Tips & News - January 2012

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ENDURING PRODUCTS AND PEOPLE YOU CAN DEPEND ON.

VOL. 16 NO. 1 | JANUARY 2012 TIPS NEWS www. hubbe l l powe r s y s t ems . com

TIPS NEWS &

PROTECTA*LITE ARRESTERS A Radical Improvement in MAIFI with

GTC MAIFI

When it was formed, Georgia Transmission Corporation (Tucker, GA) had a company-wide Momentary Average Interruption Frequency Index (MAIFI) of two. And, there was one transmission line with a MAIFI of ten. Today, the company-wide index is .92 and momentary outages on that particular line have dropped to less than one per year. Here is how GTC made those improvements.

Primarily due to Lightning

1997 2009

Company wide:

.951

Worst Line

together, they account for about half of the US electric grid. For sustained outages, GTC is on par with the national average: Unfortunately, due to lightning, it ranks near the bottom of the list for momentary outage performance. To keep track of the lightning problem, in 2001, GTC started subscribing to the Viasala (Tuscon, AZ) lightning data service. Viasala sends information to GTC on all the lightning strikes in the state of Georgia. This includes the GPS location and magnitude of the strike, polarity, the date, the time (down to the millisecond). If a momentary outage occurs, the company takes the time stamp from the digital fault recorder (also in milliseconds) at the fault’s inception, and compares it to the lightning data. “If the fault inception was within 10 milliseconds of the lightning flash and if the GPS coordinates of the lightning strike are within a one kilometer buffer around the transmission line, then we are 95% sure that momentary outage was due to lightning. In a given year, anywhere

“Since its incorporation in 1997, one of GTC’s corporate goals has been to improve the traditional IEEE metrics, including MAIFI. Engineers began by determining what was causing the momentary outages and lightning was a major problem,” says Doug Maddox, Manager- System Reliability. Lightning Central This is not surprising, since after Florida, Georgia has some of the highest lightning densities in the United States. Parts of GTC’s area are close to the Gulf Coast and other areas are close to the Atlantic Ocean. Weather fronts come through year round with lightning occurring in every month of the year. The most vicious storms happen in the summer time--afternoon thunderstorms with the high magnitude lightning and heavy downpours. These storms have consequences. GTC sends its outage data to a consultant for benchmarking. About 30 other utilities are also part of the benchmarking program and,

4 www.hubbellpowersystems.com 2

from 50 to 75% of momentary outages are due to lightning at GTC,” says Maddox. Lightning Arresters Versus Moisture

With so much riding on the lightning arresters, GTC keeps a close watch on them and sends failed arresters to a consultant for analysis. A consulting engineer in surge protection, says, “GTC has been having some problems. They wanted to know if the arrester failures were a one-time thing or a systemic problem that they need to worry about. GTC is very progressive in terms of reliability: I think the company is way ahead of the crowd in terms of protecting their system with arresters.” Analysis of failed arresters from GTC points to the usual suspect. The consulting firm found that moisture ingress is the predominate cause of arrester failures at GTC (which is consistent with the industry in general) and that there was evidence of moisture ingress in older arresters that had not yet failed. “Of course, moisture ingress is only one source of failure. Mechanical failure due to swinging is another,

Lightning is a common occurrence in Georgia and impacts a utility’s momentary outage index.

but moisture is the most common problem and it is the arrester’s biggest enemy. Moisture is the nemesis of the arrester designer (both in porcelain and polymer arresters). Designers continuously strive to make lightning arresters water insensitive,” says the consulting engineer. Choosing Protecta*Lite® Arresters To reduce problems associated with moisture ingress, GTC is now installing Protecta*Light ® arresters from Hubbell Power Systems (Ohio Brass ® brand), and has found them to be a reliable solution with a very low failure rate. So far, the few Ohio Brass failures have been due to installation problems. The consultant continues, “Moisture ingress can lead to failures in more than one way. For example, if lightning strikes a pole or line… I’ve seen arresters installed on the un-faulted phase fail during the line to ground fault. Often times, if there is a fault on phase ‘A,’ the line to ground voltage on Phases B and C increase and, depending on the configuration of the system and the impedance of the neutral, the voltage can rise high enough to cause arrester failures on the un-faulted phases. Lightning didn’t actually pass through the arrester but caused the event that lead to the failure. It would appear like a lightning failure and would most likely be recorded as such, but it was a temporary overvoltage (TOV) failure. If the arrester was already compromised by moisture, then I would say neither the lightning nor the overvoltage stress was actually the cause of the failure. Moisture ingress was the root cause.” It is a common misconception that lightning is the biggest reason for arrester failures, but that is not the case. Modern arresters are tough and are capable of surviving many lightning strikes over time. “Fortunately, when lightning of any magnitude (30 or 50-kA), passes through an arrester, it leaves a footprint. It actually modifies the characteristics of the semi-conductor and if you look at its characteristics with an oscilloscope, you can see that it experienced a high current impulse. Over the years--maybe 10% of the time—the arresters I’ve examined have failed due to a very high current surge caused by a direct lightning strike. But, usually the failures are due to moisture ingress or a

