Peninsula Light Co., a member-owned electric cooperative in Gig Harbor, Washington, is using TextPower SmartAlerts to communicate quickly, easily and directly with utility members during extreme weather and power outages, the text messaging software provider announced.
“Our services have evolved over the years and we’ve done a tremendous amount of integration to take advantage of the latest technical advances,” said Jonathan White, director of marketing and member services at Peninsula Light Co. “Partners like TextPower keep us at the forefront of the industry and enable us to provide our members with easy to use communications that deliver significant savings in both costs and human resources.”
The Peninsula Light Co. system allows members to manage their accounts, make payments, report outages and receive instant information about outages. Caller IDs are matched to accounts by the system, saving time and streamlining the process by tracking the address, meter number and identifying the supporting substation. The system is refreshed daily with updated information.
Members can report outages by phone or text after their accounts are activated. During an outage, the member’s phone number is stored so the utility knows who is calling or texting. It provides the location of the outage, which helps crews respond faster. Members simply text the word “out,” and the system sends a message back to verify there is an outage at that location.
Executive Chairman and TextPower co-founder Mark Nielsen stressed the versatility that comes with being able to use cell phones and texting.
“With SmartAlerts, users are able to activate by phone or text in less than a minute, providing all of the necessary information Peninsula Light would need to immediately alert their customers when facing a situation that could result in power failure,” Nielsen said.
The program rolled out about a year ago and supports some 2,000 members. Peninsula Light Co. deploys the Milsoft outage reporting system and works with the Cooperative Response Center, an after-hours call and dispatch center. TextPower integrates with both platforms.
Despite the area’s generally mild climate, White said, it experiences major ice and wind storms every few years. The utility serves two peninsulas and the Fox, Heron and Raft Islands. The only source of transmission to the peninsulas is a phone line originally installed in 1924-the longest span of transmission line at that time.
“When we lose the line, we lose everything including communications to all eight substations,” White said. “Everything from storms to large birds to logging trucks have damaged the line, not to mention occasional equipment failure itself. Our goal is to move completely to text technology.”
Previously the utility had to bring in 12 to 16 members of the call center staff to answer the phones 24/7 until a storm was over. Regular dispatch was available during business hours Monday through Friday, and the outage reporting system simply would shut down after 4:30 pm.
The utility needed a better system to support the community. Working with TextPower and Milsoft, Peninsula Light Co. developed a notification system that would text information to the support team’s smartphones, use Google Maps to identify locations, and be managed through Microsoft Outlook. The utility wrote its own outbound communications protocol, and after a day spent writing the code, the communications system was self-managed, freeing staff for other responsibilities.
“We were the first utility in the U.S. to write code for the outbound notification as it came into the reporting system,” White said. “We were also the first utility to use TextPower texting with Milsoft. We proudly were successful beta testers for the very first integration, and the ROI was already demonstrated before we even implemented texting.
“Eventually we will even move our own telecom system, including the outage reporting system, to the cloud for even greater cost savings and will also provide greater phone capacity for those who do call in.”
Since 1925, Peninsula Light Co. has been serving the Gig Harbor and Key Peninsulas and Fox Island in Western Pierce County. PenLight is a “full requirements utility” of the Bonneville Power Administration. The utility has grown to be the second-largest cooperative in the Northwest, serving more than 31,000 meters with 977 miles of line and 112 square miles of service territory. The company also provides service to 3,230 water consumers.
Frost & Sullivan: Grid Modernization Efforts Stabilize Demand for North American T&D Services
The Environmental Protection Agency’s (EPA’s) impending regulation to lower power plants’ carbon emissions is projected to shape demand for transmission and distribution (T&D) services.
Working toward cutting emissions 30 percent by 2030 from 2005 levels, utilities already have achieved reductions of 14 percent. Ongoing work in network renewal, new generating capacity and reconfigurations will translate into revenue growth for the T&D services market.
