Seoul Office 82-2-746-7510, 8519 Orlando 1-407-249-7350 New Jersey 1-201-816-0286 Chicago 1-847-228-8845 London 44-20-8741-0501 Moscow 7-495-258-1381 Dubai 971-4-425-7995 Tokyo 81-3-3212-2076 Yangzhong 86-511-8842-0666
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Engineering & Technical Support Ohio 1-419-522-3611
82 April 20122 | www.tdworld.com
Orlrlandodo, FlFlororidida, iiss hohosttining thththe ee IEIEEIEEEEEEEE PPESESESS TTTTTTTrarararannsnsns-
mission & Distribution Conference and Exposi-
tion May 7-10 at the Orange County Convention
Center. The March 2012 issue of T&D World pro-d
vided extensive coverage of what attendees can expect to see
and learn at the upcoming conference, who will be exhibit-
ing and where they will be located on the show fl oor, as well
as what products will be demonstrated. Here are some last-
minute updates of this show, the biggest event in T&D in 2012.
Women and Minorities in Engineering Panels
The Women in Energy panel provides an opportunity to
meet other professionals and compare experiences in the en-
ergy market. The panelists include women who are a part of
utilities, developers, engineering fi rms and universities who
2012 IEEE PES T&D Conference & Exposition
hhahahahavve d diviviiviverereererrsese e eexpxpxpxperererertitititisesesese i i iiinnn n susuststaiainanabib lity, opperratations, engineer-
ing consulting and contracting. The panel experts will discuss
their career paths, lessons learned and challenges faced.
The panel will be on Tuesday, May 8 from 3 p.m. to 5 p.m.
Shay Bahramirad of S&C Electric will moderate the discus-
sions featuring the following panelists: M p Cheri A. Warren, vice-president, smart grid, National
Grid, Waltham, Massachusetts, U.S.M Deborah Le Vine, director of system operations, Califor-
nia Independent System Operator Corp.M Marija D. Ili, professor of electrical and computer engi-
neering, Carnegie Mellon University, and honorary chaired
professor for control of future electricity network operations,
Delft University of Technology M Noel Schulz, IEEE Power & Energy Society president,
SHOW UPDATE
PHONE/FAX 1.855.5GDISALE EMAIL [email protected] WEBSITE www.geodigital.com
Hamilton, ON | Ottawa, ON | Vancouver, BC | Victoria, BC | Lompoc, CA | Los Angeles, CA | Mendota Heights, MN | Peachtree City, GA | The Woodlands, TX
GDI provides:
� LiDAR surveys and geospatial
imagery of distributed field assets
� Actionable information to manage compliance
with regulatory agencies
� Unifying mobile work force solutions that connect
the office with the field
� Web based reporting systems that lead to increased
reliability while lowering costs and minimizing risk
ANYTIMEANYWHEREANY ALTITUDE
84 April 20122 | www.tdworld.com
Monday, May 7
8 a.m. – 5 p.m. International Visitors Center Open
8 a.m. – 5 p.m. Tutorials (purchased ticket required)
8:30 a.m. – 4:30 p.m. Technical Tours
6:30 p.m. – 9:30 p.m. Opening Reception, Rosen Shingle Creek Hotel (badge required)
Tuesday, May 8
7 a.m. – 5 p.m. International Visitors Center Open
8 a.m. – 10 a.m. Opening Session
10 a.m. – 5 p.m. Exposition Open
12:30 p.m. – 3:30 p.m. Technical Tours
12:30 p.m. – 5 p.m. Ethics/Florida Laws and Rules
1 p.m. – 5 p.m. Technical Sessions
Wednesday, May 9
7 a.m. – 5 p.m. International Visitors Center Open
8 a.m. – 12:30 p.m. Ethics/Florida Laws and Rules
8 a.m. – 5 p.m. Technical Sessions
8 a.m. – 5:30 p.m. Smart Grid Day at T&D
8:30 a.m. – 4 p.m. Technical Tours
Schedule of Events
9 a.m. – 11 a.m. Student Job Fair
9:30 a.m. – 5 p.m. Info Sessions
10 a.m. – 12 p.m. Super Session I
10 a.m. – 6 p.m. Exposition Open
10 a.m. – 6 p.m. Collegiate/GOLD/Industry Luncheon (ticket required)
11:30 a.m. – 1 p.m. Student Job Fair
1 p.m. – 3 p.m. Super Session II
1:30 p.m. – 3:30 p.m. Student Job Fair
4:30 p.m. – 6 p.m. Networking Reception in Exhibit Halls
5 p.m. – 7 p.m. Poster Session Reception (conference registration required)
Thursday, May 10
7 a.m. – 2 p.m. International Visitors Center Open
7:30 a.m. – 2:30 p.m. Technical Tours
8 a.m. – 3:30 p.m. Technical Sessions
9:30 a.m. – 2 p.m. Info Sessions
10 a.m. – 12 p.m. Super Session III
10 a.m. – 3 p.m. Exposition Open
2:30 p.m. – 4 p.m. Closing Reception
PQSys
We take care of it.
A. Eberle GmbH & Co. KG s Frankenstr. 160 s�D-90461 NürnbergPhone +49 911 628108-0 s�[email protected] s�www.a-eberle.de
Power Quality.
s Power Quality according to different standards IEC 61000-2-2 / 2-4 and EN 50160s Fully compliant to IEC 61000-4-30 Class As Disturbance Recorder (oscilloscope, RMS, events)s Binary inputs, relay outputs, analogue outputs (mA)s Load analysis and energy managements Powerful visualization software WinPQ/PQ ParaExpresss SCADA-communication (TCP/IP, IEC 61850, IEC 60870-5-103)
PQI-D: flexible and precise:PQI-DA: comfortable and varied:PQ-Box 100: mobile and robust:
Paslay professor of electrical and computer engineering, Kan-
sas State University, Manhattan, Kansas, U.S.
The Minorities in Engineering panel will discuss the roles
and importance of women and minorities in the power indus-
try. The session will explore the following topics: the aging
workforce, the importance of diversity in the power industry,
and women and minorities in the power industry. The panel
will be held May 8 from 1 p.m. to 3 p.m. Chris LaRussa (FRCC)
and Kristy Baksh (PEF) will be moderating. M “Building Our Energy Future One Person at a Time,”
Wanda Reder, vice president of power systems services, S&C
Electric Co.M “Diversity and Inclusion Powers Innovation,” DeWanda
Smith-Soeder, senior diversity and inclusion consultant, Prog-
ress Energy M “Women in the Power Industry,” Beth Young, director of
energy control center, Tampa ElectricM “Minorities in the Power Industry,” Andre Uribe, senior
vice president of business development and co-founder, Power
Grid Engineering Inc.
IEEE EXPOSITION
STRENGTHTrue in OURLIES
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86 April 20122 | www.tdworld.com
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Company Boothp y
(Melec) Shanghai Jiameng Electrical Equipment Co. Ltd.. . . . . . . . . . . . . . . . . . . . . . . . . . . . 4348
Aerotec . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . c 4470
Alcan Cable. . . . . . . . . . . . . . . . . . . . . . . . . . . 4455
Aluminum Fastener Supply Co. Inc. . . . . . . . 4442
Brockhaus Messtechnik . . . . . . . . . . . . . . . . . k 1895
Classic Connectors Inc. . . . . . . . . . . . . . . . . . 4342
Dalian Ceramic Technic Co. Ltd. . . . . . . . . . . 1713
Dalian Insulator Group Co. Ltd. . . . . . . . . . . . 1709
Desma USA Inc. . . . . . . . . . . . . . . . . . . . . . . . 4349
DILO Co. Inc.. . . . . . . . . . . . . . . . . . . . . . . . . . 4444
EJ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 272
Electrical Consultants Inc. (ECI) . . . . . . . . . . . 4446
Electricas BC . . . . . . . . . . . . . . . . . . . . . . . . . . . 246
Forward Engine (Beijing) Machinery Equipment Co. Ltd.. . . . . . . . . . . . . . . . . . . . . . . . . . . . 4195
Global Choice International, LLC. . . . . . . . . . 3393
GMI Composites Inc. . . . . . . . . . . . . . . . . . . . 4566
Graybar . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . r 4489
HEDRICH Group Wilhelm Hedrich Vakuumanlagen GmbH & Co. KG . . . . . . 3581
Helicopter Services Inc. . . . . . . . . . . . . . . . . . . 284
Henan Pinki Electric Power Equipment Group Co. Ltd.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . 270
High Voltage Partial Discharge Ltd. (HVPD) . 4344
InStep Software, LLC . . . . . . . . . . . . . . . . . . . 4356
Intelligent Access Systems of NC, LLC . . . . . 4449
IPEC Ltd. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4353
IPS-ENERGY USA Inc.. . . . . . . . . . . . . . . . . . . . 593
Longsper Insulation Technology (TIANJIN) Co. Ltd.. . . . . . . . . . . . . . . . . . . . . . . . . . . . 4493
MADI, LLC . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4456
Matco Services Inc.. . . . . . . . . . . . . . . . . . . . . 4352
Midsun Group Inc. . . . . . . . . . . . . . . . . . . . . . 4454
Milbank Manufacturing . . . . . . . . . . . . . . . . . 4571
MWH Global . . . . . . . . . . . . . . . . . . . . . . . . . . 4465
Parts Super Center . . . . . . . . . . . . . . . . . . . . .r 4482
Ponovo Power Co. Ltd. . . . . . . . . . . . . . . . . . . 4354
Power Consulting Associates, LLC . . . . . . . . 4562
Rubadue Wire Co. Inc. . . . . . . . . . . . . . . . . . . 4346
Shanghai Airic Cable Accessories Co. Ltd.. . .1711
Skipper Ltd. . . . . . . . . . . . . . . . . . . . . . . . . . . . 4445
Smart Wire Grid Inc. . . . . . . . . . . . . . . . . . . . . 4345
Specialized Camera Sales, Div. of Ox Creek Energy Assoc Inc. . . . . . . . . . . . . . . . . . . . 4443
Tollgrade Communications Inc.. . . . . . . . . . . 4347
Tri-Data Solutions Inc. . . . . . . . . . . . . . . . . . . 4452
Volani Metais Industria E Comercio Ltda.. . . 2967
IEEE EXPOSITION
EXHIBITOR UPDATES(As of April 26, 2012)IEEE Show Blog
Visit the IEEE Show Blog where you will be provided a unique fi rst-person tour t the IEEE Show BloSh
of the events that make up the 2012 IEEE PES T&D Conference and Expo. f the events that mak
Blog postings begin a week prior to this Orlando event and run continuously log postings begin a w
during the May 7-10 show. Our blogger is Gene Wolf, former chairman of the ring the May 7-1
IEEE PES T&D committee. Join Gene as he participates in events major andEEE
minor, wanders the show fl oor, meets intriguing individuals and investigates min
the latest in technologies: http://ieee-pes-td.com.
Come visit us!
Booth 1281TM
Answers for infrastructure and cities.
Siemens has a tradition of setting highest standards in
the field of energy automation. With ENEAS (Efficient
Network and Energy Automation Systems) solutions for
distribution automation, the flexible adaptation of sup-
ply systems to future needs becomes possible.
Distribution automation is the interface between the
medium-voltage and low-voltage systems. It provides
the option to completely monitor and automate all con-
trollable devices, such as reclosers, breakers, and switch-
es. Siemens ENEAS solutions for distribution automation
are field-tested and based on proven Siemens devices.
Siemens can design the best solution by analyzing the
grid in the early planning phase and, together with the
customer, pave the way to implement a tailored solution
up to a self-healing grid. This allows making the right
decisions for monitoring or automation configurations.
ENEAS solutions for distribution automation enable flexi-
bility in design for comprehensive control of the entire
distribution network. Siemens ENEAS solutions imple-
ment new business models in the framework of Smart
Grids.
Precise fault location creates the basis for automated
switching and highly efficient workforce management.
Design, development, configuration changes, and up-
dates of automation equipment are made easier. Asset
data enable the reduction of maintenance times.
Siemens ENEAS solutions for distribution automation
create the highest possible degree of reliability, and the
basis for sustainable success in a cost-efficient way.
