DistribuTECH 2007 Opens Call for Papers
DistribuTECH 2006 visited beautiful Tampa, on Florida’s sunny West coast from Feb. 7-9, 2006. While there, more than 4,000 utility engineers, executives, aggregators, consultants, researchers and other industry insiders gathered to debate automation and control systems, equipment, power delivery, T&D systems and water technology. DistribuTECH 2007 promises to be just as successful when the conference returns to the West Coast for a show in San Diego, Feb. 4-6, 2007.
In preparation for DistribuTECH 2007, the call for papers has gone out to interested industry experts. Those interested in submitting an abstract for consideration can do so using the online form at www.distributech.com.
Abstracts should identify an issue, technology or project that is relevant and informative to the power transmission and distribution industry. Authors should develop a 200- to 400-word, one-page synopsis of the key points to be addressed in the proposed presentation. (The online submission form will accept up to 400 words.) Authors can also choose to present a manuscript or be a part of a panel discussion.
Once the abstract has been submitted, an automatic e-mail response will be sent to the author to confirm that DistribuTECH conference management has received it. The deadline for abstracts is June 26, 2006. The DistribuTECH 2007 Program Committee will review all abstracts submitted by the June 26 deadline. All abstracts will be evaluated on the strength of the abstract submitted, including content matter, market trends and relevance of the material. All primary contacts will be notified in writing no later than Sept. 1, 2006, as to whether or not their proposed DistribuTECH abstract has been selected.
Questions about the conference or about submitting an abstract can be directed by e-mail to [email protected].
UTC Releases Report on WiFi and WiMAX for Utilities
The United Telecom Council (UTC) released a new report in March titled, “WiFi and WiMAX for Utilities: A Primer Update 2006,” exploring ways in which the energy and related industries are beginning to use these technologies for primary and backup communications applications. The themes of integration, mobility, low cost and interoperability emerge as excellent reasons for utilities to test the waters of WLAN (wireless local area network) and WMAN (wireless metropolitan area network) technologies, and many are expected to incorporate this technology in the future, according to the report.
The research report highlights several key areas, including:
- WiFi (wireless fidelity) and WiMAX (Worldwide Interoperability for Microwave Access) technical basics,
- Technology drivers and limitations,
- WiFi as a low-cost community broadband option, and
- Utility deployments to date and potential usages.
While WiFi provides local network access without the fuss of cords and wires, WiMAX can extend that access farther, in both distance and points of access. The UTC report indicates that utilities have started to “test the waters” with both WiFi and WiMAX but that deployment of those technologies hasn’t been nearly as widespread as what the general public has embraced in this area. However, UTC predicts “the emergence of interoperable devices with chipsets handling WiFi, WiMAX and 3G wireless communications.”
The UTC report gives a numbers of areas where utilities may put fingers into the WiFi pie. One is for direct consumer access, a municipal WiFi, of sorts. Another is to smooth government communication and emergency infrastructure. (Examples of cities implementing or planning WiFi/WiMAX public access are listed in the report.) Additionally, the cheap cost and no need for infrastructure offered by WiMAX technologies may usurp other options when entering rural or third-world markets, according to the UTC report.
The UTC report lists a number of reasons utilities are “good candidates” for WiFi/WiMAX deployment, including broadband capacity, “last-feet” access (inside a consumer’s home or business), existing infrastructure, mobile workforce needs and disaster recovery (among others).
WiFi and WiMAX also will impact technology platforms that utilities utilize. Currently, the UTC sees WiFi and WiMAX usage among utilities mainly to band-aid broadband gaps. However, the report contends that “regardless of the role that they play in the future of broadband wireless technologies, and even if WiFi does not evolve as a full replacement for what was once called 3G networking, WiFi/WiMAX can be expected to play the role of an intermediate technology at the very minimum.”
Those interested in ordering the report can do so at www.research.utc.org.
NERC Files ERO Application in the U.S., Canada
The North American Electric Reliability Council (NERC) filed its application to become the Electric Reliability Organization (ERO) with the U.S. Federal Energy Regulatory Commission (FERC), in compliance with the Commission’s “Final Rules Concerning Certification of the Electric Reliability Organization and Procedures for the Establishment, Approval, and Enforcement of Reliability Standards.”