Lightning and Momentary Outages Lightning can cause momentary outages in three distinct ways. The first is the classic overvoltage flash from a high amperage strike. The voltage builds-up and flashes from the insulators to ground. The second is a ‘shielding’ failure. This occurs when lightning hits a line from the side, bypassing the over- head grounding (shield) wire. Lastly, a momentary outage can occur due to ‘back-flash,’ when lightning hits the pole. As the cur- rent passes down the pole ground, a voltage of sufficient magnitude can be created. This voltage can flash over to the conductors. In this case, improving pole ground- ing will provide some protection. Despite grounding, really high magnitude strikes will still cause a back-flash. But, properly installed arresters can prevent all types of momentary outages caused by lightning.

TIPS NEWS &

manufacturing issue or mishandling or partial discharge damage or some other thing,” says the consulting engineer. “Arresters can help eliminate momentary outages caused by lightning. (Note: It won’t prevent all momentary outages, like ones caused by falling tree branches.) And the way to do that is to install arresters at a fairly high population rate. GTC has done that on their lines. On the lines GTC has chosen to most protect, they have gone from seven, eight or nine outages per year— down to zero. They did this by installing arresters on every phase of every tower,” says the consultant. Playing with Line Designs In 1997, it was widely believed at GTC that a 115-kV line (based on its BIL and other characteristics) should be able to withstand a lightning strike of 30,000-Amps or less and not flash over. But, if the lightning strike was more than 30,000-A, engineers expected that the strike would invariably lead to an unpreventable flash-over. “Of course, we would try to reground lines to prevent problems caused by lightning strikes of less than 30,000-A, but we were not making much headway. Shortly thereafter, we began using The Electric Power Research Institute, Inc.’s (Palo Alto, CA) T-Flash lightning performance software to model its typical line configurations,” says Maddox. To get the best results, the model requires a lot of information, including type of terrain, tree cover, size and height of the poles, size of the wires, types of insulators assemblies, etc. The software then models the transmission line and predicts that there will be ‘X’ number of momentary outages per year (based on the lightning density of this particular part of the state and line modeling). Once the current line configuration is entered, transmission engineers and designers can experiment by modifying the line’s design; changing the shielding, the grounding, the insulators, the lightning arrester patterns, etc. They discovered something interesting. “When we modeled the lines with three lighting arresters on each structure (one on every phase), T-Flash predicted no momentary outages due to lightning—even if the strike was greater than 30,000-A. On the other hand, when we modeled the lines with two lightning arresters on each structure (one on the top phase and one on the bottom phase), T-Flash predicted one momentary outage every 16 years--due to lightning. So, GTC chose the top and bottom configuration as its standard, because it would reduce costs and one momentary outage every 16 years would be tolerable,” Says Maddox. So, for the last ten years, the GTC has been installing lightning arresters on its transmission lines, focusing on the load serving lines first (46-kV, 69-kV and 115-kV). Typically, the results have been excellent. What about that ‘terrible’ line—the one that had 10 momentary outages per year? “We went for broke and installed lightning arresters on all three phases at every structure. Momentary outages due to lightning went from ten outages per year to none for the next two years. For the last two years, that line has

This significant aluminum oxidation is due to moisture ingress in the Zinc Oxide Disks of a MOV type arrester.