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Roadmap for self-healing distribution gridsSiemens ENEAS solutions for distribution automation
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location
Asset monitoring
Grid quality
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Power quality Low-voltage control
April 20122 | www.tdworld.com88
IEEE EXPOSITIONProducts&Services
p gCompounds and Asset Managementp g
Dow Electrical & Telecommunications will have experts on hand to talk about the company’s offerings:
MCommercialization of its advanced performance MV TR-XLPE compound, DOW ENDURANCE HFDC-4202 EC, which demonstrates increased cable longevity, ease of installation and more robust quality processing
M Strengths in HV/EHV offering for underground and submarine cable systems
M Signifi cance of growth in the Dow Inside program that boasts an increasingnumber of licensees around the globe
M Investments in asset optimization to ensure continuing product quality and commitment to the power industry.Dow Electrical & Telecommunications | www.dow.com/electrical
Booth 4042
Transformers, Substations and Breakers
Visit Siemens to explore products and solutions, and speak directly with productexperts to learn more about the company’s innovations and the future of energy.
Siemens will have many products to explore at the show:M Navigate the inside of a transformer in a hands-on, interactive 3D experience M Gas-insulated substationM Vacuum tap changer and control panel M 362-kV dead-tank circuit breaker M 72-kV live-tank vacuum breaker M Surge arresterM Medium-voltage gas-insulated switchgear M Distribution recloser M Disconnect switchesM Outdoor distribution arc-resistant circuit breaker. The company also will have demos and models on display:M High-voltage systems M Flexible AC Transmission Systems (FACTS) M Gas-insulated linesM Voltage regulators.
Siemens | www.usa.siemens.com/power-transmission
Booth 2747
Time Domain Refl ectometer
The AEMC Fault Mapper Pro is a hand-held graphical TDR(time domain refl ectometer) designed for identifying and locatingfaults on power cables, given access to one end only.
The Fault Mapper Pro measures cable length and indicatesthe length and distance to cable faults to a range of 9 ft (3 m) to19,000 ft (6,000 m) on virtually any type of cable. It injects a series of pulses into the cable under test. The velocity at which thepulses travel is determined by the type of cable, which is known asthe velocity of propagation (Vp) of the cable. The Vp is adjustable between 1% and 99% enabling accurate calibration to the cableunder test.
The Vp value, expressed as a percentage of the speed of light, will vary according to the type of cable under test. The FaultMapper Pro can accept user-selectable values between 1% and 99% (or the equivalent value in feet or meters per microsecond).
Based on the selected Vp and the time taken for the pulses to travel through the cable, a refl ection profi le of the cable under test is displayed. An adjustable cursor assists in locating faults and termination.
The Fault Mapper Pro incorporates an oscillating tone tracer, which is detectable with a standard tone tracer, for use in the tracing and identifi cation of cable pairs.AEMC Instruments | www.aemc.com
Booth 702
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April 20122 | www.tdworld.com90
IEEE EXPOSITONProducts&Services
GRID POWER PRODUCTS
Introducing the latest products added to our
manufacture of pole line supplies.
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yDissolved-Gas Analysis Monitorsy
LumaSense Technologies Inc. has introduced a new category of dissolved-gas analysis monitors that allow electric utilities to moreeffectively reduce outages caused by faulty load tap changers (LTCs)and transformers. At a cost significantly less expensive than comparable DGA monitors and a unique hardware design that drastically cuts down installation time, the LumaSense SmartDGA platform can helputilities achieve widespread condition monitoring across generation, transmission and distribution assets.
Whereas other systems take days to install, a SmartDGA monitor can be installed in a matter of hours. Additionally, SmartDGA monitors will cost up to 50% less than other monitors. The first monitor in the newline, the SmartDGA Gauge, will be the industry’s first dedicated online gas monitor for LTCs.
SmartDGA Gauge is the newest addition to LumaSense’s line of solutions designed to provide utilities more information about how
their transformers are functioning. LumaSense also provides a range of fiber-optictemperature sensors used to monitor winding hot spots and continuous thermal imaging systems that remotely monitor substations. LumaSense Technologies Inc. | www.lumasenseinc.com
Booth 3480
gFault-Current-Limiting Devicesg
Zenergy Power is a superconductor energy technology company focused on the innovation and manufacture of highly efficient fault-current-limiting devices.
In 2009, Zenergy Power became the first company to install and operate a superconductor fault-current-limiting device in the U.S. electricity grid. The device presently resides in the distribution network of Southern California Edison.Zenergy Power | www.zenergypower.com
Booth 1983
gIED Manager Softwareg
Cooper Power Systems has announced the availability of its YukonIED Manager Suite (IMS) release 5.0. Therelease includes the Password Manager module — providing the capability toremotely manage intelligent electronicdevice (IED) passwords.
Through a web-based management interface with granular access control, IMS allows the viewing, changing and up-dating of passwords for devices such as the Cooper Power Systems SMP Gatewayand Schweitzer Engineering Laboratories relays. Generated passwords can meetall NERC CIP complexity requirementsand are securely stored in an encrypted database — providing fail-safe operation against password loss.
The IMS release 5.0 protects a utility’s critical assets through role-based access control where groups of userscan be granted permissions to performoperations to groups of IEDs. The IMS Password Manager builds on this model and users can be granted permission to view only the passwords of the IEDsto which they have access; moreover, users can only perform operations theyare authorized to do, including remotepassword updates. Cooper Power Systems
www.cooperpower.com
Booth 2063
y pUtility Enterprise Softwarey p
Sensus is partnering with HarrisComputer Systems to integrate its advanced metering infrastructure and distribution automation solutions withHarris’ utility software solutions. The collaboration will enable the delivery of smart grid solutions to new and existingutility customers.
The Harris utility applications nowavailable to Sensus customers offer anintegrated suite of software solutions for meter data management, asset manage-ment and consumer engagement. The modular and scalable suite is designedfor quick deployment and priced to suit the needs of small and mid-sized utilities. Sensus | www.sensus.com
Booth 587
gTransformer Bushingg
Henan Machinery & Electric I&E Co.is a supplier of transformer bushings that meet ANSI/DIN/AS standards.The company also produces porcelain bushings for fuse cutouts, arresters,capacitors and circuit breakers.Henan Machinery & Electric I&E Co. Ltd.
www.cmec-henan.com
Booth 3583Visit us at IEEE, Booth 3490
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Find out about reliability, safety, tools, technologies, regs, standards, and more.
Plus, register to receive monthly updates directly to your inbox with Vegetation Management
Insights, the e-newsletter from the editors of T&D World.
Go to tdworld.com/vegetationmanagement
PRODUCTS & SERVICES HELP WANTED
PROTECTION ENGINEER
Hoosier Energy REC, Inc.
Hoosier Energy, the rural electric generationand transmission cooperative in southernIndiana, is seeking a Production Engineer at its Headquarters location in Bloomington, IN.
Primary responsibilities include providing and coordinating an overall protection philosophy forHoosier Energy’s transmission facilities and for the design and application of optimum systemprotection for all transmission equipment andgeneration units; the development of designs and specifications of Hoosier Energy’s watt-hour meters and any other energy measurementsystems or devices; and assure compliancewith all NERC and RRO reliability standards.
Bachelors of Science degree in electricalengineering or its equivalent required. Thesuccessful candidate will have five years’ of progressively more technical responsibility in the design and application of relay and meteringfacilities and equipment. Must be knowledgeableof design, installation, maintenance, testingand setting of energy measurement and systemprotection devices; substation and transmissionoperation and maintenance practices; relayingand metering principles; communications and leadership skills; proficient in the useof AutoCad and Aspen One-liner. Hoosier Energy offers competitive salary and benefits,and opportunity for professional growth.
For consideration, please submit youronline resume to www.hepn.com.
An Equal Opportunity Employer
IEEE EXPOSITONProducts&Services
gSmart Metering Solution for IEC Marketsg
GE has announced the availability of the SGM1100, a PRIME (Power Line Intelligent Metering Evolution) PLC-compliant smart meter designed for global utilities following International Electrotechnical Commission (IEC) requirements. The SGM1100 provides utilities with a cost-effective and fl exible solution to meet the requirements of an advanced metering infrastructure, laying the foundation for increasing effi ciency andbetter managing energy costs.
The SGM1100 is a single-phase meter designed to support residential and small commercial energy consumers. In alignment with local standards, the SGM1100 meetsIEC requirements and provides PLC AMI communications with the PRIME and theDLMS/COSEM protocols.
Designed for ease of use, GE’s SGM1100 enables utilities to accelerate installations, automate provisioning and reduce the amount of required post-installation support, which results in faster and more cost-effi cient deployments. Additional benefi ts include increased security features and a dual pole relay for increased safety duringinstallation and service; remote upgradeable fi rmware via the PLC communications to reduce on-site visits for maintenance; local communications enabling site-specifi cconfi guration, fi rmware updates and on-demand diagnostics; and an integratedPRIME PLC modem providing reliable and interoperable communications with PRIMEcompliant data concentrators.GE Energy | www.ge.com
Booth 3271
g gGIS, Outage Management Softwareg g
Trimble’s solutions for utilities help improve effi ciencies every step of the way, from project scoping and prefeasibility to construction and management of buildings, transmission lines and pipelines to asset management, mobile GIS, vehicle location,fi eld staking and outage management solutions. Trimble offers a complete line of software, hardware and business services solutions for utilitiesTrimble | www.trimble.com/utilities
Three-Phase Reclosers
G&W Electrichas extended itsline of three-phase recloserswith a triple/single design specifi callyfor systems rated through27-kV, 630-A continuous and up to 16-kAinterrupting current. Trade-named the Viper-LT, the recloser works directly with Schweitzer’s SEL-651R recloser control.
The unit offers a variety of overhead and substation mounting frames, a single 32-pin interface control cable,phase-spacing options to accommodate up to four oil or solid dielectric PTs andcomplete site-ready confi gurations.
The Viper-LT incorporates integralcurrent and voltage sensors, permittingease of automation either now or forfuture requirements. Dead-line operation is also available. A trip/lockout handleand mechanical block feature prohibits remote close from the control or other remote source adding to operator safety.The Viper-LT and the SEL-651R are testedtogether as a system prior to shipment.G&W Electric | www.gwelec.com
93www.tdworld.comm | April 2012
PRODUCTS & SERVICES
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HELP WANTED
RECRUITING
U.S. based Substation & Transmission Line Design
Engineer - High-paying opportunities available now!
Contract and Permanent Placement openings
currently available at all levels.
To apply: visit careers at www.AbsoluteConsulting.com
or contact [email protected]
850-939-8965 ext. 160.
Absolute Consulting, Inc. is a premier provider of value added consulting and staffing services in the
energy industry.
SEL continues to grow!
Join an industry leader to develop and
manufacture products and solutions for the
protection, control, monitoring, and automation
of electric power systems worldwide.
Over 200 are positions available, including:
• Project Manager
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If you are looking for an exciting, rewarding, and
challenging career, your search ends here!
Visit our website at www.selinc.com/careers
SEL is an EEO/AA Employer. M/F/D/V encouraged to apply.
Listed in the 100 Best Companies to Work For
by FORTUNE® Magazine—2012
Need Help?Need A Job?Contact Lisa–
TOLL FREE 877-386-1091
pSe Habla Español
Electromechanical • ElectronicElectrical Service & Systems Specialists
LISA LINEAL: RecruitingLINEAL Services
Call or send confidential resume to
MORE THAN 25 YEARS EXPERIENCE!
Ray Dauria Associates RaRayay DaDauria Associates Dauauruririaia AsAssssosociatescciatesociciaiatateteses Specializing in recruiting for
HV Transmission Project Teams.
E-mail your resume to
[email protected] and visit
www.rdpowerjobs.com for information.
94 April 20122 | www.tdworld.com
SOFTWARE
HELP WANTED
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But be prepared to explain how you accomplished so muchwith so little time and effort.
Just tell them you got a little help from EasyPower: the fastest, easiest-to-use, most automatedpower system software available.
EasyPower automates everything:• One-line creation and templates • Full document set drawings• NEC code design • Arc flash calculations and analysis• Protective device coordination • IEEE-1584 & NFPA 70E compliance• ANSI and IEC solution standards • Seamless CAD output
Explore more online and download a free demo copy at www.easypower.com/demo
Enjoy your newfoundspare time.
Power System Software | Turn Days into Minutes
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CYME Power engineering analysis software
Solutions that stand behind thousands of T&D projects in more than 100 countries!<:(� �*HUHKH!����������������·�0U[LYUH[PVUHS!����������������·�PUMV'J`TL�JVT
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Power engineering services��ZWLJPHSPaLK�JVUZ\S[PUN�ZLY]PJLZ��YLSPHIPSP[`�PTWYV]LTLU[��+.�PU[LNYH[PVU��]VS[HNL�VW[PTPaH[PVU��OHYTVUPJZ
WorleyParsons is a dynamic international design and project services organization, providing engineering, procurement, and construction services through our 37,800 people across 44 countries.
Through a culture of empowerment and innovation, we offer a world of opportunities in Hydrocarbons, Infrastructure & Environment, Power, and Minerals & Metals.