FERC established rules governing the formation and approval of an ERO in accordance with the reliability provisions of the Energy Policy Act of 2005. Concurrently with its FERC application, NERC made filings seeking comparable recognition from government authorities in Canada, including the provinces of British Columbia, Alberta, Saskatchewan, Manitoba, Ontario, Quebec, New Brunswick, and Nova Scotia, and the National Energy Board.
Once NERC gains recognition as the ERO from the United States and in Canada, NERC will have the authority to develop and enforce reliability standards for the bulk power system in both countries. NERC is working to receive all necessary approvals from U.S. and Canadian authorities later this summer so that it can begin operations as the ERO on January 1, 2007.
“NERC’s ERO application is the culmination of years of hard work by NERC staff and electric industry stakeholders to establish a self-regulatory organization with the capability and the authority to develop and enforce compliance with reliability standards,” said Rick Sergel, NERC president and CEO. “We look forward to working with governmental authorities in the United States and Canada to become recognized as the ERO in both countries.”
“Approval of NERC’s applications will result in the formation of an independent, truly international reliability organization that will operate for the benefit of all North Americans,” stated NERC Chairman Richard Drouin. “We commit to do everything in our power to ensure that NERC not only meets but exceeds the high expectations placed upon it by our governments, the industry, and the public.”
The ERO application provides the documentation necessary to demonstrate NERC meets all statutory and regulatory requirements and demonstrates NERC’s competence to be a strong and effective ERO. The application includes a comprehensive set of documents defining the structure, governance, bylaws, rules of procedure, and operational procedures of the ERO, and clearly defines the authorities and responsibilities of the ERO, regional entities, and the bulk power system owners, operators, and users that are within the ERO’s jurisdiction for reliability purposes.
The application contains a formal request for certification, a statement of NERC’s qualifications to become the ERO, the certificate of incorporation, regional delegation agreements, and a transition plan. NERC submitted its existing reliability standards for approval under a separate filing concurrent with the applications.
While its ERO applications are pending, NERC’s existing reliability standards will remain in place. During this transition period, NERC will continue to monitor and report on industry compliance with its reliability standards, develop new standards, improve existing reliability programs and develop new ones in accordance with its expected reliability responsibilities as the ERO.
ABB Wins $65 Million Substation Upgrade Order
ABB has won a $65 million order to upgrade an existing 230-kV/69-kV substation, build a new 230/69-kV gas insulated switchgear substation, install a new transmission line between them and convert several miles of existing overhead power lines to underground cable for Anaheim Public Utilities in Anaheim, Calif.
“Our technology will help to ensure reliable power supply to the city,” said Samir Brikho, head of ABB’s Power Systems division. “We are well positioned to take on projects of this scope, where the customer needs a complete package of technology and project management expertise.”
ABB will provide all engineering, equipment and material procurement, construction and commissioning on the project, which is slated for completion in just under two years.
“The Lewis 230-kV Extension Project is the largest individual undertaking by our electric utility,” said Marcie Edwards, general manager for Anaheim Public Utilities. “The completed project will provide the city with a much-improved, reliable source of power along with aesthetic improvement of the electric facilities in and around the substations.”
Sierra Pacific Power to Update Network Model
JCMB Technology Inc., a provider of software and services to electric, gas and water utilities, has been contracted by Sierra Pacific Power Company (SPPC) to consolidate, capture and collect data to update its existing distribution network data model and ultimately provide field operators with maps that accurately reflect actual field conditions of the outlying districts within the SPPC service territory.
Under this contract, JCMB’s mandate is to collect field data and perform data maintenance. This will bridge the gap between what is currently mapped and what is required to run their operational system more effectively. JCMB will provide on-site data mapping technicians to capture and consolidate missing facilities found on paper, digital and strip map sources. As well, they will go into the field with SPPC field crew members and verify the actual operable devices that exist in the field vs. those mapped. JCMB technicians will reconcile discrepancies found by making the necessary changes directly in the Adele software, so that they reflect the surveyed field information.
The technicians will be working with Bluetooth-linked submeter GPS units and Tablet PCs that will provide the accuracy required for this project. Technicians will collect the location and attributes of devices, risers and structures.
SDG&E Updates Plan for Advanced Meters
San Diego Gas & Electric (SDG&E) filed an updated proposal for the installation of advanced meters for all of its customers by 2010. The updated plan calls for the replacement of SDG&E’s electric customer meters with smart meters that will allow two-way communication between the utility and its customers. SDG&E also is proposing to tie its gas meters into the system. If approved, meter installation will begin in mid-2008 and be completed by 2010.
The smart meters are expected to provide SDG&E customers with numerous benefits including improved customer service, more real-time information on energy use and faster outage restoration.
The new meters, along with advanced communication capabilities, will allow SDG&E to move toward operating its electrical system and providing utility services at much higher levels of automation and reliability than today, according to the utility.
“These meters lay a foundation that provides benefits today and prepares SDG&E and its customers for the technologies of tomorrow,” said Anne S. Smith, senior vice president, customer services, for SDG&E.
The updated plan, which replaces a proposal filed with the California Public Utilities Commission (CPUC) in March 2005, supports California’s energy policy goals. Those goals call for expanded use of energy-efficiency and demand-response initiatives. The information provided by smart meters will enable customers to customize their energy usage to match savings opportunities by shifting electricity usage away from times of peak consumption.
“We believe our updated plan will provide our customers with added advantages over the original proposal,” Smith said.
SDG&E plans an extensive outreach campaign, including the launch of a comprehensive customer-education effort, direct mail, e-mail, Web-based communication and public presentations to inform customers about the program. The outreach will focus on explaining the meter’s communication system and its benefits, as well as how to take best advantage of the meter’s capabilities. SDG&E also will hold community forums to gather customer feedback.
Before drafting its current plan, SDG&E conducted a thorough and rigorous evaluation of the technologies now on the market, plus their capability to interface with the utility’s communications and billing systems. In addition, SDG&E sought competitive bids from potential vendors, while evaluating project management experts to assist in the deployment. SDG&E assessed the potential for sweeping changes in the technology and has developed a plan to incorporate metering and communication advances in the future.
As part of its assessment, SDG&E will begin a series of field tests soon to determine the performance of several meter and communication technologies before making its final selections in mid-2007.
SDG&E’s proposal will require approval from the CPUC before deployment could begin. If approved, the smart meters are expected to reduce system costs through meter-reader cost savings, earlier detection of outages, equipment monitoring and deferred construction costs related to reductions in peak usage.
Utilities Increase Substation Automation Spending
Newton-Evans Research estimates the current annual global spending for substation automation and integration programs at about $550 million to $600 million, with an overall potential market size of nearly $40 billion.
According to the research, the years 2002-2004 were slow-growth-or no-growth-years in most categories of intelligent electronic equipment sales related to the modern, increasingly digital, electric power substation. Few retrofit programs were undertaken except for the most critical of substations.
Newton-Evans further estimates that only about 12 percent of utility-operated substations have been fully automated and integrated by year end 2005. Most of these are in fact newly or recently constructed substations.
Most substation equipment manufacturers (mid size and smaller companies) and integrators that the research company surveyed in the second half of 2005 indicated moderate-to-good growth market conditions within their utility sales sectors, resulting in sales that are as much as 5 percent to 15 percent higher than 2003 or 2004 sales levels.
Economic growth has continued in many electricity dependent sectors. In turn, this spurs demand for increased electric power, and increasingly reliable power. This results in internal planning for infrastructure and automation programs.
There remains some concern in the industry about the dearth of skilled engineering resources due to retirements and layoffs. This may further impact the ability of technology supplier companies to engage utilities for other than short-term requirements. However, third-party engineering and integration service firms are now making significant strides in winning substation automation-related business from planning to design to construction.
If distributed generation activities continue to increase across the world, there is some positive benefit that will occur for the substation automation, integration and retrofit business, as utilities become more involved with DG efforts.
In summary, retrofit substations will be upgraded as warranted, based on load growth, criticality to customers, and development of DG programs. New substations will increasingly be designed and constructed as integrated and automated remote assets for the utility.
Protocol use and plans among North American electric power utilities continue to differ from the trends among utilities in the international communities. North American utilities continue to strongly support DNP 3, and will likely migrate to a LAN version of this protocol.