New analysis from Frost & Sullivan, “Analysis of the North American Transmission and Distribution (T&D) Services Market,” finds that the market earned revenues of $20.43 billion in 2013 and estimates this to reach $20.94 billion in 2018. Key market segments of T&D services are engineering and consultancy, construction and operations and maintenance.
The North American T&D services market has benefitted from major investments in generation, T&D infrastructure in Canada and the U.S. These investments are driven by the need to:
- Renew aging equipment;
- Improve reliability and performance of electrical networks; and
- Ease grid congestion.
Utilities are making considerable investments to protect T&D infrastructure from natural and man-made disasters. For instance, in the wake of devastation caused by Superstorm Sandy in October 2012, utilities redoubled their efforts to stormproof the distribution network. This proved to boost the T&D services market significantly.
“Despite greater outsourcing of T&D tasks, the market has remained conservative in certain areas,” said Farah Saeed, energy and environmental principal consultant with Frost & Sullivan. “Small electrical jobs and support for distribution voltage projects are still offered in-house; however, there is growing demand for external support for numerous transmission projects.”
With utilities’-especially investor-owned utilities’-increasingly evaluating financial performance, there is a keen desire to slash noncritical investments and outsource noncore activities to save on all aspects of maintenance. This bodes well for T&D players, but they also are diversifying their operations in new verticals and acquiring companies to counter the sluggish investments during the past decade.
Nevertheless, the revenues from transmission services are expected to fall until 2018, as major projects near completion. In contrast, services for distribution projects will become important as this sector benefits from higher investment, as well as outsourcing to contractors.
“Although transmission infrastructure will continue to attract the headline projects, developments in the distribution sector will provide more diverse opportunities, especially in areas such as data management and environment conservation,” Saeed said.
TransmissionHub: 2014 Transmission Investment Strong, Less Than Expected
by Corina Rivera Linares, TransmissionHub
Transmission investment in 2014 is strong but less than what it was expected to be at the beginning of the year, going from a combined value of some $14.1 billion of projects expected to be energized or completed this year to some $12.8 billion now, said Kent Knutson, director of Hub Services for PennWell.
Some projects have been pushed into a future year, and some that were scheduled to be online or under construction remain in development.
Knutson also said during TransmissionHub’s Sept. 24 Quarterly Market Update that of the $28.1 billion in projects expected to come online in 2015, $13.8 billion are under construction.
“I believe that some of the projects still in development will get pushed into future years,” Knutson said.
Transmission investment in 2017 and beyond will depend largely on how fast conceptual and planned projects move through development, he said.
Transmission development activity in October has been slow.
According to Knutson’s presentation, the top 15 companies investing in transmission during the past three years include ATCO Electric with some $3.2 billion; AltaLink Management with some $2.3 billion; San Diego Gas & Electric with some $2.3 billion; Southern California Edison (SCE) with some $1.5 billion; and Electric Transmission Texas with some $1.1 billion. Some of this investment reflects projects that are under construction and expected online by year-end.
Also, from 2015 to 2018, the average transmission investment in the U.S. and Canada is forecast to top $26 billion annually. The total value of planned projects’ being tracked by TransmissionHub is $165.8 billion-50,193 miles. Because much of that remains in development, the actual investment likely will be less than anticipated, Knutson said.
The bulk of the investment in 2015 is planned within PJM Interconnection, followed by ISO New England (ISO-NE), the Alberta Electric System Operator and the Midcontinent ISO.
In 2013, Knutson said, projects valued at $12.5 billion were energized. This year, $5.5 billion has been placed in operation, $4.9 billion is under construction and $2.4 billion is still planned, for a total of $12.8 billion. Knutson also said that in 2016, $19.2 billion is expected to be energized, with only $400 million of that under construction.
The top projects in the U.S. and Canada operating as of October, Knutson said, include BC Hydro’s approximately $736 million, 214-mile, 287-kV Northwest Transmission Line; NV Energy’s and LS Power’s approximately $552 million, 235-mile, 500-kV ON Line Transmission Project; AltaLink Management’s approximately $408 million, 94-mile, 240 x 2-kV Cassils to Bowmanton project; Public Service Electric and Gas’ (PSE&G’s) approximately $390 million, 55-mile, 230-kV underground and aboveground North Central Reliability Project; and PSE&G’s approximately $381 million, 37-mile, 230-kV underground and aboveground Burlington to Camden project.
The top projects in the U.S. and Canada that remain under construction as of October included ATCO Electric’s approximately $1.8 billion, 310-mile, 500-kV HVDC Eastern Alberta Transmission Line; SDG&E’s approximately $435 million, 141-mile, 138-kV underground and aboveground East County to Boulevard project; ITC Holdings’ approximately $300 million, 122-mile, 345 x 2-kV Great Plains (Kansas V-Plan) project; AEP Ohio’s approximately $239 million, 217-mile, 138-kV Vassell Station Project; and ATCO Electric’s approximately $237 million, 82-mile, 240 x 2-kV Ells River Substation Transmission Project.
Furthermore, the top projects scheduled to come online in 2015 that are under construction as of October in the U.S. and Canada include SCE’s approximately $1.7 billion, 250-mile, 500-kV Tehachapi Segments 4-11; AltaLink Management’s approximately $1.7 billion, 215-mile, 500-kV HVDC Western Alberta Transmission Line; Central Maine Power’s approximately $1.5 billion, 440-mile, 345-kV Maine Power Reliability Program; PSE&G’s approximately $1.4 billion, 145-mile, 500-kV Susquehanna-Roseland Project; and PSE&G’s approximately $907 million, 50-mile, 230-kV underground and aboveground Northeast Grid Reliability Project.
Looking at transmission investment by objective, for instance, in 2014 and 2015, the bulk of investment is being driven by reliability, followed by multivalue and renewable purposes.
Discussing news highlights from July through September, Knutson said, for instance, that the Ontario Energy Board chose NextBridge, formerly Upper Canada Transmission, to build the East-West Tie Line, with NextBridge to submit an application in January; the proposed merger between Exelon and Pepco Holdings continues to advance; and the nominations of Norman Bay and Cheryl LaFleur to the Federal Energy Regulatory Commission cleared the Senate.
Knutson noted his optimism for the transmission industry, citing such investment plans as the one by National Grid USA to spend $8.57 billion between 2015 to 2029, as well as FirstEnergy’s plan to spend $2.8 billion over four years.
Among other things, Knutson’s presentation noted that within ISO-NE, since 2002 there have been 500 transmission upgrades at a cost of $5.6 billion, with planned upgrades from 2014 to 2017 estimated to cost $5.4 billion.
Doble Engineering Co. Opens Houston Insulating Materials Lab
Doble Engineering Co. announced the opening of a new insulating materials laboratory in Houston.
The facility is Doble’s fourth oil lab in the U.S. and will provide the Gulf Coast region with local access to comprehensive laboratory, condition assessment and innovative testing solutions.
Opened to meet the needs of Doble’s transmission, distribution, generation, industrial and service organization clients, the lab will help customers make decisions regarding the health and reliability of their critical, large electric power assets.
“Laboratory diagnostics are a crucial component of a comprehensive condition assessment program,” said Paul Griffin, vice president of consulting and testing services at Doble. “Our goal is to give customers the objective diagnostic information they need to address their day-to-day and strategic challenges. Opening a lab in the region will help us to do that more effectively.”
Doble’s labs perform more than 200 tests on liquid and solid insulating materials, including ASTM and IEC tests for dissolved gas analysis, water content and oil. At Doble’s Massachusetts headquarters, the company also provides high-voltage laboratory testing solutions up to 300 kV AC, 400 kV DC and impulse testing up to 1,200 kV for transformer components, rotating machine stator bars and cable and accessories testing.
Demand for power in Texas is growing at nearly twice the national average.
The state is also the largest energy generator in the country, including leading the U.S. in wind-power generation capacity with more than 12,000 MW.
Constellation Gives $100 Gift Cards to Customers Who Buy Honeywell Smart Wi-Fi Thermostats
Power provider Constellation and Honeywell recently introduced an energy-saving service plan available to millions of homeowners and small businesses across 23 states.
By enrolling in the plan to meet their gas and electricity needs, customers can lock in competitive prices and receive up to a $200 gift card from Constellation for buying any Honeywell Wi-Fi thermostat, including the new Lyric.
The plan builds on the companies’ regional efforts in Texas-and Honeywell’s decades-long experience in linking energy suppliers and users-bringing the thermostat offer to residents and business owners in states where Constellation does business, which covers an estimated 30 million homes alone. If only 20 percent of eligible homeowners signed up and installed the technology, they would trim their collective energy spend by some $768 million each year, a rate of $128 per household based on estimates from GreenOhm and Honeywell for the annual savings a programmable thermostat can deliver.
Customers can get the Wi-Fi devices at low or no cost with a gift card-$100 for home electricity service, $100 for gas service or $200 for both. The offer doubles for small businesses.
“Competitive rates, stability and energy management provide an excellent value for consumers and businesses,” said Bruce Stewart, senior vice president and chief marketing officer for Constellation. “Honeywell and Constellation are offering great customer service and technology, and that means value without having to sacrifice quality or comfort.”
Constellation customers can choose from Honeywell Wi-Fi connected thermostats available online and in retail stores, as well as through local contractors.
The devices can be set and managed from virtually any computer, tablet or smartphone using Total Connect Comfort, the top-rated thermostat app on iTunes and Google Play, or the Lyric app.
Ameren Teams With Vendors for Smart Grid Operating Solutions
|Typical 15-kV S&C IntelliRupter PulseCloser installation|
St. Louis, Missouri,-based Ameren Corp., recently teamed with Omicron and S&C Electric Company to verify S&C IntelliRupter PulseCloser operation.
Ameren, a utility that provides electric service to 2.4 million customers in Missouri and southern Illinois, wanted to modernize its grid technology and improve reliability. The utility partnered with S&C Electric Company and was one of the early adopters of the company’s IntelliRupter, an integrated protection and switching device. Ameren now operates a fleet of more than 500.
The utility’s normal practice for distribution system protective devices is to prove correct operation by testing the configuration, validating the overcurrent settings, and confirming system performance.
Ameren routinely checks all of its electromechanical and electronic protection relays for correct operation upon initial installation and on a cycle. Unlike stand-alone protection relays, the IntelliRupter’s integrated protection and control module could not be verified with conventional test equipment, preventing Ameren from testing to its desired standards.
The control module can be removed easily and connected to an S&C docking station, which provides control power, communication access and a connection point for a computer or Wi-Fi access to the attached control module for verification of the control configuration and communication performance. The docking station does not test operation of the IntelliRupter’s configuration and protection settings.
To test the device’s protection performance, Omicron developed the RIR1 IntelliRupter Testing Package for analyzing the settings, functions and logic of an S&C IntelliRupter protection and control module. It connects between the control module and docking station to enable an Omicron CMC Relay Test Set to inject secondary test signals into the control module. These signals simulate the unique output of IntelliRupter sensors that would be produced by primary voltage and current. The RIR1 also provides a mechanism simulation that allows the control module to react as if it were still installed in an IntelliRupter executing the advanced mechanism operations associated with S&C’s PulseClosing Technology. The Test Set then monitors control module commands that would operate the IntelliRupter to verify the response of the control module to the injected voltage and current signal simulations.
The test quickly demonstrated its value. A protection issue was uncovered that could have led to a possible miscoordination in the field.
Omicron’s Test Universe simplifies the automated testing of complex settings. A PC computer is connected to the CMC Test Set by Ethernet and is connected to the serial port on the docking station or through a Wi-Fi connection to the control module. The Universe program controls the injection of the simulated sensor signals into the control module sensor inputs then analyzes the resulting operations commanded by the control module to the RIR1 mechanical simulation interface.
The IntelliRupter current sensors are Rogowski coils, which provide a very low-level voltage output that is proportional to the integral of the primary current. The coils provide an accurate and linear representation of system current. An extremely accurate low-level signal is required to simulate their output. The CMC Test Set has a built-in Rogowski coil simulation that accurately provides the low-level outputs that are configurable and scaled via the Test Universe software, allowing the user to work with primary current values in the test modules. The voltage sensors are high-impedance sensors that are integrated into the interrupting unit. These sensors are also accurate and provide a low-level output. The CMC Test Set uses its low-level voltage outputs to simulate the voltage signals, which also are configurable and scaled via the Test Universe software, similarly allowing the user to work with primary voltage values in the test modules.
The Test Universe software is made of modules that combine into a test plan that allows the protection relay or an IntelliRupter control module to be tested automatically. The simple “Quick CMC module,” for example, can verify the response of the control module to input changes for the manual operation levers. To test more complex features such as the PulseCloser technology, the state sequencer module is required. The state sequencer controls the timing and magnitude of the voltage and current signals that are applied and monitors the mechanical simulator’s response to the control module commands. The state sequencer then analyzes the response in the context of sent signals and displays the results as a pass or fail recorded in the test plan. Once a basic test plan has been created, adapting it as the protection criteria change from one installation site to the next is accomplished easily by importing the IntelliRupter settings from an IntelliRupter setting file. This feature helps automate the test plan setup and allows changes to the test plan to be made quickly and programmatically.
Ameren is expanding its IntelliRupter System to include 34-kV subtransmission. Now that it has the capability, Ameren will test every 34-kV IntelliRupter before putting it into service. Every IntelliRupter can be site tested. Because a control module can be removed and replaced without reconfiguring the substitute module, the IntelliRupter can stay in service with a replacement module while its control module is tested. When the control module is replaced, the stored settings from the original IntelliRupter are transferred to the replacement module, allowing it to operate just like the original control module. Ameren plans to expand its control module testing to include every IntelliRupter, with the goal of testing them all on a 5-year cycle-the same as its protection relays.
In addition to the secondary injection testing of each new 38-kV IntelliRupter as it is installed on Ameren’s 34-kV systems, it will be subjected to other tests by Ameren. The first step is high-voltage testing of all bushings in the warehouse to verify voltage sensors and IntelliRupter readings before sending the IntelliRupter to the field. Once on-site, the control module is tested on the Test Set as part of the final commissioning. The last step is to measure the primary current at the site with a clamp-on amp meter and compare the readings with the actual current reported by the IntelliRupter.
For the next step, Ameren Illinois and Ameren Missouri plan to combine their Test Sets and test multi-IntelliRupter automation. Team member operation in an S&C IntelliTeam SG Automatic Restoration System will be analyzed using simulated protection operations. Multiple Test Sets are accurately time-synchronized to within a millisecond by GPS time clocks. Installing a communication module with the control module at each docking station allows communication among controls, making it possible for them to collectively respond to the simulated signals provided by the synchronized test plans executing on each CMC Test Set. This allows comprehensive verification of the fault isolation and system restoration procedures provided by the S&C IntelliTeam SG Automatic Restoration System.
POWERGRID International Names Projects of the Year Finalists
|A sellout crowd awaits Editor in Chief Teresa Hansen’s live announcement of the 2014 Projects of the Year award winners in San Antonio earlier this year. The next Electric Light & Power and POWERGRID International Awards Dinner will be Monday, Feb. 2, 2015, at the Omni San Diego Hotel. Tickets are $60 and may be purchased through the DistribuTECH website, www.distributech.com.|
The editors of POWERGRID International magazine-the official publication of DistribuTECH Conference & Exhibition-have announced eight finalists of the magazine’s annual electric utility Projects of the Year awards.
Finalists were selected in four categories: Demand Response/Energy Efficiency, Customer Engagement, Renewable Grid Integration and Smart Grid.
POWERGRID International magazine Editor in Chief Teresa Hansen will announce the winners live the evening of Monday, Feb. 2, during the Electric Light & Power and POWERGRID International Awards Dinner in San Diego. The event kicks off the electric power industry’s largest transmission and distribution show in North America, DistribuTECH Conference & Exhibition, and its sister show, the Electric Light & Power Executive Conference.
“We’re excited to announce the Projects of the Year winners again live this year during the awards dinner,” Hansen said. “Last year we sold out of tickets, and we expect to again. We also will present the Electric Light & Power Utility of the Year award, which we’ll announce in our November-December issue, and the magazine’s two Utility CEOs of the Year-Edison International Chairman, President and CEO Ted Craver and Vineland Municipal Electric Utilities Director Joseph Isabella-will accept their awards, as well.”
Finalists in the 2015 Demand Response/Energy Efficiency Project of the Year category are NV Energy for its mPowered Home Energy Management program and PSE&G for its Multifamily Housing Program and Northgate One Housing Facility.
Finalists in the Customer Engagement Project of the Year category are Sacramento Municipal Utility District for its SmartSacramento Energy Insights Pilots and Commonwealth Edison Co. for its bill transformation program.
Finalists in the Renewable Grid Integration Project of the Year category are Burbank Water and Power for its Meeting Renewable Resource Goals Through an Integrated Automated Dispatch System program and PSE&G for its Solar 4 All pole attached solar program.
Finalists in the Smart Grid Project of the Year category are Baltimore Gas & Electric for its Deploying Enterprise-scale Software Solutions With Clear Value program and the New York Independent System Operator for its new control center.
An article about the winners will appear in the April issue of POWERGRID International magazine.
For more information on POWERGRID International’s Projects of the Year Awards, POWERGRID International magazine, DistribuTECH Conference & Exhibition, and the Electric Light & Power Executive Conference, visit www.power-grid.com, www.distributech.com and www.elpconference.com.
EYE ON the world
Chinese transformer manufacturer Shenda Electric buys R. E. Uptegraff
One of China’s largest transformer manufacturers is investing millions of dollars into western Pennsylvania by buying a local company that designs and manufactures transformers and reactors for domestic and international utilities and manufacturers.
Shenda Electric of Jiangshan, China, acquired R. E. Uptegraff Manufacturing Co. of Scottdale, Pennsylvania, according to Blue Water Growth, the Pittsburgh-based global merger and acquisition consulting firm that brokered the deal.
“R. E. Uptegraff has an 82-year history of quality manufacturing here in western Pennsylvania,” said David Iwinski Jr., managing director of Blue Water Growth. “The expansion plans and capital that a global giant like Shenda Electric can provide will lead to investment, job growth and new opportunities that should enable this respected Pennsylvania firm to continue to prosper for another 82 years and beyond.”
R. E. Uptegraff Manufacturing Co. is located some 40 miles southeast of Pittsburgh. Shenda Electric’s acquisition will enable Uptegraff to expand further into developing markets and significantly grow its domestic market, said Roger Crannville of The Pittsburgh China Center, which initially introduced Uptegraff management to Blue Water Growth.
“Finding and securing an appropriate and committed investor was critical to keeping this specialist energy sector company manufacturing in the region,” Cranville said. “Blue Water Growth has the depth of experience required for this type of complex deal and fully utilized its broad-ranging expertise to bring this significant job-creating investment from China to the Pittsburgh region.”
Brokering cross-border transactions can be complicated. Blue Water helped Uptegraff understand and overcome many differences between China and U.S. in culture, business practices, laws and regulations.
Vattenfall preps seabed for offshore wind farm extension near Kent, England
|Kentish Flats offshore wind farm generates electricity for 100,000 households in the U.K. The extension of the wind farm began in October and will have a generating capacity of 49.5 MW when complete in late summer 2015. © Chris Laurens.|
The prep work started offshore in October as Vattenfall prepares the seabed for 30 kilometers of cable between turbines at Kentish Flats Extension and from the wind farm to the shore near Kent, England. Work to lay electricity cables from the shore at Hampton Pier to Red House Farm Substation in Thornden Wood Road, Herne Bay, is scheduled to start in late November.
“Kentish Flats Extension was consented in spring 2013, and since then we have been planning, organizing and contracting,” said Matthew Green, project director at Vattenfall for the construction of Kentish Flats Extension. “We’re now ready to go, and by this time next year, we plan to be generating low-carbon power from all 15 wind turbines. Building an offshore wind farm is no easy task; that is why it is one of the most exciting engineering challenges around today.”
From Oct. 22, Vattenfall’s main offshore electrical contractors, Bohlen & Doyen, started using an underwater jetting tool to create trenches in the seabed. Then in May 2015, from the same machinery, the cables will be laid at their required depth with more ease when cabling installation activities commence. The work that began in October is being carried out well in advance of cable laying to ensure any obstructions along the seabed are dealt with to avoid project delays at a later stage.
During this and further offshore construction, Vattenfall will issue notices to mariners and will work closely with Canterbury City Council’s Foreshore Services Department to ensure water users are kept regularly informed as the work progresses.
In spring 2015, Vattenfall will start foundations work some 7 kilometers offshore. These will be followed by the delivery and erection of the 139.6-meter-high wind turbines with all turbines scheduled to be deployed by July 2015. Kentish Flats Extension is scheduled to generate first power in late summer. With an installed capacity of 49.5 MW, it will be capable of generating enough power in a year to meet the equivalent annual electricity demand of 35,000 households.
Brazil’s Eletrosul: $67 million capital boost for transmission, renewables projects
by Michael Place, BNamericas
Brazilian utility Eletrosul received a 160 million real ($67 million) capital boost for investments in transmission and renewable generation projects.
The funds were raised via loans from national development bank BNDES and federal innovation agency Finep, as well as infrastructure bonds, the firm said in a statement.
According to Eletrosul, 122 million reais will be directed toward transmission expansion projects in Santa Catarina, Rio Grande do Sul and Paranàƒ¡ states.
A further 26.5 million reais will go toward the Brazil-Uruguay grid interconnection, in partnership with Eletrosul’s parent firm Eletrobras.
Solar and wind research projects also will receive 11.3 million reais, the statement said.
DistribuTECH Brasil Awards Projects of the Year
DistribuTECH Brasil and POWERGRID International awarded two Projects of the Year on Oct. 21 in Sao Paulo.
Light and Rio de Janeiro Federal University won the DistribuTECH Brasil Distribution Project of the Year award for their energy efficiency investments in Rio de Janeiro slums. Juliana Ribas Severo accepted the award.
The R&D project created a decision support system to help Light prioritize the order in which five Rio de Janeiro slums would receive the local utility’s energy efficiency investments.
The program’s main goal was to turn nonpaying energy consumers into paying ones; the slums were responsible for nearly 40 percent of the city’s stolen electricity.
Interligaàƒ§àƒ£o Elàƒ©trica do Madeira (IE Madeira, or Madeira Electric Interconnection) won DistribuTECH Brasil’s Transmission Project of the Year for its high-voltage direct current transmission line.
Interligaàƒ§àƒ£o Elàƒ©trica do Madeira Technical Director Jairo Junqueira Kalife accepted the award.
The 2,375-km-long IE Madeira transmission lines are the longest direct current lines in the world, connecting Porto Velho, in Rondonia State, to Araraquara, in Sao Paulo State. They are 2 bipoles +/- 600,000 volts and can transmit all 6 GW produced by Madeira River power plants to the Brazilian South East network. The transmission lines have 5,000 towers, cross 81 municipalities in the states of Rondàƒ´nia, Mato Grosso, Goiàƒ¡s, Minas Gerais and Sao Paulo. They cross the most severe and diversified geographic conditions, including the Amazon Rain Forest, swamps in Pantanal and the dry savanna of the Central Highland.More PowerGrid International Issue Articles
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