Current full-time and contract/temporary opportunities include:
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WorleyParsons offers opportunities for accelerated career progression including advanced education, developmental assignments, opportunities for promotion, competitive compensation, great benefits, and an outstanding work environment.
www.worleyparsons.com/careers
Midwestern, Mid-Atlantic,New England, Eastern Canada:Stephen M. Lach
13723 Carolina Lane
Orland Park, IL 60462
Phone: 708-460-5925 Fax: 913-514-9017
E-mail: [email protected]
Southeastern, Mid-Atlantic,New England:Douglas J. Fix
590 Hickory Flat Road
Alpharetta, GA 30004
Phone: 770-740-2078 Fax: 770-740-1889
E-mail: [email protected]
Southwest:Gary Lindenberger
7007 Winding Walk Drive, Suite 100
Houston, TX 77095
Phone: 281-855-0470 Fax: 281-855-4219
E-mail: [email protected]
West/Western Canada:Ron Sweeney
303 Johnston Drive
San Rafael, CA 94903
Phone: 415-499-9095 Fax: 415-499-9096
E-mail: [email protected]
Craig Zehntner
15981 Yarnell Street, Suite 230
Los Angeles, CA 91342
Phone: 818-403-6379 Fax: 818-403-6436
E-mail: [email protected]
Western/Eastern Europe: Richard Woolley
P.O. Box 250
Banbury, OXON, OX16 5YJ UK
Phone: 44-1295-278-407
Fax: 44-1295-278-408
E-mail: [email protected]
Asia: Hazel Li
InterAct Media & Marketing
66 Tannery Lane
#04-01 Sindo Ind Building
Singapore 347805
Phone: 65-6728-2396
Fax: 65-6562-3375
E-mail:[email protected]
Japan: Yoshinori Ikeda
Akutagawa Bldg., 7-7,
Nihonbashi Kabutocho,
Chuo-ku, Tokyo 103-0026, Japan
Phone: 81-3-3661-6138
Fax: 81-3-3661-6139
E-mail: [email protected]
Korea: Y.B. Jeon
Storm Associates Inc.
4F. Deok Woo Building
292-7, Sung-san dong, Ma-po ku,
Seoul, Korea
Phone: 82-2-755-3774
Fax: 82-2-755-3776
E-mail:[email protected]
Classified Sales: Susan Schaefer
870 Wyndom Terrace
Secane, PA 19018
Phone: 484-478-0154
Fax: 913-514-6417
E-mail: [email protected]
Advertiser Page # Website
*Denotes ads appearing in only certain geographic areas.
Transmission & Distribution World (ISSN 1087-0849) is published once monthly by Penton Media Inc., 9800 Metcalf Ave., Overland Park, Kansasd
66212-2216 U.S. Periodicals postage paid at Shawnee Mission, Kansas, and additional mailing offices. Canadian Post Publications Mail Agreement No. 40612608. Canada return address: Pitney Bowes-International, P.O. Box 25542, London, ON N6C 6B2.
POSTMASTER: Send address changes to Transmission & Distribution World, P.O. Box 2100, Skokie, Illinois 60076-7800 U.S.RR
95www.tdworld.comm | April 2012
A. Eberle GMBH & Co. KG . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 84 www.a-eberie.de
AFL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 80I www.aflglobal.com
Alcan Cable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17 www.cable.alcan.com
American Electrical Testing Company . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 80E www.99aetco.com
Baur Pruf-und Messtechnik GMBH . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 88 www.baur.at
Black & Veatch . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11 www.bv.com
Bronto Skylift . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 80o www.bronto.fi
Burndy . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 54 www.burndy.com
Burns & McDonnell . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . IBC www.burnsmcd.com
CG Power Solutions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20A www.cgglobal.us
CG Power Solutions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20B www.cgglobal.com
Crux Subsurface Inc. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 76 www.cruxsub.com
Diversified Product Development . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 80W www.diversifiedproduct.com
Doble . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15 www.doble.com
Doubletree Systems/JSHP Transformer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 42 www.jshp.com
Dow Electrical & Telecommunications . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 63 www.dowinside.com
DuPont . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33 www.countondupont.com
EDM International Inc. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 56 www.edmlink.com
EEI . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 69 www.eei.org/2012
Efacec Power Transformers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 61 www.efaceusa.com.
ERLPhase Power Technologies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 50 www.erlphase.com
ET&D Strategic Partnership . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 66 www.powerlinesafety.org
Fluke Corporation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 47 www.fluke.com
FWT Inc. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 85 www.fwtinc.com
G&W Electric Co. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 71 www.gwelec.com
GE Digital Energy . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19 www.gedigitalenergy.com
Geodigital . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 83 www.geodigital.com
Greenlee Textron . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 80M www.greenleeutility.com
Grid One Solutions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 80U www.gridonesolutions.com
Grid Power Products . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 90 www.gridpowerproducts.com
High Voltage Inc. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31 www.hvinc.com
Hubbell Power Systems Inc. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Belly band www.hubbellpowersystems.com
Hubbell Power Systems Inc. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . IFC www.hubbellpowersystems.com
Hubbell Power Systems Inc. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 80G www.hubbellpowersystems.com
Hubbell Power Systems Inc. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 53 www.hubbellpowersystems.com
Hyundai Heavy Industries Co. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 57 www.hyundai-elec.com
Hyundai Ideal Electric Co. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 81 www.hyundai-elec.com
IEEE/PES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 65 www.ieeet-d.org
Krenz & Co. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .38-39 www.krenzvent.com
Lug-All Corp. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 80Q www.lug-all.com
Michels Corporation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 41 www.michels.us
Nesco Sales & Rentals . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14 www.nescosales.com
NLMCC/NECA-IBEW . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13 www.thequalityconnection.org
Nordic Fiberglass Inc. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 60 www.nordicfiberglass.com
Novatech . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 43 www.novatechweb.com
Oldcastle Precast . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35 www.oldcastleprecast.com
Omicron Electronics Corp. USA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25 www.omicronusa.com
Phenix Technologies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 68 www.phenixtech.com
Pike Energy Solutions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7 www.pike.com
Power Engineers Inc. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3 www.powereng.com
PowerSense A/S . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 73 www.sensethepower.com
Preformed Line Products Co. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 75 www.preformed.com
Quanta Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5 www.quantaservices.com
Remote Solutions LLC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 62 www.safe-t-rack.com
S&C Electric Co. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8-9 www.sandc.com
Sabre Industries . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 51 www.sabretubularstructures.com
Schweitzer Engineering Labs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 58 www.selinc.com
Schweitzer Engineering Labs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 77 www.selinc.com
Scott Powerline & Utility Equipment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 86 www.scottpowerline.com
Sensorlink . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21 www.sensorlink.com
Seves Canada Inc. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 55 www.sediver.fr
Sherman & Reilly Inc. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .80B-C www.sherman-reilly.com
Siemens AG . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 87 www.siemens.com
Siemens Energy Inc. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 www.usa.siemens.com
Southwire . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 23 www.southwire.com
T&D World Books . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 80 www.buypenton.com
T&D World Grid Optimization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 89 www.tdworld.com
Tait Radio . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6 www.taitradio.com
TDW Vegetation Management . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 91 www.tdworld.com/vegetationmanagement
Thomas & Betts Corp./Meyer Steel Structure . . . . . . . . . . . . . . . . . . . . . . . . . . . .26-27 www.tnb.com
Trachte . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 90 www.trachteusa.com
URMC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 59 www.utilityrisk.com
Utility Lines Construction Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . BC www.utiliconltd.com/ulcs
Valmont/Newmark . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 45A www.valmont-newmark.com
Valmont/Newmark . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 45B www.valmont-newmark.com
Williams Form Engineering . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 78 www.williamsform.com
ZTT International . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 70 www.zttcable.com
April 20122 | www.tdworld.com96
StraightTALK
Electronic Devices for HVDC
Ram Adapa ([email protected]) is a technical leader in the
transmission and substations area of the power delivery and
utilization sector of EPRI. He is a member of CIGRÉ, a registered
professional engineer and an IEEE fellow.
High-voltage direct-current (HVDC) transmission proj-
ects started more than 50 years ago in the electric
power industry. Initially, HVDC schemes used mer-
cury arc valves for switching, then the thyristor became pre-
dominant. Today, insulated gate bipolar transistors (IGBTs)
are used in voltage source converter technology.
Presently, semiconductor devices (thyristors and IGBTs) for
HVDC applications use silicon material. Silicon has remained
as the industry workhorse for power electronics applications
for more than five decades. However, silicon-based converters
have limitations:M Limited maximum blocking voltage, which requires se-
ries connection of many devices and multi-level convertersM Limited maximum switching frequency, which requires
large passive elements for filteringM Limited operating temperature, which requires signifi-
cant cooling.
A new set of materials known as wide bandgap semicon-
ductors are being developed to address the above limitations.
These wide bandgap materials include silicon carbide (SiC),
gallium nitride (GaN), aluminum nitride (AlN) and diamond,
though the most promising ones in the near future are SiC
and GaN. Wide bandgap materials have several advantages:M Wide bandgap and high thermal conductivity allow high-
temperature operation with reduced coolingM High saturation current velocity gives high current densityM High breakdown electric field increases maximum block-
ing voltage of devicesM High breakdown electric field and electron mobility give
lower specific resistance for a given blocking voltage.
Research is ongoing to develop high-voltage, high-current
and higher switching frequency power electronic devices us-
ing wide bandgap materials. This wide bandgap development
is at different stages depending on the material. SiC-based
high-power devices have the potential to demonstrate a much
higher level of efficiency than silicon devices because of their
much higher breakdown fields (more than 10 times) and ther-
mal conductivity (more than double). However, SiC is still lim-
ited somewhat by the associated control electronics. It can op-
erate up to and above 400°C (752°F), but the associated gate
dielectrics still decompose at ~200°C (392°F), and packaging
also has yet to match the high operating temperatures of SiC.
GaN has been used in a wide range of production LEDs
and semiconductor lasers, in part because of their direct
bandgap. GaN also has electrical and thermal properties that
match closely those of SiC. However, bulk GaN substrates have
not been successfully developed at a production scale like SiC.
A key component of modern high-efficiency, high-power de-
vices could be realized by the marriage of SiC base structures,
with epitaxially grown GaN gates for high-power, optically
controlled devices.
EPRI has conducted an industrywide survey to assess the
future technological developments in the materials for power
electronics applications. The figure shows the future voltage-
rating projections for different devices based on different ma-
terials from now through 2030. The maximum operating volt-
age of a silicon-based device may be around 10 kV until some
new breakthroughs in technology occur. Though SiC-based
devices can go up to 100 kV (10 times the silicon-based devic-
es) theoretically, for practical manufacturing limitations SiC
devices are projected to reach 60-kV levels by 2030. Though
GaN devices have more potential to reach higher voltages in
the long run, they are expected to reach 20-kV levels by 2030.
Similarly, the current ratings of wide bandgap materials will
also reach in the several kilo-amperes range in the future.
It is fair to say that wide bandgap materials can be oper-
ated at higher voltages, higher currents and higher tempera-
tures with lower switching losses compared to silicon, though
it has a long way to apply wide bandgap materials for HVDC
applications.
Projected voltage ratings of different power electronic devices basedon the different materials.
By B Ram Adapa, Electric Power Research Institute
Vo
ltag
e (kV
)
60
50
40
30
20
10
01960 1970 1980 1990 2000 2010 2020 2030
Years
GTO – Gate turn-off thyristor
LTT – Light-triggered thyristor
GCT – Gate-commutated thyristor
IGBT – Insulated gate bipolar transistor
FET – Field effect transistor
SiC – Silicon carbide
GaN – Gallium nitride
Silicon thyristor
Silicon IGBT
SiC IGBT
Silicon GTO
SiC thyristor/GTO
GaN FET
Silicon GCT
SiC
GaN
Silicon
2012 Game Changers Lineup
January: Sustainable Substations
March: 3-D Substation Design
April: Distributed Solar
April: Thermal Measurements on Lines
May: Plug-in Hybrid Electric Vehicle
Charging Stations
June: Grid Analytics
July: Smart Grid Communications
August: Enterprise Data Management
September: Standards and Interoperability
October: Marine Renewables
November: High-Voltage Direct Current
.
TECHNOLOGIES, STRATEGIES AND BIG IDEAS THAT ARE RESHAPING OUR WORLD
E n g i n e e r i n g , A r c h i t e c t u r e , C o n s t r u c t i o n , E n v i r o n m e n t a l a n d C o n s u l t i n g S o l u t i o n s
GAME CHANGERS 2.0
Burns & McDonnell and GE, in partnership with Transmission & Distribution
World, are hosting a series of webinars in 2012 exploring innovative
technologies and ideas that are changing how power is delivered and used.
This 11-part series kicked off in January and concludes next November.
Join Burns & McDonnell, GE and Southern California Edison on April 26 as
they introduce an online discussion exploring how large, intermediate and
small-scale solar photovoltaic rooftop installations are impacting electrical
distribution systems in Southern California. Please join us to learn about the
future of distributed solar systems.
GAME CHANGERS: Innovation Brought to Life
www.burnsmcd.com/td
Sponsored by Burns & McDonnell and GE
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APRIL 2012 A Supplement to Transmission & Distribution World Magazine
ABB Ltd
Power Systems and Power Products
P.O. Box 8131
8050 Zurich, Switzerland
Phone +41 (0)43 317 7111
Harnessing the power of wind ?
Naturally.
Renewable energy plays a vital role when it comes to balancing the need for more power
with minimum environmental impact. Addressing challenges like intermittent supply and
often connecting remote locations, ABB has integrated more than 200 gigawatts of hydro,
wind and solar power into the grid – enough electricity to serve the needs of nearly 70 million
people. ABB’s HVDC Light® technology plays a central role in enabling long-distance trans-
mission and cross-border grid connections, underground and underwater, to deliver reliable,
high-quality power supplies with minimal losses. ABB is uniquely positioned with technology
and competence across the value chain including manufacturing capability for converters,
high power semiconductors and high voltages cables. For more information please visit us
at www.abb.com/hvdc
www.tdworld.com
Transmission & Distribution World l April 2012 1
TM
David Miller, Publisher [email protected]
Rick Bush, Editorial Director [email protected]
Vito Longo, Technology Editor [email protected]
Emily Saarela, Senior Managing Editor [email protected]
Gerry George, International Editor [email protected]
Gene Wolf, Technical Writer [email protected]
Susan Lakin, Art Director [email protected]
Julie Gilpin, Ad Production Manager [email protected]
Sonja Trent, Marketing Campaign Manager [email protected]
Steve Lach, Midwestern, Mid-Atlantic, New England, Eastern Canada
Doug Fix, Southeastern, Mid-Atlantic, New England dfi [email protected]
Gary Lindenberger, Southwest [email protected]
Ron Sweeney, West/Western Canada [email protected]
Craig Zehntner, West/Western Canada [email protected]
Richard Woolley, Western/Eastern Europe [email protected]
Yoshinori Ikeda, Japan [email protected]
Y.B. Jeon, Korea [email protected]
Hazel Li, Asia [email protected]
Copyright 2012 Penton Media Inc. All rights reserved.
HVDC Reaches Critical Mass
Rick Bush, Editorial Director
Over the past 10 years, the editors at Transmission &
Distribution World have found that coverage of tech-
nical issues sometimes requires a “critical mass” of
information and insights to kick-start engineers and engineer-
ing managers to grasp the entirety of the topic and, only then,
to take a giant leap forward.
One of the best ways we’ve found to do this is to produce
comprehensive supplements on these critical topics. Last year,
for example, we produced our Big Solar, Big Wind supplement,
in which we shared with utilities how worldwide renewables
initiatives require massive investment in T&D infrastructure.
This effort required us to muse what our future grids will
look like if they are reshaped to handle these signifi cant yet in-
termittent resources. Then, after this supplement came out, we
experienced the meltdown of the Fukushima Daiichi Nuclear
Plant, combined with unremitting societal pressure against
greenhouse-emitting coal-fi red plants, making it increasingly
clear we need a bulk power system with more fl exibility and
more capacity than ever before.
Our technical writer (and former IEEE T&D committee
chairman) Gene Wolf and I reached out to our peers to see what
they thought the power system of the future might look like.
Gene had been the engineer of record for an HVDC back-to-
back intertie when he worked at Public Service Company of
New Mexico, so naturally, we took a long hard look at HVDC.
As I am sure you are aware, HVDC is fi nding increasing
uses both overhead and underground, but it is not limited to-
day to interties or point-to-point links. In Europe, for example,
efforts are underway to build out an HVDC grid to bring off-
shore Baltic wind to load centers.
After months of research and more than a little head-
scratching, Gene and I are thrilled to bring you this supple-
ment on the past, present and future of HVDC. We decided to
focus this supplement on the advancement of the technology,
rather than on case studies, which we already cover in regular
issues of the magazine.
The supplement’s content was selected and provided solely
by T&D World editors. However, we would like to acknowl-
edge ABB for its sponsorship, which provided us the oppor-
tunity and the fl exibility to share the future of HVDC on an
integrated bulk power system.
As we worked to get our arms around the future of HVDC,
Gene and I came to the realization that we are reaching an
infl ection point. The promise of HVDC is fast becoming a re-
ality as the technology and business drivers push us toward
critical mass.
Table of ContentsA World of Knowledge
By Gene Wolf, Technical Writer . . . . . . . . . . . . . . Page 2
HVDC: A Revolution Ahead By Ronnie Belmans, K.U. Leuven . . . . . . . . . . . . . Page 3
War of the Currents — An UpdateBy Gene Wolf, Technical Writer
For a technology many considered obsolete, dc continues
to grow, expand and improve the grid. . . . . . . . . . . . . Page 4
Renovating the Grid for the 21st CenturyBy Gene Wolf, Technical Writer
Remote renewable generation, deregulation and
environmental concerns are the drivers reshaping
the transmission grid. . . . . . . . . . . . . . . . . . . . . . . . Page 10
Connecting the Dots By Gene Wolf, Technical Writer
The grid is being hybridized into an ac-dc network
that is more fl exible, accessible and reliable. . . . . . . . . . Page 14
The Evolution of HVDC TransmissionBy Narain Hingorani, Consultant . . . . . . . . . . . . Page 20
www.tdworld.com
2 April 2012 l Transmission & Distribution World
Part of the fun of being a consulting engi-
neer is never knowing what adventure the
next phone call will bring. The past year
has brought me a variety of assignments, from
wind farm substations to life-extension inves-
tigations of HVDC converter stations, but none
of that prepared me for a call from Rick Bush.
It was another of his famous “pack your bags”
announcements.
The last time this type of request came, I
found myself in the middle of the restoration
effort for Hurricane Ike in south Texas. Don’t
get me wrong, that trip was very rewarding, but it was also
extremely challenging.
This time the fi ckle fi nger of fate was extremely kind.
As T&D World’s technical writer, Rick wanted me to head
off to Europe and explore the latest developments in HVDC
technology. I have been involved with HVDC for more than
30 years, including serving as the chairman of the IEEE PES
HVDC & FACTS subcommittee and building a back-to-back
converter station, so this seemed like a natural assignment for
me to tackle.
Like many assignments, this one evolved from a series of
previous assignments. A few years ago, Rick and I started
exploring the subject of renewable energy, which produced a
supplement about connecting renewables to the grid (March
2009). We had no idea how this subject would lead us into so
many other areas of technologies that seemed unrelated at fi rst
glance.
The renewables supplement pointed out that wind and so-
lar generation needed some form of energy storage, which
we shared in a second supplement on energy storage (August
2009). This led to a third supplement. Someone had the idea
that if a wind farm was geographically huge, the wind had to
be blowing somewhere along the array, which would make the
resource more dependable (March 2011).
This spawned the latest supplement. Enormously large
wind farms are remote, but bringing their power to the load
centers is a huge challenge, which has attracted a great deal of
attention in the new “old” technology of HVDC.
I say it is a new “old” technology because it has been part
of the electric utility industry for an extremely long time. The
fi rst modern HVDC transmission link dates back to 1954
with ASEA’s connection between the Swedish mainland and
Gotland Island. Strangely, there are many unaware of the role
HVDC technology has been playing in our industry.
Where once it was thought of as a niche market, HVDC has
become a major integrated part of the grid. Granted, in some
parts of the world it is playing a lesser role than in other parts,
but that is changing. As engineers understand the technology
A World of KnowledgeBy Gene Wolf, Technical Writer
better, they fi nd applications that will improve
their systems. And that is why I traveled to the
epicenter of HVDC activity — Europe — to
see what is happening.
Wow, What an Opportunity My trip stared out in Zurich then moved on
to Sweden, which was followed by a stop in
Tallinn, Estonia. I fi nally said auf wiedersehen
to Europe when I hit Germany. In a week, I
had covered way too miles and spent every
night in a different hotel, but I touched the
pulse of the technology.
The result of this hectic pace was a series of meetings with
engineers, scientists and executives — all HVDC experts. You
might say it was a deep immersion into a multifaceted subject.
To borrow from a favorite poem: Thyristors to the left of me,
multiple-level converters to the right of me, dc circuit breakers
in front of me, dc simulation center behind me.
In my mind, it was the equivalent of being sent to an
HVDC Disneyland, which way over stimulated the nerd
HVDC engineer in me.
The Human Touch I can’t think of a better way to spend an afternoon than
sitting with the manager of an R&D department discussing
the future direction of HVDC technology over endless cups of
coffee. Unless, of course, it is being able to travel from city to
city, meeting the folks responsible for manufacturing equip-
ment, designing converter stations and seeing actual HVDC
facilities.
My trip made it possible for me to meet the people behind
so much of the development taking place in this mind-blowing
technology. It was great seeing and touching the hardware, but
talking with the people responsible for R&D defi ned the hu-
man interface of the technological challenge.
It also pointed out the differences in global philosophies.
There are places in this world where their attitude places no
limits on HVDC applications. As a result there are ±800-kV
systems with ±1,100-kV and ±1,200-kV UHVDC in develop-
ment. Others see HVDC as a technology that will allow a more
stable grid and access to remote renewables. Some approach
HVDC as a niche market of limited capability, and they are
waiting for the technology to develop. It all depends on your
perspective and knowledge.
As it turned out, this trip was reminiscence of Hurricane
Ike: challenging and rewarding. It also reminded me of the
movie If It’s Tuesday, This Must Be Belgium. I can’t wait for
that next phone call: Where will it send me? What will I learn?
Who will I meet? The adventure continues.
www.tdworld.com
Transmission & Distribution World l April 2012 3
HVDC: A Revolution Ahead
Ronnie Belmans is a professor with the K.U. Leuven,
teaching electric power and energy systems. His re-
search interests include techno-economic aspects of
power systems, power quality and distributed genera-
tion. Belman is hononary chairman of the board of
directors of ELIA, the Belgian transmission grid operator.
By Ronnie Belmans, K.U. Leuven
The power engineering industry is fac-
ing tremendous challenges worldwide.
Countries such as China, Brazil and
India have experienced a massive demand
increase, which needs to be covered; North
America is seeking a more reliable energy sys-
tem; and in Europe, we are predominantly look-
ing for a more sustainable energy supply, based
on liberalized market principles. This editorial
will focus on the developments in Europe.
The European power system is operated ever
closer to its limits. Links between countries are
now serving the liberalized electricity market,
whereas they have only been developed in the
past to help neighboring countries. Investments are heavily
needed, whilst transmission system operators are facing an
increasing opposition when it comes to the construction of
new overhead lines.
The drastic need for transmission system upgrades and the
inability to upgrade the European electricity system in past
years using traditional solutions is well demonstrated when
one observes the evolution of the so-called TEN-E priority
development plans.
The TEN-E plans have been pinpointing the missing links
that had been recognized as being important for Europe and the
European electricity market in the long run. Most of these pri-
oritized links kept popping up whenever the TEN-E brochure
was updated, meaning that those heavily needed links were
still missing and, unfortunately, not too much had changed.
The new infrastructure package, “Energy Infrastructure
Priorities for 2020 and Beyond,” provides a blueprint to tackle
the challenges in a coherent way.
The Future Will Be Ever-More ChallengingThe ambitious 20-20-20 targets of the European Union —
aiming to increase the share of renewable energy sources in
the overall energy mix to 20%, cut greenhouse-gas emissions
by 20% and increase the energy effi ciency by 20% in the year
2020 — will defi nitely be refl ected in the way the European
energy system will evolve in the years to come.
Nowadays, we are talking about a massive integration
of intermittent renewable energy sources such as wind and
solar, with part of the wind energy coming from offshore wind
energy. Germany alone has an installed capacity of more than
40 GW in wind and solar combined.
It has become more and more apparent to the power engi-
neering community that a real change of paradigm is needed
in order to make the step forward that policy makers would
like. This is well refl ected by the smart grid initiatives popping
up all around the world, as well as the plans that have been
put forward by different institutions and groups
to construct offshore grids interconnecting the
wind farms to be built, or even a new overlay
grid, both onshore and offshore, as a backbone
structure for the European power system.
