Archive for the ‘Electric Vehicles’ Category

The Smart Grid – more than just smart meters

Posted by Utilimetrics on January 19, 2012

By Jonas N. Olsen, On-Ramp Wireless, Inc.

Search the term ‘smart grid,’ on the Internet and you’ll get a long list of articles about smart meters. But the smart grid goes far beyond the meters. Often located in underground basements or on impossibly high rooftops, devices associated with operating the smart grid can be hard-to-reach, especially in metro or other challenging environments, where there is no hardwire Internet connection. 

Distribution Automation (DA), which has the potential to significantly improve the performance of the smart grid, also struggles to connect these “smart devices.” DA systems strive to improve reliability of the smart grid through situational awareness, outage management, and faster response times when a fault is discovered. A smarter distribution system can also assist in utility capital planning by highlighting changing load conditions over time. Utilities are interested in implementing DA because it improves their bottom line and it is an autonomous project – they don’t need to communicate with their consumers.  

Half the battle of optimizing a DA system is connecting these billions of “smart” devices cost-effectively. Utilities need to be able to deploy a secure and reliable wireless remote monitoring system throughout their distribution network to accomplish asset monitoring, fault indication to improve outage restoration, alert to power quality issues, capture power theft and act as a hub for demand-side load management, which ultimately lowers cost of operation and maintenance costs for utilities.

For electric utilities, an added challenge is the advent of distributed generation, where electricity is generated from many small energy sources, and the introduction of Electric Vehicles (EVs), which bring new pressures to utilities’ distribution grids. However, wireless remote monitoring systems can address this too, especially as they become increasingly prevalent. 

Wireless Systems for Remote Monitoring

While utilities are increasingly using wireless technology for remote monitoring applications, it should be noted that not all wireless technologies are created equal. There are significant differences, which ultimately determine their applicability (cost and performance) to a specific application.

The key characteristics of a wireless system that determine its overall applicability are:

  • Coverage: The system’s ability to transmit a signal over a long distance.
  • Capacity: This can be defined in two terms. First, there is the actual application throughput (good put) from a single end device (such as a pressure sensor) in the network. Second, the overall network capacity must also be considered. This refers to the ability of a concentrator (or Access Point) to process data from nodes in the network. This is what we call the overall throughput capacity.
  • Power consumption: In remote monitoring applications, many end points must rely on batteries as the main source of power. The preference is for lower power consumption to extend the span between battery replacements. In some installations solar or other renewable sources can be used to supplement a main battery.
  • Latency: This term relates to the time it takes for information to move through the system in either direction (from the remote device to a central collection system and the other way around).
  • Communication type: Wireless (or any communication system for that matter) operates as either simplex (communication only one way), half-duplex (communication both ways but not at the same time), or full-duplex (same time, bi-directional communication).

Wireless spectrum allocation is another concern that must be addressed. Wireless systems perform over a wide range of frequencies, from a few kilohertz to high frequency gigahertz systems. Many frequencies are licensed and typically bought by private companies through public auctions. Other frequencies are designated unlicensed and can be used free of charge. The unlicensed frequencies, however, are associated with rules and regulations about how the free spectrum can be used by various different private operators. An example of a rule would be guide use of popular technologies such as Wi-Fi and Bluetooth. The rules and guidelines address the amount of power output and the occupied bandwidth that can be applied in the allocated free spectrum. The rules vary from country to country, and operators need to observe and comply with local restrictions. Many remote monitoring applications operate in the free and unlicensed frequencies. This is mainly due to cost concerns, as many of these applications do not warrant the high cost of dedicated frequencies or the monthly recurring fees incurred when renting this spectrum of a third party operator.

It is important to recognize that different wireless systems mix and match these characteristics in various ways. This also means that there isn’t a “one size fits all” wireless system that is ideal for any application. The unique application requirements of a flow measurement system, for example, are very different from a low latency, factory floor SCADA application, which may require millisecond response times. Some applications will require very high data rates, while others just process a trickle of index data throughout the day. Pick any of the above mentioned system characteristics and the same kind of comparisons could be made.

Most remote monitoring applications fall into a category where range and low power consumption is prioritized. Range, in this sense, should be understood as either great distance (e.g. >10 km), or as the ability to penetrate obstacles, like vegetation, building, etc. Low power is key, as many remote devices will require monitoring without access a continuous power source (i.e. battery operated). Relatively small amounts of data are typically transmitted and capacity therefore tends to be a minor concern. What is important, however, is the aggregate data rate at the collectors/Access Points. If a wireless system has great coverage it is likely to provide coverage for many thousands of devices from a single network infrastructure point. This “Access Point” must provide sufficient throughput capacity to, robustly, receive and process data from all of the covered devices. This is where many narrow-band radio systems fail to meet the requirements of utility customers.

Finally, one needs to consider the communication type. Some applications can survive with simplex communication. This would be the case when all the application is intended to do is to collect data from a remote point. For an application where two-way communication is needed (resetting alarms on remote devices or changing configurations) a duplex system must be deployed.

Backhaul Options

An additional concern is backhaul from the remote site to a central data processing site. Most remote operation is far from the main hubs for IT infrastructure. When a private wireless system is installed (as opposed to using public infrastructure like a carrier based GMS network), it is up to the user to provide all connectivity links in the system. A wireless system that uses unlicensed spectrum will typically terminate in a set of wireless access points or gateways, which then need to be connected to the overall company network. This can be done in various was, but the most commonly used methods are a direct connection to the Local Area Network (if available), backhaul via a public cellular network (again, if available), and finally through satellite links. These options are listed both in terms of preference and cost.

Systems Integration

Integration with a process automation platform has to be considered. For a wireless remote monitoring system to be effective, it has to present the collected data in an industry standard format. An end-to-end wireless remote monitoring application will provide every step in the process, from integration of the wireless module with the remote sensor, wireless networking and networking infrastructure and conversion of the data to a standard format, such as Modbus or OPC. This allows for simple integration, both with on-site process automation systems and backend historical data storage.

Conclusion

As electric, cable, and telecom utilities increasingly work to improve their DA systems while having an eye on their bottom line; they should look at wireless remote monitoring solutions. With the right system, utilities should be able to pinpoint a problem exactly where it occurs so that their work crews can go directly to the affected area to fix it, and don’t have unnecessary downtime. In some cases, preventative maintenance system integration will even avoid failures altogether. A system should also be able to integrate fault indicator alarms with work order systems for simple and automated dispatch of workmen. Beyond the workforce, a connected DA system also leads to low power consumption by limiting peak power requirements, better capital planning, and fewer outages.

Lastly, the network should ultimately allow for a low-cost, fully-automated Distributed Grid, which enables e.g. fault indication (above and below ground), transformer monitoring, substation automation and other applications that were previously thought unfeasible to automate. When these applications come “online”, utilities will see significant enhancements in key performance metrics.

Jonas N Olsen is the VP strategic partnerships for On-Ramp Wireless, Inc., which is currently deployed by a Western utility for its wireless communication system.

Posted in Smart Grid, Smart Meters, Electric Vehicles, Post Deployment, Distribution Automation, