April2012.pdf

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CONTENTS

™

No. 4

C O V E R S T O R Y

APRIL2012

Vol. 64

36

Substation Design in the Third Dimension Modern design tools streamline substation work processes. By Gene Wolf, f Technical Writer

36

Wired for Success KCP&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

44

LiDAR to the Rescue A severe ice storm in Russia leads to re-evaluation of ROW status and vegetation management practices. By Boris Mekhanoshin, JSC IDGC Holding

44

52

Raising the Standard for Customer Engagement Glendale Water & Power invests in customer outreach, gaining early and continuous support for its smart grid project. By Glenn O. Steiger, r Glendale Water & Power

64

Bus Bar Innovation Transpower New Zealand designs, tests and commissions a new under-hung substation bus bar system. By Andrew Renton, Transpower New Zealand Ltd

74

50 2

NV Energy Signals Demand Reductions A decade of demand-response growth has generated benefits and created new challenges. By Victor Garman, NV Energy

64

April 2012 2 | www.tdworld.com

82

Show Update

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CONTENTS

Departments p 10

GlobalVIEWPOINT Smart India. Rick Bush travels to Mumbai to learn about India’s strong commitment to a robust energy future. By Rick Bush, Editorial Director

10

12

BUSINESSDevelopments Duke Energy and Progress Energy File Market Power Mitigation Plan EnerNOC Expands Upon AutoDR Success in New Zealand with Move to South Island

M M

16

SMARTGrid Team Announced for Consumers Energy’s 1.8 Million Smart Meter Deployment M City of Medicine Hat Chooses MeterSense for Meter Data Management M

18

TECHNOLOGYUpdates NEMA Encourages Action to Expand Meter Socket Lifespan and Inspections M Western Electricity Coordinating Council Contracts with Siemens PTI for Data Collection Tool M

18 22

QuarterlyREPORT PEVs 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

24

CHARACTERSwithCharacter A 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

24 96

StraightTALK Electronic 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 Everyy Issue 92 95 4

April 2012 2 | www.tdworld.com

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www.tdworld.com Editorial Director

Rick Bush

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Vito Longo

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Emily Saarela

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Gerry George

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Matt Tani

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Amy Fischbach

afi[email protected]

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Gene Wolf

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SUBSCRIPTION RATES: Free and controlled circulation to qualified subscribers. Nonqualified persons may subscribe at the following rates: U.S.: 1 year, $105.00; 2 years, $179.00. Canada: 1 year, $130.00; 2 years, $239.00. Outside U.S. and Canada: 1 year, $160.00; 2 years, $289.00. For subscriber services or to order single copies, write to Transmission & Distribution World, d P.O. Box 2100, Skokie, IL 60076-7800 U.S.; call 866-505-7173 (U.S.) or 847-763-9504 (Outside U.S.), e-mail [email protected] or visit www.tdworld.com. ARCHIVES AND MICROFILM: This magazine is available for research and retrieval of selected archived articles from leading electronic databases and online search services, including Factiva, LexisNexis and Proquest. For microform availability, contact National Archive Publishing Company at 800-521-0600 or 734-761-4700, or search the Serials in Microform listings at napubco.com. REPRINTS: To purchase custom reprints or e-prints of articles appearing in this publication, contact Wright’s Media at 877-652-5295 or [email protected]. Instant reprints and permissions may be purchased directly from our website; look for the iCopyright tag appended to the end of each article. PHOTOCOPIES: Authorization to photocopy articles for internal corporate, personal or instructional use may be obtained from the Copyright Clearance Center (CCC) at 978750-8400. Obtain further information at copyright.com. PRIVACY POLICY: Your privacy is a priority to us. For a detailed policy statement about privacy and information dissemination practices related to Penton Media Inc. products, please visit our website at www.Penton.com. CORPORATE OFFICE: Penton Media Inc., 249 West 17th St., New York, NY 10011 U.S., www.penton.com. Copyright 2012 Penton Media Inc. All rights reserved.