After extensive modeling and virtual experimentation, GTC chose the top and bottom installation as its stan- dard lightning arrester configuration. 4 www.hubbellpowersystems.com

experienced one momentary outage per year (both during summer storms) that were caused by lightning. In both cases, the stroke magnitude was greater than 100 kA,” says Maddox. “The Vaisala data indicates that GTC still has the same quantity and magnitude of lightning within a 1-km buffer around that line. So, to go from ten momentary outages to about one per year is a remarkable improvement,” says Maddox. With that transmission line taken care of, GTC has now reached a point where its worst lines do not have more than three or four momentary outages per year. But, the company is still installing lightning arresters and otherwise improving its lines, where a majority of momentary outages are caused by lightning. In 2009, GTC had its best year ever for momentary outages: 0.951 momentary outages per consumer. In 2010, the lightning flash count for Georgia was up 20% over 2009. MAIFI was slightly worse (~7%) at 1.018 momentary outages, per consumer. Technology and a Change in Attitude GTC’s drive to improve MAIFI goes beyond just providing reliable service to its members, it is necessary to ensure the company’s future. “In the 1970s, a momentary outage simply meant that the lights blinked. Customers did not complain. Linemen would search for the cause of the problem, but, in general, everyone at the company was happy because the protection scheme worked properly (the breaker did not lock- out),” explains Maddox. “But, it is a very different world today. The digital age brought computers and, now, just about everyone has a dozen high-tech devices in their homes and offices. Momentary outages are a big problem,” continues Maddox. Also, for the last 15 years, Georgia has been experiencing an economic boom. High-tech companies are building new facilities and, invariably, these manufacturers—small and large commercial, industrial—are using computer controlled equipment. While it may be easy to put a UPS on a single computer, it is much harder to protect a conveyer line or an entire plant. For a manufacturing plant, a momentary outage can mean anywhere from two to four hours of downtime. Today, momentary outages negatively affect all of GTC’s members and if the company wants to provide comparable service to other utilities, it needs to get its momentary outages in-line with its peer utilities in the South. In Georgia, there is competition for new electrical loads. If a company is moving into the area, it will typically look at three to four sites. Invariably someone will ask, ‘If we build at Site X, in this industrial park, how reliable will our electric supply be?’ “To prosper, GTC must provide reliability for the digital age. Improving MAIFI is just one part of an ongoing effort,” says Maddox.

Worker installs a lightning arrester on a transmission line at GTC.

TIPS NEWS &

for Your Most Demanding Application SDC™ GSU Transformer Bushings Electro Composites HV SDC™ (Solid Dielectric Capacitor) bushing line has been expanded to high current – high temperature applications for use on Generator Step‐Up (GSU) Transformers and other High Current Applications. Our SDC™ GSU design offers a continuous operating temperature up to 130°C and is rated per IEEE C57.19.01. Electro Composites ™ solid HV bushings solution

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4 www.hubbellpowersystems.com 6 6

EVP Arrester EnhancedVaristor Protection For PVN Station Arrester Replacement,

Built on 20 years of polymer arrester experience

Same housing material

Same mechanical strength

Same protective level

Same energy rating

Improved sealing system

Slotted tripod base for flexible installation (fits 8 3/4” and 10” bolt circle)

Grading ring usage optimized

Improved drawing documentation

Intelligent catalog numbering system

Sustainable features

EVP Line supersedes PVN Family

For more information contact your Hubbell Representative.

surge arrester MOV SEMINAR

June 5 & 6, 2012 Aiken, SC Space is limited to the first 20 applicants. Reservations will be accepted on a first-come, first- served basis, based upon paid registration fee.

E-mial us at: HPSTraining@hubbell.com

TIPS NEWS &

transmission foundations CHANCE® Helical Foundations

Difficult Site Conditions Cut build and repair delays.

Frost Heave

• Fast installation • No concrete cure time solve problems • Weak soils • Site access limitations • Frost heave

Any load. Anywhere.

For more information go to: http://www.hubbellpowersystems.com/anchoring/foundation/

8 www.hubbellpowersystems.com

CHANCE® Pole support anchoring Hot-dip galvanized per ASTM A153

Helical Pole Support

HELICAL POLE SUPPORT • Helps prevent pole from sinking in soft soils. • Installs in minutes in bottom of standard size pole hole. • Used with SS5 or SS150 Square Shaft anchors. • Installs with Standard PISA ® or T ough O ne ® anchor tools. • 19,000 to 40,000 lb. bearing capacities based on soil class. • Greener method than expanding foam!

Extension (optional)

• Choose from two hub-drive sizes: Catalog No. C1100941 for 2.25” hub Catalog No. C1100929 for 2.50” hub

Lead Section

POLE CLIP • Attaches pole near groundline to PISA ® helical anchors with 3/4” or 1” rods. • Primarily on H-frame sttructures, helps prevent

POLE BEARING PLATES • Choose from two designs shown below. • May be used in pairs on opposite sides of pole. • Attach with 7/8” machine bolts. • Grounding hole provided.

jacking or “walking” structure out of the ground. • Provides 5-1/2” of adjustment. Cat. No. E1020690 includes threaded coupler.

Each plate adds 90 sq. in. bearing area to pole base.

Each plate adds 122 sq. in. bearing area to pole base.

Catalog No. C1100954 plate only. Kits sold with bolts & lag screws.

Catalog No. C1100926 Sold as a single unit, not in pairs.

For more details, contact your local Hubbell Power Systyems representative or go to: http://www.hubbellpowersystems.com/anchoring/pole-support/ for additional information on our web site.

TIPS NEWS &

MVN Arrester Next Generation Porcelain - Replaces VN Standard high creep housings

Shorter lead times

Better on time service

Porcelain Stocking Program

Reduced height and weight on select sizes

Reduced grading ring size on select sizes

Universal casting provides high seismic performance

For more details, see your local Hubbell Power Systems Representative.

FIRST & ONLY 27kV Polymer Cutout

• Hubbell is the first and only brand to pass the Design and Type Test requirements of Canadian Standard CSA C310-09!

• This is the World’s first and only polymer cutout standard!

FUNCTION-DRIVEN reasons why Hubbell polymer cutouts are superior • Design-technology combines over 50 years of Chance ® brand cutouts and 30 years of Ohio Brass ® insulators.

• Employ time-proven ESP hydrophobic silicon-alloy rubber with tracking-resistant toughness.

• Light in weight, easy to handle and install.

• Superior mechanical and electrical performance due to hardware crimping technology and chemical bond interface to polymer weathershed.

10 www.hubbellpowersystems.com

You Thought All Secondary Pedestals Were the Same……

“Electric” identification permanently molded into the top surface of the cover as standard.

Easy to carry and easy to remove the cover using molded in handles.

Double Locking Cover security provided by Penta Head bolt and security features for your padlock.

Four sizes manufactured from proven & cost effective High Density Polyethylene material.

Easy installation of connectors and clearance for fasteners is provided by recessed areas on internal flange

Clear plastic covers included when connectors are ordered.

Rugged stability provided by wide base flange and extensive internal & external ribs.

Wire training and pedestal placement are made easier with mouse holes on taller sizes.

Think Again. Hubbell’s HDPE Secondary Pedestals provide a rugged, secure, and maintenance free enclosure for secondary electrical connections. Available in four sizes, with the features that the industry asked for.

TIPS NEWS &

CHANCE® BP3 3-Phase Switches Save Space and Improve Efficiency for GVEC By Richard Scott, Crew Foreman Guadalupe Valley Electric Cooperative (GVEC) Gonzales, Texas

8'-5"

5-1/2" REF

45"

5-1/2" REF

45"

5-1/2" REF

45"

5-1/2" REF

45"

3/8"THICKPLATE GALVANIZEDSTEEL (3-PLACES)

4"X4"X1/8"WALL G LVANIZEDSTEELTUBE

4"X4"X1/8"WALL GALVANIZEDSTEELTUBE

10-7/8"

12-1/4"

NAMEPLATE

SWITCHTERMINALPADS (TYPICALALLPHASES)

SWI CHTERMIN LPADS (TYPICA ALLPHASES)

29-3/8"

7-9/16"

15-1/8"

LEFTSWITCH

CENTERSWITCH

RIGHTSWITCH

LEFTSWITCH

C NTERSWITCH

RIGHTSWITCH

13-3/16"

26-3/8"

18-5/8" (TYP)

26-3/8"

1 -5/8" (TYP)

23-3/8"

TOPVIEW

ANDERSONCATNOCCLS-814-C TERMINALCONNECTOR ANDMOUNTINGHARDWARE (TYPICAL6-PLACES) (NOTASSEMBLEDONSWITCHES)

ANDERSONCATNOCCLS-814-C TERMINALCONNECTOR ANDMOUNTINGHARDWARE (TYPICA 6-PLACES) (NOTASSEMBLEDONSWITCHES)

LIFTINGEYES (ONOUTSIDEPHASESONLY)

LIFTINGEYES ( NOUTSIDEPHASESONLY)

29-3/8"

4-3/16"

5/8"DIATHRU-BOLTS (SUPPLIEDBYUSER)

6-3/4"

14"

90°

25-1/4"

10-7/8"

22"

FRONTVIEW

SIDEVIEW

(POLEMOUNTING)

VIEWA-A

“It is 3 a.m. and I get the call — a storm took down a pole outside of a substation and all three phases are on the ground. We have a lot of members out of service and want to make repairs quickly. “ Before we can make those repairs, we need a visible opening on both sides of the fault. At the substation, the line/ load switches are locked open, so we are good there. Down-line is a set of three electronic reclosers, but their contacts are internal. “So, how do we get our visible opening?”

The BP3 simplifies the isolation/by-pass-switch configuration for three-phase reclosers and for three single-phase reclosers installations.

www.hubbellpowersystems.com

technologies and work practices. We have just started installing electronic reclosers at circuit tie-points, where we used to install motorized air-break switches. In the event of a fault, a sectionalizing recloser lets us quickly break the feeder in two. We can then supply power from a different direction using the tie-point recloser, keeping some of our members in service while we fix the problem. This arrangement is great from a systems operation viewpoint because it gives us options, but it can create some minor problems in the field. Depending on fault location, we may not be able to use the tie-point recloser to isolate the fault. In the past, our reclosers were always attached to the primary line and opened by internal contacts only. But if we use them at tie-points, we need a way to isolate/by-pass the recloser—preferably in a way that does not entail removing the jumpers. Finding The Ideal Switch Assembly One of the first ideas was to build an isolation/by-pass assembly with nine of Hubbell’s solid blade, hook-stick switches: three to serve the left side of the pole, three to serve the right side of the pole and three to serve as the sectionalizer/by- pass switches. To install all of that, we would have to use two sets of double cross arms to mount the three on the left and the three on the right. And we would probably have to install another set of double cross arms to hang the other three switches underneath. This design would have required a substantial amount of labor and a total of nine hook-stick switches, driving the cost of the project for tie-points substantially higher. Then I remembered something I had seen at a conference a few years ago. Hubbell had a single-phase isolate/by-pass switch assembly that could be opened with a hookstick. I started envisioning how we could use those to improve our operation methods. Our operations manager

A few months ago, our only option would have been to send a crew in a bucket truck out there to manually remove the reclosers’ high-side jumpers. That would have taken some time to accomplish, delaying repairs and taking additional time to re-attach the jumpers when the repairs were complete. Today we are using Hubbell’s three-phase isolate/ by-pass switch: the BP3. In just seconds and without the need for a bucket truck, a lineman can isolate the line by opening the source and load switches that are part of the BP3 switch assembly. We just saved time and money. It also means we will get our members’ lights back on in a timely manner and do it without

compromising safety. Smart Grid Improvements

The Guadalupe Valley Electric Cooperative (GVEC) has about 68,000 customers in a service territory of 3,500 square miles in 13 counties in South Central Texas. We have about 7,900 miles of overhead distribution line. GVEC is in the early stages of applying Smart Grid

allowed us to get one for demo and testing. Before we took delivery of our first switch, our Hubbell representative told me that a neighboring utility had about 45 BP3 (three- phase) switches installed. So, I visited a couple of those locations to see for myself how they had made the BP3 work for them. I also spent some time with their transformer shop foreman, who is responsible for getting the switches ready to install. With some minor changes to my original vision, the BP3 seemed like the perfect solution. Successful Trials GVEC ordered a few of the three-phase by-pass BP3 switches and built a mock setup at our facility that mimicked field conditions. We then gave a demonstration to the line crews and the members on the standards committee to see what they thought. Everyone involved was excited about the installation, operation and improvements this switch could make to our future critical tie locations.

Even when the reclosers are wrapped around a pole, the BP3 is a simple way to add isolation/by-pass switches.

We use adapters to orient the connectors on the switch tabs to get the jumpers headed in the right direction. However, the ideal situation would have been to have a choice of connector orientation, so the switch would be turnkey ready. (We use a 90-degree orientation. Jumpers run vertically from the switch to the primary line.) We currently have seven BP3 switch assemblies installed and have found the installation to be simple and cost effective. I wish I had the BP3’s 30 years ago. Three Successful Applications The first installation was part of GVEC’s Smart Grid initiative. We had a normally-open air break switch at the end of two different circuits that were fed from two different substations. We planned to remove the air brake switch and replace it with a three-phase electronic recloser in a normally-open position. And, we needed to be able to isolate the recloser, in case our people ever needed to work on a downed line. On this job, the three electronic reclosers were in one large cluster that wrapped around the pole. The BP3 switch assembly allowed me to run the jumpers and maintain clearances. The second installation was on a transformer step-down rack. One of our scheduled system improvements was to convert a primary line to 14.4kV and move a step-down rack further down the line. Since installing another pole was not an option for us, I had to mount the three reclosers on an existing pole at the load end of the step-down rack. The BP3 switch allowed me to run my jumpers the way I wanted to. At the third site, we used the BP3 switch with a three-phase electronic recloser. This installation was similar to our first, but in this case, the three-phase recloser was all in one can and bolted to the pole. The BP3 simplified the design and installation, making it easier to operate than our previous switch option.

14 www.hubbellpowersystems.com

Multiple Advantages for GVEC GVEC faces some challenges that big utilities do not have to worry about, and the BP3 really helps us. • No Need for Another Pole Many electric utilities install their electric infrastructure in highway rights of way. They can add poles and equipment as needed. GVEC, on the other hand, works diligently to place our electric facilities on private property, which can make it more difficult to add poles. The BP3 can easily be installed on an existing pole. • Meets Visible Opening Requirement

The BP3 switches are important to us because as electronic reclosers take the place of air brake switches, we need some way to isolate the recloser. The recloser contacts are internal: We cannot have our men working on a line without visible openings. The BP3 isolation/switch provides that visible opening. • Improved Circuit Protection Sectionalizing In the old days, we used motorized air brake switches as isolation points on mainline feeders. We could open them remotely, but they did not provide any circuit protection. We are currently installing electronic reclosers where two feeders meet. With the BP3, we can have the best of two worlds; circuit protection and the ability to isolate. • Better Outage Management Another consideration is that most of our servicemen work out of a pickup truck. A bucket truck might not be readily available. The BP3 design allows us to work all switches from the ground with hot-line tools. We do not have to wait for a bucket truck to remove jumpers. This is a big advantage because it reduces our outage times and requires fewer men and vehicles. • Simplified Engineering The BP3 switches simplify the engineering design. It is much easier to design a configuration with one three-phase BP3 than it is to design something with nine single-phase switches. • Quick Isolation of Failed Recloser One of the things that is driving us to use the BP3 is the need to isolate a recloser that may have failed. • Easier Recloser Maintenance Another benefit is recloser maintenance. In a matter of literally seconds – maybe 60 seconds – I can by-pass all three reclosers. It’s game-changing. Now, linemen can isolate the reclosers, ground the tops and begin work. • Reduces Cost and Work Hubbell’s BP3 switch comes ready to install, and we have replaced our old construction technique in favor of it. Our other option would require a crew to assemble six 10-foot cross arms, nine double-arming bolts and nine 600-amp hook-stick switches. Considering all of the benefits, the BP3 gives us the results we want. Not only will it will lower construction costs and simplify future maintenance, but the BP3 also helps us take care of our members because we can restore service in a timely manner.

TIPS NEWS & Hubbell TIPS & NEWS magazine is pub- lished to inform personnel of electric utilities and associated companies of new ideas and techniques in transmission and distribution practices. The magazine, under different titles and formats, has been published since 1932. Your suggestions and editorial or photo- graphic contributions are invited and may be submitted to Hubbell TIPS & NEWS.

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UNITED STATES, CANADA & INTERNATIONAL • 210 N. Allen • Centralia, MO 65240 • Phone: 1-573-682-5521 • Fax: 1-573-682-8714 • E-mail: hpsliterature@hubbell.com MEXICO • S.A. DE C.V. • Av. Insurgentes Sur # 1228, Piso 8 • Col. Tlacoquemecatl Del Valle • Mexico, D.F. 03200 • Phone: 52-55-9151-9999 • Fax: 52-55-9151-9988 NOTE: Because we have a policy of continuous product improvement, we reserve the right to change design and specifications without notice.

VOL. 16 No. 1 | JANUARY 2012

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Transmission&DistributionExpo May 8 - 10, Orlando Convention Center, Orlando, FL 2012 IEEE PES

Make the Hubbell booth a “must stop” when you attend the 2012 Orlando Exposition. See the many new products introduced since the 2010 show. You’ll see how Hubbell Power Systems can supply 90% of the components needed on steel transmission towers and 75% of those needed for distribution. Plan on visiting the Hubbell Hospitality Suite Monday May 7, Tuesday May 8 and Wednesday May 9 from 5:00 to 9:00 p.m., in the Signature 1 Suite in the Rosen Centre Hotel. Our Suite is pool side in the Rosen Centre, 9840 International Drive. Conveniently located next to the Convention Center. A short walk away from the show action. See you in Orlando.

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