Industry is ChangingBut while rethinking the power system, our
community is faced with the same challenges
when it comes to social acceptance as a de-
cade ago. Therefore, opportunities have to be
discussed to tackle those issues: What about a
change on the technology front?
It’s no secret that the power engineering
community has primarily been thinking in terms of ac over-
head lines as the standard solution, because this is what we
have been taught to do. The industry still is very much con-
centrated on ac technology (high-voltage lines, switchgear,
transformers, etc.). The material has been optimized over the
years, with improved effi ciency, lower prices and increased
reliability and lifetime.
European companies have invested massively in the de-
velopment of HVDC during the last years, and although the
turnover in dc applications is still low, compared to ac in-
stallations, the growth is immense. New challenges such as
deep offshore wind parks, interconnecting of asynchronous
ac zones, and the development of the dc grid overlay of the
existing 400-kV ac grid are being addressed.
Voltage source converter HVDC is seen as one of the key
enabling technologies in developing the renewable energy sec-
tor in Europe and as the prime candidate for a new European
overlay grid or “super grid.”
European players are making investments in new manu-
facturing units with the aim of increasing the capacity for
cables and high-rated power electronic components. New sys-
tems are becoming ready for the market, such as dc current
breakers. Others are still on the drawing board, such as fl ow-
control devices for meshed dc grids. SCADA systems have to
be developed to operate with these new devices.
The step is use, the investments in the grid are massive, but
it is clear “no grid, no party.” If we will not be able to deploy
the new grid, the party to celebrate the future CO2-free elec-
tric energy system will not take place.
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April 2012 l Transmission & Distribution World4
War of the Currents
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Transmission & Distribution World l April 2012 5
The VSC valve is the latest development in HVDC technology. Courtesy of ABB.
– An Update
For a technology many considered
obsolete, dc continues to grow,
expand and improve the grid.
By Gene Wolf, Technical Writer
Sometimes technological advancement is not about a new discovery,
it is about steady progress, hard work and improvement of existing
technologies. Although direct current (dc) and alternating current (ac)
started out as competing technologies, they are really complementary
technologies; unfortunately, many still do not recognize this fact.
Strangely, early accounts of these technologies sounded more like something
from a Harry Potter movie than the start-up of the electric industry. It was an epic
battle between two wizards for dominance — the Wizard of Menlo Park (Thomas
Edison’s dc) and the Wizard of the West (Nikola Tesla’s ac). The clash even had
Edison staging the electrocution of an elephant to show how dangerous ac was
compared with dc, which brought about the electric chair as a new form of capital
punishment.
Timing is Everything The fi rst commercial dynamo, the dc generator became available about the
same time Edison invented the lightbulb, which proved to be fortunate since the
newfangled lightbulb worked fi ne with electricity of the dc variety. As a result,
In 1890, the dc system required wires for each voltage level, making the city streets look like a spider’s web of wires. Courtesy of Georgia Power Co.
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April 2012 l Transmission & Distribution World6
the dynamo, but he also presented Edison
with some innovative ideas based on the
new ac technology. Needless to say, Edison
was less than enthusiastic about ac and Te-
sla; he was too vested in dc technology.
The wizards parted company less than
amicably and became pitted against each
other for dominance. Once Tesla was on
his own, he designed a complete ac sys-
tem. He was awarded seven U.S. patents
for polyphase ac motors and power trans-
mission equipment. It was around the same
time that George Westinghouse entered the
battle. He believed in the new ac technolo-
gy and struck a deal with Tesla to purchase
his patents. The “War of the Currents,” as
historians call it, was under way.
It is Economics
Calling it a “war” may be a little fanciful but representa-
tive of the idea. A great deal of turmoil existed until the West-
inghouse-Tesla ac system was selected to illuminate the 1893
Chicago World’s Fair. Tesla’s polyphase system of ac power
generation and transmission system was about half the price of
the dc system and required far less infrastructure.
From that point forward, more than 80% of the electri-
Advancements in HVDC technology require many hours of testing before the equipment can be deployed to the fi eld. Courtesy of ABB.
In 1893, ac and dc competed for the privilege of illuminating the Chicago World’s Fair. The Westinghouse-Tesla ac system won. Courtesy of Brooklyn Museum
Archives, Goodyear Archival Collection.
Edison invented or improved a lot of devices needed for the
early dc electric system, earning him many patents on dc
equipment. Within a short time, there were more than 200
electric utilities in North America with dc systems, and they
were all paying patent royalties to Edison.
With the growth of his electrical empire, Edison hired a
young engineer from Europe, Nikola Tesla, to improve the
equipment used in the dc distribution systems. Tesla improved
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Transmission & Distribution World l April 2012 7
cal devices ordered in the United States were for ac voltages.
While ac technology became the preferred method of power
transmission throughout the world, dc technology was never
entirely defeated in this battle of currents. From the start, en-
gineers recognized ac and dc were complementary rather than
competing technologies, but a great deal of work was needed.
Research and Development Before dc could be a truly complementary technology, it
had to be compatible with ac. The advocates of dc technology
knew the best way to make dc successful was to make it an
integral part of the ac grid. A great deal of research took place,
and probably the biggest breakthrough came when Dr. Uno
Lamm and a group of ASEA (now ABB) engineers developed
the low-pressure mercury arc valve (valve referring to early-
day vacuum tubes).
The mercury arc valve brought about high-voltage direct-
current (HVDC) applications. It was used for the effi cient con-
version of ac to dc and then back to ac again. Power could be
transmitted at high dc voltages and then converted to ac voltag-
es, allowing utilities to meet customers’ lower-voltage needs.
ASEA combined the mercury arc valve and submarine
cables to connect the Swedish mainland with Gotland Island,
making it the fi rst comprehensive application of this technol-
ogy. The distance was about 60 miles (97 km), which was too
far for an ac cable transmission
but perfect for HVDC. The inter-
connection had an initial capacity
of 20 MW. From that point, the
mercury arc valve became the
workhorse of HVDC transmis-
sion (from the mid-1950s until the
late 1970s).
Utilities saw the advantages
this new type of transmission of-
fered the industry, but they want-
ed a competitive marketplace.
ASEA saw the wisdom of com-
petition and developed licensing
agreements with other manufac-
turers of dc equipment. From this
start, a new technology became a
business.
Solid State In the mid-1950s, German
scientists at Siemens developed
the monocrystalline silicon semi-
conductor. A short time later, a
sample of this material made its
way across the Atlantic to GE’s
research laboratories where en-
gineers began tinkering with it.
The result of that tinkering was
the thyristor, a bipolar semicon-
ductor switching device that only
conducts current from anode to cathode. In effect, a thyristor
valve is a controllable unidirectional (diode-like) switch. This
made it possible to build the silicon-controlled rectifi er, and
thus, solid-state power electronics was born.
The world’s fi rst commercial mercury arc valve at Gotland Island in 1954. Courtesy of ABB.
Classic HVDC converter valve hall using light-triggered thyristor valves. Courtesy of Siemens.
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April 2012 l Transmission & Distribution World8
Just as the semiconductor impacted electronics, the thyris-
tor did the same for HVDC. Mercury arc valves were fi nicky
and massively complicated pieces of machinery. They required
a great deal of maintenance to keep them operational. With
the advent of the thyristor valve, things became simpler and
HVDC schemes increased signifi cantly throughout the world.
But, once again, utilities wanted competition, so GE licensed
the thyristor technology to others.
The fi rst application of thyristor valves took place at
Gotland with ASEA adding a 10-MW thyristor-based con-
verter group to the Gotland link. This was followed by GE’s
320-MW Eel River Converter Station, which was the fi rst all
solid-state converter system in operation.
HVDC BasicsBefore going any further, it is important to review HVDC
technology. Simply put, ac power is fed into what is referred to
as a converter. It is a rectifi er that changes the ac to dc, hence
the name converter.
The dc power is transmitted through a conductor, cable or
busbar to a second converter. This converter is operating as an
inverter with an output of ac power. The ac power matches the
frequency and phasing of the receiving system.
Without going into a great deal of detail, there are three
basic confi gurations, or schemes, for HVDC converters:
● Monopolar
● Bipolar
● Back to back.
The monopolar HVDC system generally consists of one
or more three-phase, full-wave bridges, known as six-pulse or
Graetz bridges, at each end. Power is transferred by one con-
ductor and returns through the earth.
The bipolar confi guration is a combination of two monopo-
lar systems. The poles are made up of one or more 12-pulse
bridges in series or parallel. This scheme can be found with a
ground return, a dedicated metallic return or without a dedi-
cated return path used for monopolar operation.
The back-to-back converter is a special adaptation of mo-
nopolar interconnections without the dc transmission. Both
the rectifi er and the inverter are located in the same station and
are connected with busbar. These schemes are mainly used for
power transmission between two asynchronous ac grids.
Advantages vs. DisadvantagesBecause of the availability of the ac power transformer,
ac quickly became the preferred method of power transmis-
sion. The transformer permitted power to be generated at low
voltages, stepped up to higher voltages for transmission and
stepped down to lower voltages again for the customer’s use,
but that dominance carried a price.
Unfortunately, ac has some inherent challenges that are
substantial issues for today’s grid. The reactive elements (in-
ductance and capacitance) found in overhead lines and cables
place limitations on transmission capacity and distance. They
also may require additional equipment on the line for compen-
sation such as series capacitors or shunt reactors.
All too often, connecting several ac systems can be prob-
lematic. There can be frequency differences between ac
systems along with phasing concerns. Even linking two ac
systems with the same frequency can bring about problems
Offshore wind farms are growing in size and increasing in distance from shore thanks to advancements in submarine cable and HVDC technology used on collector systems and connections to shore-based grids. Courtesy of ABB.
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9Transmission & Distribution World l April 2012
due to system instability, increasing short-circuit
levels and undesirable power-fl ow scenarios.
HVDC addresses these issues and offers sev-
eral additional advantages. Power transfers can be
controlled and measured precisely. Being able to
control the power fl ow is a huge advantage. Trans-
mission congestion can be ignored by being able
to direct exactly where the power is injected into
the ac grid.
Another consideration is the effect of the
HVDC link on power quality. Since HVDC links
have the ability to control the ac output voltage and
frequency, they can improve the power quality of
the ac grid to which they are connected. This also
reduces the phenomena known as fl icker, which
can impact lighting systems and cause thermal
losses in electronic and electrical equipment.
Another evolving HVDC application is the multitermi-
nal system. They are more complex than the point-to-point
system, but they are gaining a lot of interest as dc schemes
become more numerous. The world’s fi rst multiterminal sys-
tem was built between 1987 and 1992 with line-commutated
converter (LCC) technology for Hydro-Québec and National
Grid USA (formerly New England Electric Systems). It is a
2,000-MW transmission system that originally had fi ve termi-
nals connecting load centers in Canada and the United States
(New England).
Green Advantages Environmentally, HVDC offers a much smaller footprint
for transmission rights-of-way, which means less land is
required, less disturbance and less right-of-way maintenance.
Of course, the converters require land, but an HVDC trans-
mission line carries a great deal more power than an ac line.
A typical 6,000-MW transmission link would need seven
power lines to carry the power if the ac voltage level was
500-kV. That same amount of power would require two
600-kV dc transmission lines or one 800-kV dc transmission
line, which is a substantial savings of right-of-way. In addition,
magnetic fi elds from HVDC transmission lines are negligible
in comparison to corresponding magnetic fi elds for ac lines.
HVDC Station Designs Several topologies are available for HVDC links today, but
the two most prevalent are the LCC and the self-commutated
voltage source converter (VSC). The LCC is considered the
classic design, using thyristors for its valve design.
The valves are the 12-pulse design with voltage being con-
trolled from maximum positive to maximum negative and
unidirectional current (current fl ows in one direction no mat-
ter the direction of the power fl ow). Unfortunately, LCCs con-
sume but cannot supply reactive power.
This design also produces harmonic distortions and re-
quires harmonic fi lters. In addition, the LCC requires special
converter transformers with more robust insulation to handle
the dc currents found in the scheme. The LCC’s major advan-
Companies mentioned:ABB | www.abb.com
GE | www.ge.com
Hydro-Québec | www.hydroquebec.com
National Grid US | www.nationalgridus.com
Siemens | www.siemens.com
tage is its ability to operate at extremely high power levels for
effi cient cross-country transmission.
On the other hand, VSCs use insulated-gate bipolar transis-
tor technology for valve designs. These two technologies are
very similar, but the VSC is considered to be more fl exible
than the LCC. One major advantage of the VSC technology is
the fact that, with gate turn-off properties, the VSC schemes
can supply reactive power and it is much simpler to change
power fl ow direction. Since they do not require any driving
system voltage, they have black-start capability.