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S&C’s IntelliTeam® isn’t just automatic service restoration ince its introduction in 1997, S&C & ’ss InttelliTeam® Automatic Res esttora tora rati tion ti on n System has become the in industry ry’s ’s sta t ndar ard. d The latest vers rsio ion— n— — a solut utio ion n fo for im impr p oving gr grid id rellia iabi billit bi lity. IntelliTeam® SG—is a universal seCl Clos o ers, s, S Scada a-M -Mate® and nd Sca ada d It works with S&C IntelliRupter ® Pulse Mate CX™ Switches, Remote Su uperv r isorry Pa Padd-Mo Mo ounted Ge ear ar, and d d Dis istr trrib ibution Sw S itchge geear. A nd, Remote Supervisory Vista® Underground using S&C’s IntelliNode™ Interface Modul ulee, e, IIntelliTe Team Te am S SG G works with protection relays and reclos oser se control olss fr from om otherr man anuf ufa ac acturers tooo. But we didn’t stop there. No Now w we e’v ve de dev veloped d In Inte tell lliT iTeam® VV and d ® h llea eadi din di ng-edg ge co comm mmunication productts, to IntelliTeam DEM, along wiith meet other important needs of th t e intellig ig gen entt gr grid i . S&C’s IntelliTeam® VV Volt-V Var ar Optim miz izat atio ion System JUHDWO\LQFUHDVHVJULGFDSDFLWW\DQ DQGHI HIÀF HI ÀFLH L QF LH QF\ \ ,WZRUNV with load-tap changers, volttage re reg gu ato gula tors rs, an and d capacitor controls to optimize system m volttag age an and powe w r factor based on real-time condittion ons.. Our Int ntelliTeam® DEM Distributed Energy Man anag gem ment System can manage n ty t DÁHHWRIXSWRDWKRXVD DQG QG6 6 &3XUH:DYH® Communi Energy Storage Units, to iissolate consumers from distribution system op operations and transients for hours, and also integrrate the h community’s wind and solar power sources. And S&C’s SpeedNet™ Radios and IntelliCom® :$10HVK5DGLRVDUHLGHDOIRUDZLGHUDQJHRI6PDUW Grid application ns.

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vo tage ratings vo IntelliRupterr ® PulseCloser, available in vol of 14.4 kV through 25 kV, features PulseCl C osing Cl Technology™—a unique means for verifyin ying that yin the h line is clear of faults before initiating a cl closing operation. ope at o Pulseclosing u sec os g is s supe superior o to conven co e entional en to a reclosing. It greatly reduces stresss on syste syst stem m components, as well as voltage sa agss experienc n ed by nc customers upstream of the fault.

6800 Series Automatic Switch Controls provide remote reporting of switch status points, current, voltage, watts, and VARs via a variety of protocols.

Automation needs change and gro ow witth increased load, ca apacity, an nd dem mands for more reliab ble servicce. Scada-M Mate CX ® Switches meet these ch hanging needs, economically, in voltage ra atings of 14.4 kV thro ough 25 kV.

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IntelliCom™ WAN Mesh Rad adios ios os s provi provide d de reliable, high-capacity, se elf-hea healin lin ng wireless mesh network co ommunicatttion o for a wide range of appliccations requ uiring ng high throughput and very y low latenccy. S SpeedNet™ dN t™ Radio R di has h sb been optimized for IntelliTeam SG,, distributtion automa ation, and SCADA applications. Its high spee ed and low latency provides the fastestSRVVLEOHFRP PPXQLFDWLR RQIRUSULRULW\WUDI¿F

Remote S Supervisory PMH and PME Pad-Mounted G Gear ffeature power-operated switches which respond to opening and closing signals from a remote location. This gear, available in ratings of N9DQGN9FDQEHVSHFL¿HGZLWKDFRPPXQLFDWLRQDQG control equipment group, for a completely integrated and selfpowered automated switching and protection package. p g

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T Inte The elliTeam ® DEM Distributed Energy Management System aggregates PureWave ® Community Energy Storage Units into a dispatchable energy source. It provides fully automated charging and discharging off the energy storage units, either at scheduled times orr to discharg meet target demand at feeder and substation transformer levels.

PurreWa P eW Wave e® C Community it E Energy Sttorage Sto e Syst Syst ysst stem e provides distributed electric ele c ene nergy rgy gyy st s orage, for reliable, loc lo o all bac b kup up p po powe we for consumers. wer we The he multiipli p citty of of unit n s—i ni s ntegrated ® and d co controlled ed d byy the he IntelliTeam IIn n DEM D M Di Distribu b ted d En Energ ergyy Management erg S tem Sys em—of em —o ferrs higher er agg gg gre r ated reg av ilabil ava bility bil ity . . . keeping the he gr grid id id functioning fun ng g for mo m re consum um mers s.

S&C’s S &C’s solutions solut for improved grid reliability, LQFUHDVHG GJULGFD DSDFLW\D DQGHIÀFLHQF\DQGJULG communiccation in nclude a wide range of supporting engineeriing and design, and construction and implemen ntation sservices. These services can be provided iindividu ually or on a turnkey basis with the equipmen nt. Conta act S&C C today to see how we can design an nd impleement a solution for your system. Visit us a at sandc.com/intelliteam or call us today a at 773-33 38-1000. See S ee these and other er products from S&C at the IEEE PES Show in Orlando, Florida, USA,, May 8—10, 2012.

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GlobalVIEWPOINT

Smart India

I

had been invited to India by the executives of the Indian Electrical and Electronics Manufacturers Association (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, Ministry 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 struggling Indian power sector while providing plenty of opportunity 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 sector 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 introducing 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 predicted growth rate in the country of 7% to 9% per year, India faces quite a hurdle to meet the energy shortfall while meeting 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 tremendous 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%

10

April 20122 | www.tdworld.com

Rick Bush and ELECRAMA Chairperson Indra Prem Menon enjoy a lighter moment together.

to 28%,” said Lavasa. I learned that the revenue losses vary significantly by state but are typically due to poor accounting 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 efficiency, 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 electricity, 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 inefficiencies. As India addresses systemic losses on the distribution system, more funds become available to invest in the distribution, 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 conductors. 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 investors 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.

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BUSINESSDevelopments

D Duke Energy and Progress Energy 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 off intent 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 from m the NCUC and the Public Service Commission of South Carolina 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 mustdeliver, must-take power purchase agreements with Cargill Power Markets, LLC; EDF Trading North America, LLC; and Morgan Stanley Capital Group Inc. The companies 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.

E EnerNOC Expands Upon AutoDR Success in New Zealand with Move to South Island EnerNOC 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 industrial 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.

12

April 20122 | www.tdworld.com

I India Awards Alstom Grid Order for EHV 765-kV Circuit Breakers The Power Grid Corporation of India Ltd. has awarded Alstom Grid a contract worth approximately 10 million 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 ultra high-voltage circuit breakers, Alstom Grid is the first manufacturer to localize in India the production of circuit breakers 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, engineering, manufacture, supply, transportation, unloading and on site delivery, including insurance, supervision of erection, testing and commissioning of the 765-kV circuit breakers and support structures. Visit www.alstom.com/grid.

       
       
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BUSINESSDevelopments

P Power Station Demolition Clears the Way y for New Electricity Interconnector with Europe 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 countries. 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 between 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.

F First Wind Secures $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 Oahu’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 progressed 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 generate 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 customers. Hawaii state law mandates 70% clean energy for electricity and surface transportation by 2030, with 40% coming from local 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.com

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SMARTGrid

T Team Announced for Consumers Energy’s 1.8 Million Smart Meter Deployment SmartSynch has announced the team that will help provide the advanced metering system that will form the foundation of a grid and meter modernization program 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 comprehensive 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 Michiichiigan across a 32,000-sq-mile (82,880-sq-km) service territory, the largest U.S. utility lity tyy to choose a cellular-based communications system for the smart meter deploymentt 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.

C y of Medicine Hat Chooses MeterSense City for Meter Data Management The city of Medicine Hat, Alberta, Canada, has selected MeterSense, a division of Harris Utilities, to provide meter data management (MDM) for its electric-delivery 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 customers’ 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 smartmeter program will pay for itself in approximately seven years. For more information, visit www.medicinehat.ca and www.metersense.com.

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C Council Votes City on GWP Smart Grid Opt-Out Option The Glendale (California) city council unanimously voted on charging customers a fee of US$59 per billing period for having electric and water smart meters 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.

V Vermont Utility 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 platform. BED and other Vermont utilities worked together with the state of Vermont 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 residential customers and more than 3,600 commercial customers. The utility was looking 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 functionality and the ability to improve operational efficiencies through reduced truck rolls and better outage management. Visit www.burlingtonelectric.com.

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TECHNOLOGYUpdates

N NEMA Encourages g Action to Expand Meter Socket Lifespan and Inspections 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 components, deformed socket jaws, broken components, failed insulation, damage due to ground settling or vandalism, or any exposed live parts. If any damage is discovered, the meter socket should be replaced by a qualified electrician immediately. For more information, www.nema.org.

ATC Builds Transmission Line in Wisconsin A A new 7.7-mile (12-km) transmission line between the Canal Substation in Sturgeon 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 Transmission 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.

W WECC Contracts with Siemens PTI for Data Collection Tool Siemens Power Technologies International (Siemens PTI) has entered into an agreement with the Western Electricity Coordinating Council (WECC) to deliver WECC’s Base Case Coordination System (BCCS) planning tool. The BCCS solution, based on Siemens 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 completion 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 infinite number of scenario cases and could save the average WECC member an estimated 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.

NERC Reports Loss of Reactive Power and Voltage g Instability Most Likely Outcome from a Geomagnetic Disturbance 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].

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TECHNOLOGYUpdates

C CRC Partners with TextPower to Offer Outage Reporting via Text Messaging Cooperative 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, California, 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.

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April 2012 2 | www.tdworld.com

ABB’s new 69-kV turnkey GIS switchyard provides Anaheim’s peak power demands with greater reliability and cleaner energy through local generating resources.

6 69-kV GIS Switchyard Adds 200 MW for City of Anaheim The Canyon Power 69-kV gas-insulated 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 California to the city of Anaheim’s electrical system. The project now provides up to 150,000 residential customers with additional 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 enhance 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 management and ABB provided the project on a turnkey basis, including all engineering, equipment and construction labor to design, build, test and commission 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 operating and maintenance costs associated with GIS equipment. This GIS switchyard 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.

QuarterlyREPORT

PEVs Move into the Fast Lane B Rick By

Tempchin, Edison Electric Institute

P

lug-in electric vehicles (PEVs) have arrived, and electric 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 offering 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 technology has the potential to connect with other emerging technologies 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 Electric 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 alternative for everyone. Congress, in particular, has a significant role to play in securing a place for electric vehicles in the country’s transportation fleet. The American Recovery and Reinvestment Act of 2009 provided 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 existing 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:

22 April 20122 | www.tdworld.com

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 operational needs M Providing new rate options to customers that will encourage off-peak charging of PEVs M Updating call center training to incorporate PEV knowledge 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 developing 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 Transportation 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 electricity 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 electricity to power even greater progress in the 21stt century. 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.

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CHARACTERSwithCharacter

A Lineman’s Legacy B Stefanie By

Kure, Contributing Editor

Dennis Kerrr, Int’l Lineman’s Rodeo Association

D

ennis Kerr may have retired from DTE Energy (Detroit, Michigan, U.S.) in August 2009, but the 65year-old’s schedule remains busier than an electrical 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 became 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 Lineman’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

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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 every 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 important to the utility industry because they promote safety and skills of the trade. It is dangerous to be a lineman, and participating in these events can help decrease that risk. They’re also a bunch of fun.” According to Kerr, lineman’s rodeos also help raise awareness 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 lineman 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 during 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 excitement 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 dolphins, 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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April 2012 2 | www.tdworld.com

Modern design tools streamline substation work processes. By Gene

Wolf, Technical Writer

D

esigning 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 engineering departments were using almost 100 years ago. Of course, some innovative utilities and engineering firms are pioneering new engineering processes, but the majority of engineering departments are designing substations manually like fine Swiss watches. Each substation is carefully crafted: 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 loadmanagement software. It was not long before focus shifted to the actual transmission and distribution grid. Utilities added sensors, sophisticated monitoring components and diagnostics to the equipment. Computerized protection and control systems grew. Communications came in the form of fiber optics and stand-alone smart substations networked 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 programs. 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 analytical 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 paperbased tasks coexist with some form of computer-assisted processes, 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 manually count the components (length of conduit, number of insulators, nuts and bolts) and fill out requests for purchase orders by hand. Is this the best way to use a critical resource? www.tdworld.com | April 2012

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SUBSTATIONDesign

A virtual substation model improves public meetings and the permitting process. Courtesy of PNM.

Leading the Way Although in the minority, a few organizations have evolved to the 21stt century. They are using digitally enabled technology that is connected across the enterprise, and that is the real story with designing substations in the 21stt century. Utilities such as Public Service Company of New Mexico (PNM), American Electric Power, Duke Energy, Nashville Electric Service (NES) and Progress Energy Carolinas have realized how inefficient 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 substations 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 design a simple distribution substation (transformer, switchgear,

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isolation devices and feeders). Move up in complexity to something 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 automated 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 customization, 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 predefined standardized designs while only 20% or fewer will require some form of customization. That is a pretty good payback 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 configurations, it could streamline the engineering process. “Once the standard configurations were defined, technicians 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 configuration and 3D-DASL did the rest,” Garcia explained. “The menus produce a complete set of detailed construction drawings. The best part of the process is the fact that the drawings

SUBSTATIONDesign

Terrestrial LiDAR can be used in congested locations inside an energized substation without Terrestrial LiDAR mapping equipment in an placing personnel in danger. Photo by Gene Wolf. older substation. Courtesy of Merrick & Co.

are 3-D, only minimal training was necessary for the designer and the design/drafting process has been reduced from several 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 substations and retrofits to existing stations. NES’s engineers have

created a library of parts or blocks for equipment and substation 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

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SUBSTATIONDesign

A 3-D substation model generated from AutoCAD using 3D-DASL plug-in. Courtesy of PNM.

design process. The utility saw the need to link software, databases 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 other 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 software offers utilities some interesting 3-D substation modeling and integrated connections between MicroStation, ProjectWise and ORACLE SQL databases. Consulting engineering companies also are adapting tools to improve their efficiency. Black & Veatch offers 3-D renderings with automated links to other business systems. POWER Engineers is developing a smart one-line diagram with embedded 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 utilizing 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, foundations, bolts, wire jumpers and everything else needed. The cells will allow for complete BOM to be generated by the software rather than have skilled designers manually count parts and components,” he reported.

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April 2012 2 | www.tdworld.com

Global Interest The 3-D substation design is a worldwide phenomenon. Hydro-Québec started developing its internal 3-D CAD capabilities in 2004. The utility uses software from Dassault Systèmes to build up its 3-D substation modeling system. HydroQuébec 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 Shanghai 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 process. 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 technicians can take a laser snapshot of the substation without being exposed to any dangerous clearance issues normally associated 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

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SUBSTATIONDesign single-line analyzer function. The software is used for designing IEC 61850based 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, assists the engineer with connections and lays out the communications system. This program replaces all the vendor tools previously required to link IEDs and SCADA, simplifying the process and removing all the iterations previously required between sessions with the separate vendor tools. A 3-D LiDAR isometric model of a substation. Courtesy of Merrick & Co.

making accurate measurements and identifying clearance issues 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 surveying of a substation expansion. A traditional surveying company included five days of expenses for a crew of three in its proposal. An engineering company using GPS surveying methods 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 documentation, 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 database and links to equipment databases. In a nutshell, anyone in the enterprise with access to a computer can view the 3-D LiDAR model. The panoramic photographs 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 software called System Engineering Tools, which includes a

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April 2012 2 | www.tdworld.com

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 documentation 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 produced from the response. Project inventory is managed from receipt to issuing to installation without data being reentered. And that is only the beginning of 21stt century technology 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

J

Enclosure Solutions

SMAR SM ART TGr Grid id

Wired for ucc ss KCP&L P&L is retrofitting g Midtown Substation S Substa ubstation atio on with updated communications protoccols as partt off a DOE smartt griid demonstrattion project. By Ed

Hedges, Kansas City Power & Light Co., and Mattthe hew w Ol Olso son, Burns & McDonnell

T

he 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 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 Reinvestment Act of 2009. The two largest elements of this funding 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 demonstrations “to verify smart grid viability, quantify smart grid costs and benefits, and validate new smart grid business mod-

Mark Adams of KCP&L, a protection and control engineer 1, programs a protective relay.

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April 2012 2 | www.tdworld.com

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 emergemerg 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 Electrotechnical 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

Dan Bayouth, Burns & McDonnell engineer, testing network performance in the Smart Grid Lab.

SMARTGrid Smart generation Solar

Biofuel

Voltage/VAR management

Back office

Electric storage

Grid management

Demand response

Smart building Office building Distributed energy resources

Smart meter School

Rooftop solar panel

Smart substation

Web portal

Smart distribution Rooftop solar panel

Commercial building

In-home display Smart end use

Public charging station

Digital thermostat Time-of-use Electric pricing vehicle

Time-of-use pricing

Building energy management system

Home area network

Technologies demonstrated in KCP&L’s Smart Grid Demonstration Project.

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 function 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 automation 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 communications-centric design technologies that originated in the information technology industry and are now being applied to power delivery. KCP&L partnered with Burns & McDonnell

Ethernet Communications Simplifies Substation Control Using 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 operation and the ability to queue packets in the switch. Queuing provides Quality of Service (QoS) by giving priority to time-dependent 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.

www.tdworld.com m | April 2012

37

SMARTGrid

Load transfer

Cross triggering Faster overcurrent tripping Backup overcurrent tripping

SEL-487E transformer

SEL-451 main

SEL-751A tie

SEL-487B bus Publishing

Subscribing

SEL-751A feeders

GOOSE message flow diagram for Midtown Substation.

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 transformer. 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 feeder 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 continually 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 distribution 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 indicating an operation where a stuck breaker timer is initiated.

SMARTGrid

Switchgear enclosure

Switchgear enclosure

Bus 4 relays

Bus 3 relays

Bus 1 relays

Bus 2 relays

RuggedCom RSG 2100

Cisco CGS 2520

RuggedCom RSG 2100

Cisco CGS 2520

Intra-ringtie

Control enclosure Primary system

RuggedCom RSG 2100 root

Backup system Cisco CGS 2520

Substation firewall DMS – HMI Siemens SICAM PAS

XFMR relays

RuggedCom RSG 2100

Cisco CGS 2520

RuggedCom RSG 2100

Cisco CGS 2520

Bus 6 relays

Bus 5 relays

Bus 7 relays

Bus 8 relays

Switchgear enclosure

Switchgear enclosure

The Midtown Substation communications network.

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 relay provides redundancy to the logic, sensors and wiring in the feeder relays, allowing them to trip a feeder with a reclosing function if the feeder relay fails to detect or clear a fault.

SMARTGrid To control enclosure

Fiber distribution panel

Backup system

Primary Ethernet switch RuggedCom RSG 2100

Primary system

P1A P1B SEL-751A bus tie

P1A P1B SEL-751A feeder

P1A P1B SEL-751A feeder

P1A P1B SEL-751A feeder

P1A P1B SEL-751A feeder

Bus tie

Feeder 4

Feeder 3

Feeder 2

Feeder 1

Aux 2

To adjacent bus

P1A P1B SEL-487A bus

P1A P1B SEL-451A-5 main

Aux 1

Main

Typical switchgear physical arrangement.

The bus differential relay uses its current circuit and sensor to monitor the feeder, and it is programmed to send a GOOSEbased 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 implement. Using the common communications bus reduces the cost of implementing these additional schemes to programming 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 information. This information explains how the protection and control 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 impossible 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-

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April 2012 2 | www.tdworld.com

tion. As part of the pilot, the Midtown Substation was retrofitted 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 redundancy. 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 proprietary protocol for blocking loops from forming in the Ethernet 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 communications. 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 scheduling an outage on the protection LAN. All relays except the transformer protection relays were installed on the doors of switchgear cubicles. The fiber jumpers

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 mechanical 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 preterminated 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, providing redundant connectivity. Using a hardened pre-terminated fiber system reduces outage duration by eliminating any field terminations and special training for the electricians performing the relay replacement. The hardened cable eliminates 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 control of the substation will be through a centralized 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, serial communications will be maintained to each relay from the substation remote terminal unit to support dual communications 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 management 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 networkconnected clock could be used to provide time coordination through the redundant fiber Ethernet connections, eliminating additional wiring.

Ready for IEC 61850? Deploying IEC 61850 requires coordination and crosstraining from at least four areas of the organization: protection and control, information technology, security and compliance, 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

www.tdworld.com m | April 2012

41

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 acquisition (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, capacitors 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 isolate 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 construction, but this project showed that it brings the same benefits to an existing substation. Using IEC 61850 in a retrofit applica-

JSHP

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 processing in the station. KCP&L’s demonstration project is modernizing power delivery in its demonstration area by leveraging the knowledge and capabilities of information processing to restore service and protect equipment from failure. Deploying new technology, 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 responsible 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 professional engineer in Wisconsin.

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April 2012 2 | www.tdworld.com

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 packet-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 registered 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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VEGETATIONManagement

Extreme ice loading caused a tree to fall on this 110-kV transmission line.

LiDAR to the Rescue A severe ice storm in Russia leads to re-evaluation of ROW status and vegetation management practices. By Boris

Mekhanoshin, JSC IDGC Holding

F

rom Dec. 25, 2010, to Jan. 10, 2011, several regions of Russian, including the city of Moscow and the surrounding district, were affected by an unusual meteorological 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 previous 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 widespread 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.

44

April 2012 2 | www.tdworld.com

Widespread Network Damage The overall picture of disturbances from this event occurred in the Moscow, Nizhny Novgorod, Smolensk, Tver and Pskov regions. There were three separate occasions, each lasting three hours, when the outages occurred at 133 master substations 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 substations 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, substations, relay protection and automation systems remained undisturbed throughout this period. According to published data, 470,000 people were without electricity for two to three

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50 22 31

600

588

500

464

200

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621

562

700

273 110

394

424

152 358

297 145 110,5 91,5

131 256

111 97

50

70 59

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39 49

22

37 17

74

85

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22 12,2 9,5 5,3 4 2 2 12

55 53

334 255

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69

311 270 91

92

282 300 247

200

63

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12 3,6 3,6 5 0 0

400

382

384

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Number of repair crews

Number of outages (thousands)

Involved repair crews Tripping OHL 35-220 kV Tripping substation Tripping citizens

690

300

300

42 31 8,4 16 13 3 2,1 3 0 1 0 1

100 12 01

0

06- 12- 18- 23- 10- 20- 12- 06- 23- 07- 22- 06- 18- 06- 11- 12- 21- 08- 14- 12- 16- 14- 20- 16- 2000 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 12/26

12/27

12/28 12/29

12/30

12/31

01/01

Week 1: Dec. 26-31, 2010

01/02

01/04 01/06 01/08 01/09 01/05 01/07 Week 2: Jan. 1-9, 2011

01/03

Date for outage count and crew deployment Electricity supply limitation was terminated Jan. 7, 2011.

Number of tripping and repair activities during two weeks with freezing rain.

Breakdown Cause

180 Overhead line outages per year

days while some localities, with severely damaged overhead line feeders, were without power for nearly two weeks. The three peak disturbances and breakdowns occurred during the period when the freezing rain was at maximum intensity.

160 140 120

Total number of the overhead line emergency tripping Successful automatic reclosing Unsuccessful automatic reclosing Automatic reclosing disconnected

100 80

The main causes of the wide60 spread power outages in the Moscow region were trees falling on power 40 lines and their crowns touching the 20 conducting parts of transmission lines because of the weight of accu0 2008 2009 2010 2011 mulated ice. Ice accretion is caused (January to April) by anomalous meteorological conYears ditions: sudden warming, long-term super-cooled liquid precipitation The number of overhead line outages per year in MOESK‘s eastern grid. (freezing rain), and intensive icing on trees and along overhead lines, conductors and towers. forestry in the Moscow region. Long-term discussions about Based on research conducted in the United States, the average forest usage rules and the requirements of the electrical instaltime of freezing rain is 2 hours to 4 hours for humid regions, lation rules had prevented utilities from adequately maintainwhereas the Russian weather data for freezing rainfall in the ing the ROW. In August 2011, new legislation was approved Moscow region for this event lasted for 14 hours, exceeding that allows adequate ROW to be created and maintained for the monthly average rate of adverse weather by four to seven each voltage class. times. To assess the extent of the technical breaches caused by The primary cause of the massive loss of electricity sup- freezing rain, results based on a special analysis of sample data ply was insufficient ROW clearance for power lines routed of overhead line outages for the period from 2008 to April through forests that belong to a special category of protected 2011, provided by the Eastern Electricity Grid department of

46

April 2012 2 | www.tdworld.com

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VEGETATIONManagement ROW Width for Overhead Lines with Bare Conductors Nominal voltage (kV) to 1 1 to 20

ROW width in meters (feet) 2 (6.6) 10 (32.8)

35

15 (49.2)

110

20 (65.6)

150, 220

25 (82.0)

300, 500

30 (98.4)

supporting towers. With insufficient width of ROW, it was difficult 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 January 2011, utilities have continued to remove trees, cutting crowns and branches in close proximity to overhead line conductors. They have already removed more than 40,000 trees from the overhead line corridors. To further improve the reliability of supply, there is a planned expansion of the use of insulated conductors for the 1-kV to 35 kV overhead lines.

LiDAR Surveys

The typical result of ice accretion on trees too close to lines is a predictable meeting of vegetation and line.

MOESK, were examined. The data confirmed the total number 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

Airborne laser survey (ALS) of overhead lines is now widely used by utilities for updating the as-constructed documentation and monitoring the in-service condition of all overhead line components. This includes conductors, ground wires, towers, line insulation and the various buildings and structures located near the ROW. JSC IDGC Holding regularly requests its 13 regional utilities 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 vegetation. 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 Holding JSC IDGC Holding, a company operating in the electricity sector of the Russian Federation, comprises interregional distribution 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).

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April 2012 2 | www.tdworld.com

VEGETATIONManagement

Result of ALS processing, the yellow denotes vegetation that needs to be cleared from the ROW (left). A span of double-circuit overhead line where each tree is taller than the phase conductors (right).

Maximum Permissible Current for 110-kV Overhead Lines “TPP 21 – Novobratcevo” in Different Weather Conditions Conductor: 150 kcmil ACSR Wind speed, m/s

Admissible continuous current, Amperes at an ambient air temperature, °C -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

(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 internal 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 requirements is used by utilities to determine the type of trees or shrubs to be cleared and the area of the ROW requiring clear-

The NDT device inspecting damaged conductors.

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 required 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 conductor ground clearance should not be less than 6 m (19.7 ft). This is the reason why vegetation causes phase-to-earth shutdowns 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). www.tdworld.com m | April 2012

49

VEGETATIONManagement Ground Clearance

A Satisfactory Condition

Another result of the JSC IDGC Holding overhead line ALS showed a significant number of violations for line specification 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 overloading of the freezing rain that caused abnormal conductor elongation.

Central Russia experienced a sequence of abnormal weather conditions that started with an anticyclone in the summer 2010 that caused numerous forest and peat fires. 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 confirmed the main contributing cause of the disturbances was the unsatisfactory condition of the overhead line ROW. ALS proved to be a highly effective means for planning vegetation 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 acknowledge the technical assistance and support received during the preparation of this article by Vladimir Shkaptsov and Konstantin Konchenko at OPTEN Ltd.

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Boris Mekhanoshin (Mekhanoshin-Bl@ holding-mrsk.ru) started his career in fiber-optic communications at the Moscow Power Engineering Institute. He then worked for the chair of Radio Transmission Devices and has been involved with fiber-optic technology until he joined ORGRES, where he established the first fiber-optic systems laboratory for the Russian electric power industry. In 1992, he was appointed deputy general director 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.

Companies mentioned:

ERLPhase Power Technologies www.erlphase.com

50

April 2012 2 | www.tdworld.com

204.477.0591 [email protected]

JSC IDGC Holding www.holding-mrsk.ru OPTEN Ltd. www.optensolutions.com

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CUST ST TOM O ME ER REn E ga gage ementt

Gllendale Water & Power invvests in customer outreach, gaining early and continuous support pp for its sma art grid project. By Glenn

O. Steigerr, Glendale Water & Power

I

n 2011, Glendale Water & Power (GWP) completed installation of more than 120,000 smart electric and water meters, one of the utility’s largest projects, which started in 2009. The municipal utility in Glendale was one of the first U.S. utilities to connect and integrate all of its electric and water customers using smart grid technology. Some of the other fi firsts rsts included being the first 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 first introduced its smart grid business plan to the city council, the entire project was expected to take approximately five years. In 2009, the utility applied for and won the DOE grant. Then, in 2010, GWP completed its proof-of-concept phase, testing out 1,000 electric and 500 water meters. Smart meter installation started in

One of the key elements of the smart grid is this smart meter.

52

April 2012 2 | www.tdworld.com

late 2010 and was completed by September 2011. GWP P expects to be fully functional in all aspects pertaining to thee meters, including meter data maanagement, in two years ratther than five years.

Keeping Customers En ngaged Customer engagemen engagement nt is an extremely important aspect of any smart grid project. Keeping information flowing to customers, 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 continuous supporters of the project, GWP had to educate and inform them of the benefits of the technology and how they, specifically, would benefit 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, everything was working just fine. GWP’s first task was to let customers 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

“Coffee in the Park” is one of the GWP customer outreach events held to communicate smart grid benefits.

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CUSTOMEREngagement changed much in the last 100 years. It was time to implement change and start showing the benefits. Having learned from the miscommunication mistakes of investor-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 project so as to inform and educate customers of what was coming and how the smart meters and smart grid would benefit them. Every project milestone was publicized. Prior to installations, cus- Smart meter installation is a “process step” that is preceded by considerable customer outreach tomers received a letter about the activities. coming installation and why it was necessary. They received tion on the project, and provided input on outreach materials. All customer outreach, including the utility’s external newsbrochures and bill inserts on frequently asked questions. GWP gave the city council and commission frequent project status up- letters, website and social media sites, had a special section dates. The utility also created a stakeholder advisory committee devoted to this project with progress constantly being highmade up of city residents and business owners who met with the lighted. GWP also attended every community event sponsored utility on a monthly basis and shared their insight and informa- by the city, distributing smart grid educational materials and ®

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CUSTOMEREngagement

Smart Grid Maturity Model Glendale 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 Defining the Pathway to California’s 2020 Smart Grid for Publicly Owned Utilities. According to the survey’s findings, 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 transformation 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.

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 benefits. The purpose was to go to the customers to engage and educate them on the new technology.

56

April 2012 2 | www.tdworld.com

Extensive outreach is a definite must for any utility pursuing a smart grid project, because keeping customers in the know, along with giving them information and progress updates, will help them eventually adopt and adapt to the new technology, and the many changes it will bring them.

Transformers

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Power Electronics

CUSTOMEREngagement

Communications is the underpinning of the smart grid.

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 meters 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 project came together by chance for GWP when a company approached the utility. At a 2009 conference, 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 information 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

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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 Centerr . . . . . . . . . . . . . . . . . . . . . 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

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April 2012 2 | www.tdworld.com

Booth 1281

Roadmap for self-healing distribution grids Siemens ENEAS solutions for distribution automation

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 supply systems to future needs becomes possible.

Precise fault location creates the basis for automated switching and highly efficient workforce management. Design, development, configuration changes, and updates of automation equipment are made easier. Asset data enable the reduction of maintenance times.

Distribution automation is the interface between the medium-voltage and low-voltage systems. It provides the option to completely monitor and automate all controllable devices, such as reclosers, breakers, and switches. Siemens ENEAS solutions for distribution automation are field-tested and based on proven Siemens devices.

Siemens ENEAS solutions for distribution automation create the highest possible degree of reliability, and the basis for sustainable success in a cost-efficient way.

ENEAS solutions for distribution automation enable flexibility in design for comprehensive control of the entire distribution network. Siemens ENEAS solutions implement new business models in the framework of Smart Grids.

Medium-voltage

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.

Monitoring Fault detection and location

Low-voltage

E50001-E720-F338-X-4A00

www.siemens.com/eneas

Power quality

Asset monitoring

Automation Restoration Reconfiguration Self-healing

Grid quality

Low-voltage control

Answers for infrastructure and cities.

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Dow Electrical & Telecommunications will have experts on hand to talk about the company’s offerings: M Commercialization 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 Significance of growth in the Dow Inside program that boasts an increasing number 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 product experts 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 substation M Vacuum tap changer and control panel M 362-kV dead-tank circuit breaker M 72-kV live-tank vacuum breaker M Surge arrester M Medium-voltage gas-insulated switchgear M Distribution recloser M Disconnect switches M 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 lines M Voltage regulators. Siemens | www.usa.siemens.com/power-transmission Booth 2747

Time Domain Reflectometer

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April 2012 2 | www.tdworld.com

The AEMC Fault Mapper Pro is a hand-held graphical TDR (time domain reflectometer) designed for identifying and locating faults on power cables, given access to one end only. The Fault Mapper Pro measures cable length and indicates the length and distance to cable faults to a range of 9 ft (3 m) to 19,000 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 the pulses travel is determined by the type of cable, which is known as the velocity of propagation (Vp) of the cable. The Vp is adjustable between 1% and 99% enabling accurate calibration to the cable under test. The Vp value, expressed as a percentage of the speed of light, will vary according to the type of cable under test. The Fault Mapper 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 reflection profile 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 identification of cable pairs. AEMC Instruments | www.aemc.com Booth 702

What does it take to make the Smart Grid

SMART? Check out T&D World’s new Grid Optimization PLFURVLWHWR¿QGRXW