International utilities tend to use IEC protocols. Currently, the 60870-5-103 protocol is popular, especially in Europe, while migration to IEC 61850 is underway in Europe, the Middle East and Africa, and among some of the largest utilities elsewhere. Nonetheless, Latin American and Asian Pacific utilities report strong use of Modbus and Asia-Pacific utilities tend to align themselves more with DNP 3 at the present time.
This information was gleaned from the four volumes of reports comprising the 2005-2007 series on substation automation and integration published by Newton-Evans Research during the first quarter of 2006.
Additional information on the four volume study “Worldwide Market for Substation Automation and Integration Programs in Electric Utilities: 2005-2007″ is available from Newton-Evans Research Company at www.newton-evans.com.
Smart Energy Alliance Brings Together Industry Leaders
The Smart Energy Alliance is a collaboration of technology leaders-Capgemini, HP, Intel, GE, Cisco, and Oracle-who have combined forces to change the creation and deployment of solutions for power distribution operations. Each of these companies brings world-leading expertise, proven innovations and specific utility experience to meet the challenges of the utility industry.
The Smart Energy Alliance works from a roadmap developed in conjunction with some of the largest and most progressive utilities and institutions in the world. This roadmap focuses on an architecture that is modular, flexible and comprehensive-reducing complexity as it integrates various pieces gradually. According to the Alliance, the resulting solutions:
- Are modular and flexible;
- Are built with combined expertise;
- Use equipment, hardware and software components as “services”;
- Are part of a common communications infrastructure;
- Reduce isolated “silos” of information;
- Deliver a real-time view of your business; and,
- Enable faster time-to-solution.
Because they are based on industry-standard equipment, hardware and software components, these solutions are easy to extend; they also adapt easily to changing business needs. This keeps initial deployment costs low and enables intelligent growth going forward. And, as each Alliance member company is a market leader in their field, each solution comes with extensive utility and cross-industry experience.
Additionally, components are available to multiple operations rather than dedicated to one task, maximizing their utilization and lowering cost, and, as a part of a common communications infrastructure, the solutions reduce the cost of overall deployment, taking advantage of existing systems and allowing for partial roll-outs in critical areas.
Because these solutions consists of services that can “talk” to each other, they replace functional silos-systems that can’t communicate with other systems-with networks of services that share information and data across your company. The result is a fabric that integrates all of the distribution equipment with customer information systems, SCADA, field operations, subcontractors, shop floors, compliance systems and back-end billing systems.
And, because information becomes widely available across your company with these solutions, they can be harnessed to provide true visibility into your operations, enabling faster response to problems, closer collaboration with suppliers and subcontractors, better load balancing and improved demand forecasting. Finally, because the pieces of the solution work together and many parts are pre-integrated by the Alliance companies, integrating them with your existing systems is accelerated.
By combining their utilities expertise within a flexible and modular framework, the Smart Energy Alliance advertises that they build solutions that orchestrate and leverage the innovative technologies that can transform utility operations.
Cal ISO OKs Three Transmission Projects
The California Independent System Operator (California ISO) Board of Governors Operations Committee has approved three major improvements that will strengthen the transmission grid in northern California. The trio of transmission projects will also reduce the cost of managing transmission bottlenecks and maintaining adequate generation for local reliability by approximately $30 million per year. Combined with four smaller projects that did not require board approval, the grid enhancements will add transmission capacity and reduce local generation needs by 700 MW.
The California ISO worked closely with Pacific Gas and Electric (PG&E) to identify these three projects as potentially providing significant economic and reliability benefits:
- New Vaca Dixon 500/230-kV transformer (online, December 2007),
- Re-conductor Vaca Dixon-Tulucay-Lakeville 230-kV lines (on line May 2010), and
- New Oakland C-X #2 115-kV underground cable (online May 2010).
The ISO is taking an integrated approach to transmission planning process, looking at proposed transmission projects on a regional basis to see how each one will interact with other proposals in the area in providing economic and reliability value to the California ratepayers in the ISO footprint.
The overall goal is to approve projects that give consumers the biggest bang for the buck, according to the ISO.