ABB developed the VSC technology in the 1990s. The fi rst
VSC transmission system was commissioned in 1999 con-
necting a wind farm on the south end of the Gotland Island to
the city of Visby. This was followed by the 36-MW Eagle Pass
VSC back-to-back scheme connecting Mexico and the United
States (Electric Reliability Council of Texas).
The Expanding Presence of HVDCFrom its earliest days, HVDC technology has stirred de-
bates as to its role in the grid. From the historical perspective,
dc has had an interesting function. It went from dominance to
dormancy to ascendancy.
HVDC may have been the fi rst type of transmission system,
but it was replaced by ac technology and interest in it waned.
In recent years, however, there have been great advancements
in the technology, sparking more interest and awareness. The
technology is now at a point where it is capable of making
signifi cant contributions as understanding of its potential
increases.
Moreover, several new market developments, like integra-
tion of renewables, interconnectors and long-distance trans-
mission, lend themselves to HVDC technology.
HVDC converter station with components identifi ed. Courtesy of ABB.
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10 April 2012 l Transmission & Distribution World
Renovating the Grid For the 21st CenturyRemote renewable generation, deregulation and
environmental concerns are the drivers reshaping
the transmission grid.
By Gene Wolf, Technical Writer
So many old ideas are becoming new again. This
is a phenomenon that takes place over and over
again as technology advances and matures. Think
about renewable energy. Using wind power to pro-
duce electricity actually dates back to 1888. Solar,
hydrogenation and geothermal have all been around for a long
time, but they were not practical, feasible or economical until
technological breakthroughs made them that way.
Wind turbines are a good example. There was a 1.25-MW
wind turbine in the early 1940s, but the blades broke off the
hub after only a few hundred hours of operation. The technol-
ogy was not there yet. After countless hours of fi ddling with
materials and other technologies, 10-MW turbines now exist.
And mega wind farms are on the drawing boards with ratings
of thousands of megawatts (T&D World, March 2011).
Unfortunately, the best locations for renewable energy gen-
eration seem to be extremely remote or far offshore from load
centers. Transmission resources may not be available or they are
challenged by the present alternating-current (ac) technology.
Strangely, the solution to this challenge brings the electric
utility industry back full circle to the beginning of its exis-
tence. The industry’s founding fathers, Thomas Edison and
Nikola Tesla, tussled over a direct-current (dc) grid or an ac
grid, with ac proving to be more adaptable.
A hundred years later, dc has become a stabilizing infl u-
ence as high-voltage direct-current (HVDC) is integrated into
ac grids worldwide. It comes in two basic forms: the classic
HVDC technology, known as the line-commutated converter
(LCC), and the voltage source converter (VSC) technology.
These advancements are proving to be a powerful force prom-
ising to reshape grids worldwide.
Global VisionCombining LCC with VSC fl exibility is a huge plus for in-
tegrating dc into the ac grid. These HVDC schemes are giving
the old idea of a multinational electric grid, connecting coun-
tries and continents to each other, new life. These multination-
al grids have been called super grids, mega grids, electricity
highways and even the global grid.
Regardless of what we call these transmission grid con-
fi gurations, the goal is the same: to move tremendously large
blocks of power over extreme distances, increasing access to
electricity worldwide. R. Buckminster Fuller talked about the
world having a global grid for electricity in the early 1970s. He
envisioned an intercontinental electrical network, integrating
all the continents into an interconnected global network.
With grid interconnections, it is sometimes diffi cult, if
not impossible, to connect two ac networks. High-voltage ac
networks have challenges such as stability, congestion and
frequency shifts.
Even in highly developed parts of the world, the complex-
ity of operating transmission systems is a challenge. Europe’s
huge European Network of Transmission System Operators for
Electricity (ENTSO-E) system extends to Africa by a link be-
tween Gibraltar and Ceuta. Even networks with the same nom-
inal frequency have some slight variation, normally less than
±0.1 Hz, which challenges high-voltage ac interconnections.
There are also networks with both 50-Hz and 60-Hz fre-
quencies within close proximity (for example, South America
and Japan) of each other. In the United States, the eastern and
western power systems are both 60-Hz networks, but they are
not synchronized with each other.
Global-Scale Power GridsBecause of diffi culties such as these, there is increasing
interest in HVDC bulk transmission, ac-dc grid interconnec-
tions, asynchronous connections and dc networks. VSC tech-
nology continues to advance as insulated-gate bipolar transis-
tors (IGBTs) increase in power ratings. These higher voltage
and current ratings give utilities even more options and appli-
cations for renovating their transmission grids.
Reliable bulk-power transmission plays a key role in
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Transmission & Distribution World l April 2012 11
today’s power system, but high-voltage ac needs reinforce-
ments to get the job done. China, India, Africa and South
America are leading the world in this area. They are rich in
renewable resources, having some of the largest hydropower
resources in the world. Unfortunately, the load centers are re-
mote, as far as thousands of kilometers from those resources
or any type of transmission facilities, but these countries are
doing something about it.
China
In China, ±500-kV and ±600-kV systems are fairly com-
mon, and now ±800-kV systems are having a big impact.
China has huge renewable resources (that is, hydropower gen-
eration) located on the western side of the country. Its load
centers are located on the eastern side of the country, and they
are huge, too.
At the Electric Power Research Institute’s 2011 HVDC con-
ference, the State Grid Corporation of China (SGCC) made
several presentations on the HVDC activity taking place on
its grid. SGCC reported, “China is constructing a power high-
way. Ultrahigh-voltage direct-current (UHVDC) is one of the
key technologies to meet these requirements.”
UHVDC projects have pushed the HVDC solution provid-
ers as well as the boundaries on voltage levels. By the end of
2010, there were two ±800-kV projects in service on the SGCC
network. The 2,000-km (1,243-mile), 7,200-MW Xiangjiaba-
Shanghai transmission line was the
world’s fi rst UHVDC scheme in
commercial operation, transmit-
ting clean hydropower to Shanghai
to about 24 million people. The
1,450-km (901-mile), 5,000-MW
Yunnan-Guangdong transmission
line was also placed in service that
year.
SGCC also has plans for two
more ±800-kV projects and the fi rst
±1,100-kV project. The new ±800-
kV projects are the Xiluodu-Zhexi
line and the Hami-Zhengzhou
line. The ±1,100-kV project is the
Zhundong-Chengdu line. In all,
SGCC announced it will build 11 UHVDC projects in the next
fi ve years with a combined transmission capacity of roughly
88,000 MW and a total combined distance of approximately
40,000 km (24,855 miles).
India
China is not the only country using UHVDC technology.
Powergrid Corporation of India Ltd. has begun an 8,000-MW,
±800-kV North-East Agra UHVDC project through India’s
famous Chicken’s Neck area, the Siliguri Corridor, a narrow
strip of land between Nepal and Bangladesh.
India plans to create power pooling points (multiple termi-
nals) in the northeastern region, collecting power from sev-
eral hydropower stations and using LCC technology (±800-kV
UHVDC bipolar lines) to transport it to major load centers.
The fi rst phase of that plan is the North-East Agra project.
The transmission line will run about 1,728 km (1,074 miles).
This will be one of the largest UHVDC transmission projects
built and is expected to be in service by 2015. It is estimated
this 8,000-MW project will be capable of meeting the electri-
cal needs of approximately 90 million people.
South America
In South America, Brazil gets roughly 95% of its genera-
tion from hydropower and is very interested in integrating
high-voltage ac with HVDC to bring these remote resources
The ±800-kV UHVDC sending station Fulong of the Xiangjiaba-Shanghai project in China.Courtesy of ABB and State Grid Corporation in China.
The ±800-kV UHVDC Yunnan-Guangdong facility. Courtesy of Siemens.
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12 April 2012 l Transmission & Distribution World
to its load centers. Brazil is certainly no stranger to HVDC
projects. Its Itaipu project set a few records in its day, but cur-
rent plans will dwarf those.
The fi rst stage is the Rio Madeira project, which includes
three stations and the longest HVDC transmission line to date,
approximately 2,500 km (1,553 miles). It is a fl exible, long-
haul transmission scheme combining an HVDC LCC point-
to-point design with a VSC back-to-back converter element.
The LCC portion is a ±600-kV project rated at 3,150 MW,
which connects the hydropower stations located near Porto
Velho with the Sao Paulo load center. The VSC portion is an
800-MW back-to-back converter station considered to be a
fl exible connection for the high-voltage ac system in north-
western Brazil.
AfricaAfrica is the second-largest continent in the world, but the
majority of the population living there has little to no access to
electricity; no wonder it is called the Dark Continent. But that
is changing, thanks to a number of HVDC projects in plan-
ning, several under construction and a few in operation.
Africa also is the home of the Inga dams located on the
Congo River at the Inga Falls, the largest waterfalls in the
world. Inga I and II have an installed capacity of 1,775 MW,
with plans to refurbish the dams. There are proposals to add
Inga III and Grand Inga, two massive hydropower plants —
4,500 MW and 39,000 MW, respectively — to the facilities.
NamPower’s 300-MW, ±350-kV Caprivi Link Intercon-
nector project connects Namibia and Zambezi. It was commis-
sioned in 2010, but what makes it unique is that two very weak
ac networks are connected with a 950-km (590-mile) overhead
line between two VSC stations. (Yes, that is correct, an over-
head transmission line connecting two VSC stations!) Previ-
ously, VSC technology was limited to underground/submarine
cables, but technology moves on, and this project proved VSCs
can be used with both cable and overhead connections.
EuropeMoving thousands of megawatts great distances to load
centers with tens of millions of customers fi ts well in the
framework of China, India and other huge markets, but that
enormity does not fi t the scale of most of the world’s networks.
Consider the grids in North America or Europe; they
are not built to handle a transmission line with that
amount of power. A 5,000-MW bump on the Eastern
U.S. grid would create huge problems; in the West-
ern U.S. grid it would be overwhelming, and in the
Electric Reliability Council of Texas grid, it would
be catastrophic.
The European Union has plans for a different
type of HVDC scheme using HVDC transmission
technology (LCC and VSC) to build an interregional
HVDC grid. This makes sense for the established
networks of Europe, which include one grid in West-
ern Europe, one in Eastern Europe and one in the
Nordic countries. Then add the islands of Great Brit-
ain, Iceland, Ireland, Sardinia, Corsica, Crete and others; they
all have their own grids and no ac connections to the European
continent.
Regional HVDCThe European Union recognizes its network needs more
fl exibility and intelligence with the ability for long-haul trans-
mission, too. It also recognizes the need for sharing resources,
making interconnections, integrating renewables and phasing
out nuclear generation in some countries.
As a result, regional HVDC links are being built right
now with many in service using both classic (LCC) and VSC
technology. These regional applications consist of submarine
HVDC cable connections between grids, such as the 2006
Estlink link between Finland and Estonia. It is a 350-MW,
±150-kV VSC underground/submarine cable interconnection
bringing hydropower from Finland to Estonia. A second cable
link, Estlink 2, recently started construction using LCC tech-
nology (rated at 650 MW and ±450 kV) and is scheduled for
completion in 2014.
Another dc element is the Fenno-Skan link connecting
Sweden and Finland through classic HVDC with an under-
ground/submarine cable. It is comprised of two stages. Fenno-
Skan 1 is a 500-MW, ±400-kV link that has been in service
since 1989. The second link, Fenno-Skan 2, was completed in
December 2011, rated at 800 MW and ±500 kV.
Adding to the interconnections is the NordBalt project us-
ing VSC technology with an HVDC cable connection between
The Caprivi Link Interconnector, connecting electricity grids in Namibia and Zambia, is the world’s fi rst VSC application using overhead trans-mission instead of underground cable. Courtesy of ABB.
Placement of submarine cable requires careful handling, complex equipment and a skilled workforce. Courtesy of ABB.
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13Transmission & Distribution World l April 2012
Sweden and Lithuania. It is rated at 700 MW and ±300 kV.
This system is expected to be commissioned in 2016.
HVDC is Offshore, TooRegional HVDC grids are not limited to cable connections
between countries; they also are being used with the large
offshore wind farms. There is a growing trend to build larger
wind farms further out to sea. They are being developed in
groups and connected to the grid in clusters.
They go by names such as BorWin, DolWin and HelWin.
Bor stands for Borkum, Dol for Dollart, Hel for Helgoland and
Win for wind. To keep track of the connection portion of the
project, numbers are associated with these facilities, such as
BorWin1 or DolWin1.
The BorWin1, consisting of 80 5-MW wind turbines, is
the most remote offshore wind farm. The HVDC link was
completed in 2009, and the wind turbine installation will be
completed this year. BorWin1 is connected to the Germany
power grid using VSC technology with a 125-km (78-mile)
submarine cable and a 75-km (47-miles) underground cable.
The scheme’s rating is 400 MW and ±150 kV.
No sooner had the BorWin1 project been completed than
the German company TenneT Offshore GmbH announced the
800-MW DolWin Alpha North Sea project. It will connect the
wind farms in the DolWin1 cluster (400-MW plus future wind
Companies mentioned:Electric Power Research Institute | www.epri.com
ENTSOE | www.entsoe.eu
Hydro-Québec | www.hydroquebec.com
NamPower | www.nampower.com.na
Powergrid Corporation of India | www.powergridindia.com
State Grid Corporation of China | www.sgcc.com.cn
TenneT Offshore GmbH | www.tennettso.de
farm additions) to Germany’s grid at the Dorpen/West con-
nection point.
DolWin uses the latest VSC technology and takes advan-
tage of recent extruded polymer (cross-linked polyethylene)
cable advancements with the higher ±320-kV operating volt-
age to increase its power-transfer ratings and reduces losses.
Its submarine cable length is about 75 km (47 miles) and its
underground cable length is 90 km (56 miles). The project will
be placed in service in 2013.
North AmericaNorth America has not had as much HVDC action as the
rest of the world. There have been several life-extension proj-
ects for older schemes, but there has not been much activity in
the area of long-haul transmission for renewables or offshore
wind farms.
That does not mean there has not been interest in HVDC.
Some notable projects have been built and there are more on
the drawing boards. The United States and Mexico were in-
terconnected by the fi rst large-scale open-access ties with the
150-MW Sharyland back-to-back converter station in 2007.
In Canada, Hydro-Québec built the 1,250-MW Outaouais
back-to-back scheme interconnecting Ottawa and Québec
in 2009. The station has two independent HVDC blocks
(625 MW) for reliability and operating fl exibility. This link
provides Ottawa with access to Québec’s vast hydroelectric
generation renewable resources.
There also have been several underground/submarine ca-
ble projects using VSC technology, such as the Cross-Sound
Cable, Neptune and Trans Bay Cable projects.
Changing GridIt is an interesting time to be working in the electricity in-
dustry. Renewable energy resources are one of the principal
driving forces in the industry today. It is one of the fastest-
growing sectors as dependency on fossil fuels is trimmed
down, the carbon footprint is reduced and greenhouse gasses
are lessened.
For utilities to be able to harvest this renewable power po-
tential, they must be able to move it effi ciently from the remote
sites where it is generated to the load centers. Increased bulk
transmission capacity is the solution to utility-scale renewable
generation. Integrating HVDC technology into the ac grid is
the key to that solution. HVDC’s inherent properties make
the high-voltage ac backbone more fl exible, controllable and
stable.
Huge cranes and ship are required to install the VSC con-verter station (dedicated platform) for the BorWin1 project, which is the world’s fi rst HVDC link connecting an offshore wind farm to an ac grid. Courtesy of ABB.
The platform housing the BorWin1 VSC converter station is moved from the assembly area for installation in the North Sea. Courtesy of ABB.
www.tdworld.com
14 April 2012 l Transmission & Distribution World
Connecting the DotsThe grid is being hybridized into an ac-dc network
that is more fl exible, accessible and reliable.
By Gene Wolf, Technical Writer
Today’s electrical grid is a complex system so
heavily loaded and congested it can be pushed
into instability by unrelated events. The infa-
mous 2003 Northeast blackout in North America
spread across the grid at warp speed, affecting
roughly 10 million people in Ontario, Canada, and 45 million
people in eight U.S. states. The industry revisited this phe-
nomenon with the 2006 European blackout. Six European
countries were affected, putting an estimated 15 million cus-
tomers in the dark.
The Valhall offshore complex is the fi rst oil fi eld to have its entire ac requirements provided by a VSC converter station. Courtesy of ABB.
www.tdworld.com
15Transmission & Distribution World l April 2012
The grid has grown into vast synchronous high-voltage
alternating-current (ac) networks that become weak as reserve
capacity fl uctuates. These high-voltage ac network-based sys-
tems require extensive studies, computer modeling and enor-
mous amounts of data exchange between the interconnected
systems.
In addition to all of that, the interconnected systems must
maintain a high degree of technical compatibility and opera-
tional coordination; otherwise, there will be problems — big
problems. As the blackouts of 2003 and 2006 proved, a snag
anywhere on the grid can be felt everywhere. Relatively small
troubles can grow into major power failures with enormous
impacts on load centers far removed from the location of the
actual problem.
Technological Game ChangerSeveral postmortems of the 2003 and 2006 blackouts
pointed out the cascading failures did not propagate into
Québec during the North American blackout or into the U.K.
during the European blackout. Both had interconnections with
the affected power grids, but the blackouts were stopped at the
borders.
Those interconnections were high-voltage direct-current
(HVDC) interties performing like fi rewalls, which prevented
the outage from invading their grids. Many in the industry
knew HVDC facilities had the ability to block errant fault cur-
rents, but it seemed the rest of the industry needed a wake-
up call. As a result, there was a new awareness not only of
the fi rewall capability but also of the many other benefi ts of
HVDC (for example, load fl ow control, voltage control and
reactive power support).
In other words, HVDC offers improved stability, which is
why the idea of a hybridization of high-voltage ac networks
with HVDC applications is gaining traction in so much of the
world. By hybridizing the grid, industry experts are talking
about overlaying the ac system with a dc grid. They envision
this dc grid as a combination of regional and interregional
HVDC grids.
It is interesting to note this supposedly new idea of a dc
grid is not all that new. Visionaries imagined a dc grid for off-
shore oil and gas fi elds more than 30 years ago. When wind
farms began moving offshore, an offshore dc grid gained more
interest, but it has taken time for technology to catch up.
Trends Start SomewhereThe mercury arc valve technology gave utilities the benefi ts
of long-haul HVDC transmission and submarine links. Utilities
took advantage of this technology and built the Cross-Channel
project (U.K. linked to France) and the New Zealand Inter-
Island project. The technology worked, but when it came to
maintenance, it was complex, expensive and labor-intensive.
Then came the thyristor valve; it simplifi ed HVDC tremen-
dously, and utilities took advantage of this technology with a
fl ood of HVDC systems globally. Utilities began to link their
systems, crossing borders, connecting islands to the main-
land and sea crossings became common — Denmark-Norway
(Cross-Skagerak project), Italy-Sardinia (SAPEI project),
Germany-Denmark (Kontek project) and Germany-Sweden
(Baltic Cable project), to name just a few. These were but a
precursor to what was ahead.
Power Transistors Complement ThyristorsAs the industry was preparing to enter the 21st century,
HVDC technology took a quantum leap forward when ABB
introduced the voltage source converter (VSC) with pulse-
width modulation. It was revolutionary, or perhaps evolution-
ary would be a better descriptor since technology, like all evo-
lutionary process, builds on itself.
This was a completely new converter design unlike any-
thing before it. It was based on valves using power transistors
rather than thyristors. VSCs use fast semiconductors known
as insulated-gate bipolar transistors (IGBTs) and cross-linked
polyethylene (XLPE) dc cable.
This new type of valve architecture let designers break
from net-commutated principles by allowing operation in
www.tdworld.com
April 2012 l Transmission & Distribution World16
all four quadrants of the P-Q plane. This permitted reactive
power to be controlled independently of active power, which
is an enormous advantage over line-commutated converter
schemes when it comes to renewables.
VSC technology also is able to deliver power to a network
without other generation sources — the so-called black-start
capability. The VSC also eliminates problems from infeed
to weaker networks. And if that is not enough, VSCs change
power direction by switching the direction of the current, not
changing voltage polarity. These
abilities make VSC multiterminals
easier to connect to different points
in the same ac network or different
ac networks, which is a stepping
stone to the hybrid dc grid.
Changing ConceptsVSCs are changing offshore elec-
trical power traditions in a big way.
The traditional method to power off-
shore oil and gas fi elds was to either
bring high-voltage ac power from
the mainland or generate electricity
by burning gas or diesel on the plat-
form. Diesel/gas-generated electric-
ity impacts the carbon footprint and
produces a lot of greenhouse gasses.
high-voltage ac brought from the
mainland has distance limitations
requiring reactive compensation
about every 50 km (31 miles).
Then in 2005, VSC technol-
ogy changed everything with the
Troll A project. For the fi rst time,
a VSC system provided power
from the Norwegian grid to an
offshore compressor station. It
also included another new tech-
nology, ABB’s very high-voltage
motor (VHV), which was devel-
oped with compressor platforms
in mind.
What makes the VHV unique
is the fact it is designed to be driv-
en directly by the VSC without a
transformer. Not having a trans-
former is a substantial weight
savings, which is critical on an
offshore platform. Of equal im-
portance was the elimination of
emissions from the combustion
turbines, which were estimated
at roughly 230,000 tons of carbon
dioxide and 230 tons of nitrogen
oxide per year.
The success of Troll A paved
the way for the next step, supplying an entire oil fi eld’s ac
requirements from a VSC installation. BP (formerly British
Petroleum) replaced the Valhall oil fi eld’s production and
compression platform and its living platform with a new VSC
platform, which eliminated several gas turbines and reduced
emissions signifi cantly (about 300,000 tons of carbon dioxide
and 250 tons of nitrogen oxide per year).
With Europe’s commitment to the environment, VSC
schemes also are making inroads with offshore wind farms. In
The Western HVDC Link project connecting Scotland and England via submarine cable. Courtesy of Siemens.
The world’s fi rst multiterminal HVDC system bringing Hydro-Québec’s clean hydro gen-eration to Montreal and New England. Courtesy of ABB.
www.tdworld.com
17Transmission & Distribution World l April 2012
2009, the BARD Offshore 1 wind farm became the fi rst wind
farm to be connected to shore with a VSC scheme.
Offshore DC Grid Hub ConceptToday, dozens of VSC offshore wind projects are in ser-
vice, under construction or in
the planning stages. Offshore
wind generation has grown at
a fantastic pace in Europe. The
European Wind Energy As-
sociation (EWEA) released its
2011 offshore wind statistics
recently.
The EWEA reported a
total of 1,371 offshore wind
turbines have been connected
to the grid. This fi gure repre-
sents 3,813 MW from 54 wind
farms connected to 10 Europe-
an countries. EWEA estimates
roughly 40 GW of wind will be
installed offshore by 2020 and
expects it to increase another
110 GW by 2030, for a total of
150 GW.
That is a lot of wind gen-The BARD Offshore 1 wind farm and the BorWin1 VSC platform located in the North Sea. Courtesy of ABB.
The Troll A platform combines the latest in motor technology with VSC HVDC technology to bring power from shore and reduce the carbon footprint of this oil/gas fi eld, which is so critical to providing Europe’s energy needs. Courtesy of ABB.
eration to connect with individual connections, which is not
an effi cient method. This has triggered a slew of proposals to
connect wind farms and oil fi elds to an offshore dc grid that
is international by nature. One plan for the European Union is
called the Offshore Grid project.
www.tdworld.com
April 2012 l Transmission & Distribution World18
This offshore grid would connect the North and Baltic Sea wind farms to the continent through hub connections at sea.These hub connections would then form a dc grid, allowing the aggregation and dispatch of all the offshore wind farms to be sent to any country connected to the dc grid.
This would meet two huge needs of the industry. The wind farms would be located in totally different regions, which could solve the intermittent nature of wind; in an area this size,the wind is blowing somewhere all the time. The other issue just starting to gain attention is the submarine cable conges-o gain attention is the submartion problem. Each offshore facility requires submarine cablem. Each offshore facility requires submarinconnections to shore using today’s designs. The dc grid hubnections to shore using today’s designs. The dc gridconfi guration would avoid a large number of parallel subma-onfi guration would avoid a large number of parallel subma-rine cables by consolidating the wind farm feeds.rine cables by consolidating the wind farm feed
Recently, the 10 nations bordering the North Sea showed Recently, the 10 nations bordering the North Sea showed how serious they are about offshore grids and congestion by w serious they are about offshore grids and congestion signing an agreement called the North Sea Countries Offshore signing an agreement called the North Sea Countries OffshoreGrid Initiative. This initiative has been heralded as the fi rst Grid Initiative. This initiative has been heralded as the fi rst
eploy-lstep in the European super grid. It will coordinate the dn the European super grid. It will coordinate the step in the European super grid. It will coordinate the deploy-ment of new HVDC cables with the goal of linking renewablent of new HVDC cables with the goal of linking renewment of new HVDC cables with the goal of linking renewableenergy acrergy across the North Sea.ener
Part of the initiative is the BritNed cable between the U.KPart of the initiative is the BritNed cable between the U.K.and the Netherlands, which is the fi rst HVDC link between theand the Netherlands, which is the fi rst HVDC link between theU.K. and another country in 25 years. The BritNed auctions U.K. and another country in 25 years. The BritNed auctionsns the cable’s transmission capacity on the open market. Inter-the cable’s transmission capacity on the open market. Interer-estingly, the cable’s 1,000-MW capacity has been fully pur-estingly, the cable’s 1,000-MW capacity has been fully pur-chased since going into service. The next HVDC link for this chased since going into service. The next HVDC link for thisis strategic plan is the 2012 East-West Interconnector (Ireland-strategic plan is the 2012 East-West Interconnector (Irelandd-
alWales) project.
A DC GriA DC Grid in the FutureCombine this offshore dc grid hub concept with the Combine this offshore dc grid hub concept withh the
The Guilio Verne cable-laying vessel. Courtesy of Prysmian Group.
Conceptual regional and interregional HDVC grid intercon-Conceptuanecting the European Union. necting the E Courtesy of ABB.
www.tdworld.com
April 2012 l Transmission & Distribution World18
This offshore grid would connect the North and Baltic Sea
wind farms to the continent through hub connections at sea.
These hub connections would then form a dc grid, allowing
the aggregation and dispatch of all the offshore wind farms to
be sent to any country connected to the dc grid.
This would meet two huge needs of the industry. The wind
farms would be located in totally different regions, which
could solve the intermittent nature of wind; in an area this size,
the wind is blowing somewhere all the time. The other issue
just starting to gain attention is the submarine cable conges-
tion problem. Each offshore facility requires submarine cable
connections to shore using today’s designs. The dc grid hub
confi guration would avoid a large number of parallel subma-
rine cables by consolidating the wind farm feeds.
Recently, the 10 nations bordering the North Sea showed
how serious they are about offshore grids and congestion by
signing an agreement called the North Sea Countries Offshore
Grid Initiative. This initiative has been heralded as the fi rst
step in the European super grid. It will coordinate the deploy-
ment of new HVDC cables with the goal of linking renewable
energy across the North Sea.
Part of the initiative is the BritNed cable between the U.K.
and the Netherlands, which is the fi rst HVDC link between the
U.K. and another country in 25 years. The BritNed auctions
the cable’s transmission capacity on the open market. Inter-
estingly, the cable’s 1,000-MW capacity has been fully pur-
chased since going into service. The next HVDC link for this
strategic plan is the 2012 East-West Interconnector (Ireland-
Wales) project.
A DC Grid in the Future
Combine this offshore dc grid hub concept with the
Submarine cable installation vessel. Courtesy of ABB.
Conceptual regional and interregional HDVC grid intercon-necting the European Union. Courtesy of ABB.
www.tdworld.com
19Transmission & Distribution World l April 2012
Companies mentioned:ABB | www.abb.com
BP | www.bp.com
Deutsche Energie-Agentur GmbH | www.dena.de/en
European Wind Energy Association | www.ewea.org
onshore proposals being considered, and an over-
all hybrid ac-dc grid emerges. Onshore, Deutsche
Energie-Agentur (DENA) has some interesting
plans that propose to take advantage of existing ac
and dc facilities, as well as new facilities. DENA is
proposing an extension of its existing integrated grid
as a transmission network by upgrading overhead
transmission lines, constructing new transmission
lines and overlaying a meshed dc grid (overhead
and underground HVDC transmission).
A dc grid would consist of dc hubs connected
to synchronized and unsynchronized ac systems,
onshore and offshore, connected as regional dc
grids and interregional dc grids. Its principle value
would be as a facilitator for power exchange, power
trading between power systems and reinforcing the
ac grid.
The regional dc grid is defi ned as a system that
comprises a single protection zone. Such a system
can be built with today’s HVDC technology. It re-
ally does not need a dc circuit breaker to isolate the
faulty part of the grid, but regulatory issues do need
to be addressed and solved.
The interregional dc grid is a different matter.
It is a system that needs several protection zones.
It needs dc circuit breakers, fast protection, power
fl ow controllers, automatic network restoration and
a dc-dc converter for connecting different region-
al systems. Of course, there are more regulatory
issues complicated by the number and size of the
interregional dc grid.
Grid-Wise TechnologyThese are interesting challenges, but they are not showstop-
pers. Multiterminals have given utilities some experience with
several of these issues. Power balance is maintained when the
power input is equal to the power output (including losses).
The dc voltage is the indicator of power balance. When there
is a surplus of power, the dc voltage goes up; when there is a
power defi cit, the dc voltage goes down — simple.
Control systems are available that have a proven track
record maintaining energy balance with voltage and power
control. Several professional groups are working on ac and dc
grid-simulation models as well as advanced power fl ow pro-
grams to develop new operating strategies for large HVDC
systems, such as an overlaying backbone system and its effects
on the existing ac networks.
Perhaps the most signifi cant barrier to the interregional
dc grid has been the lack of a suitable HVDC circuit breaker.
This is due to the fact a dc grid has very low impedance, and a
short-circuit fault is much harder to deal with than that found
in an ac grid. An HVDC circuit breaker must be able to clear a
fault in a few milliseconds to avoid a collapse of the common
dc voltage.
The existing mechanical dc breaker designs are too slow.
Semiconductor designs are fast, but they generate large trans-
fer losses. To overcome these shortcomings, ABB is develop-
ing an HVDC breaker concept that combines mechanical and
semiconductor designs into a hybrid breaker.
No Shortage of ChallengesToday, the situation is rather simple. The need for con-
nectivity between countries and power market regions is
the major motivator for developing hybrid grids (ac with dc
overlay). Renewable energy and environmental concerns for
reducing greenhouse gasses and the carbon footprint are key
policy drivers. HVDC technology is proving to be a most
important tool in the industry’s toolbox for addressing these
forces. In many ways, this situation is very similar to the early
days when people thought they had to decide between ac or
dc. But, now dc is not competing with ac; it is improving the
network.
An HVDC grid is taking shape with cross-border links increasing yearly in the European Union (based on data from the European Wind Inte-gration study).
Finland
Italy
Spain
Iceland
Sweden
Norway
France
Poland
U.K.
Greece
Netherlands
Belgium
Ireland
Estonia
Mediterranean Sea
NorthAtlanticOcean
Bay of Biscay
Gulfof
Bothnia
North Sea
Norwegian Sea
TyrrhenianSea
IonianSea
Aegean
English Channel
Adriatic
BalticSea
Germany
Gulf of Sidra
TunisiaAlgeria
Libya
ExistingUnder constructionUnder consideration
Denmark
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April 2012 l Transmission & Distribution World20
The Evolution of HVDC TransmissionBy Narain Hingorani, Consultant
Narain Hingorani is considered the father of fl exible al-
ternating current transmission systems (FACTS) and cus-
tom power innovations, and a leader in HVDC. After six
years at Bonneville Power Administration and 20 years
at EPRI, he retired to start consulting in the development
of power electronics and devices.
Commercial HVDC was pioneered in the
1950s, starting with the 20-MW Gotland
submarine-land project, based on mer-
cury arc valves designed by Dr. Uno Lamm and
built by ASEA in Sweden. Then, in the 1960s
came a major evolution through General Elec-
tric’s introduction of silicon-controlled rectifi ers
(now known as thyristors).
Through the seven decades of HVDC tech-
nology evolution, there was a long period of
feast and famine for companies in the HVDC
business. One or two orders could keep a sup-
plier busy for three years, and then there may not be an or-
der for a year or two. That sorted out the fi eld, leaving three
manufacturers left in global competition: ABB, Siemens and
Alstom.
In recent years, HVDC business has increased well beyond
expectations of most experts, and the three manufacturers are
hard-pressed to keep up with demand. Well, what happened?
Expanding the GridDeveloping countries — particularly China, India and Bra-
zil with sustained high-growth rate and fast growth in electric
energy demand — have undertaken long overhead transmis-
sion lines from hydro and fossil energy sources and are ex-
panding their systems with ultra-high-voltage (UHV) ac grid
and UHV dc long-distance overhead lines and some HVDC
back-to-back projects. Several ±800 kV, 6,000-MW projects
and higher are under construction or in the planning process,
and there seems no end in sight.
Europe has numerous HVDC projects, too, but for dif-
ferent reasons. European utility and energy companies, that
can hardly expect new overhead transmission corridors, have
taken on harnessing wind energy and diversity of hydro, wind,
storage and other sources of energy with underground and un-
derwater transmission. Most of these are HVDC because it
only takes 40 miles to 50 miles (64 km to 80 km) of transmis-
sion length to make HVDC more economical, not to mention
having control of power fl ow over an HVDC line. Europe has
found it appropriate and economically viable to pay for un-
derwater and underground HVDC cables to harness available
energy sources. The cost of several hundred miles of undersea
and underground dc cables including converters is still signifi -
cantly less than cost of generation of any kind.
Recently, the HVDC technology also has evolved. Voltage
source converter (VSC) technology enables the use of cables
with no polarity reversal. This increases the dielectric cable’s
withstand strength to nearly twice the dc voltage, and solid di-
electric cables, polypropylene-paper, have become attractive
and economical for this application. There are other advantag-
es of the recently evolved modular VSC technol-
ogy, including no need for ac or dc fi lters, lower-
cost transformers, black start and almost free
leading or lagging reactive power as required up
to 30% rating. Underground HVDC transmis-
sion does not require a prolonged permit process
and may even enable shorter route to its desti-
nation. VSCs require semiconductor devices
that have turn-off capability and presently use
transistors, whose current and voltage capability
is half that of thyristors. Therefore, with contin-
ued advancement, we should expect signifi cant
cost reductions in VSC-based HVDC technology. After six
decades, HVDC technology feels like a new technology.
Connecting WindThe United States needs a better regulatory environment,
as well as regional and national transmission planning, if it is
to harness vast renewable resources and could be using HVDC
underground transmission for connecting large wind farms
through the plains to load centers. But utilities are unwilling
to use HVDC underground transmission, believing that un-
derground is much more expensive than overhead transmis-
sion, even though it takes years and years to get permits to
build overhead lines along viable corridors.
Interestingly, the California ISO determined a 40-mile
HVDC submarine transmission through the San Francisco
Bay was more economically viable than overhead line op-
tions for bringing 400 MW of power to San Francisco and was
built by a private investor using Siemens technology. Close
to approval stage is the Champlain Hudson Power Express, a
333-mile (536-km) HVDC cable project that will bring hydro
power from Canada to New York City. The cable will be
placed in waterways or buried along railway routes to mini-
mize impact to local communities and the environment. Just
ordered from Siemens-Prysmian is the Western HVDC Link,
a 370-km (595-km), 2,200-MW, 600-kV submarine cable link
from Scotland to Wales to harness wind generation.
Today, underground HVDC transmission including con-
verters through plain fi elds and lakes will probably not cost
much more than overhead ac transmission and, in many cases,
will be small compared to the cost of generation. Let us give it
a try to harness our clean energy sources.
ABB Ltd
Power Systems and Power Products
P.O. Box 8131
8050 Zurich, Switzerland
Phone +41 (0)43 317 7111
Clean power superhighways ?
Absolutely.
Renewable energy sources such as hydro, wind and solar are often located far from high
demand centers. UHVDC and HVDC (ultra and high-voltage direct current) technologies
enable clean electricity to be transported over vast distances with minimal losses bringing
much needed power supplies to millions of consumers. ABB pioneered HVDC technology
in the 1950s and remains a global leader with more than 70 installations, providing a total
installed capacity of over 60,000 MW across the world. For more information please visit
us at www.abb.com/hvdc
ABB Ltd
Power Systems and Power Products
P.O. Box 8131
8050 Zurich, Switzerland
Phone +41 (0)43 317 7111
Cross-border power connections, underwater ?
Certainly.
As our world becomes increasingly global and concerns about the environment grow, countries
are trying to balance their need for more electricity with cross-border interconnections. ABB
technologies are bringing this vision to life with transmission links that cross vast distances,
often underwater, transporting large amounts of high-voltage power with low losses and
minimum environmental impact. We offer a range of products, systems and services for power
generation, transmission and distribution to help increase power capacity, enhance grid relia-
bility, improve energy efficiency and lower environmental impact. With a 125 year heritage
of technology innovation ABB continues to shape the grid of the future. For more information
please visit us at www.abb.com
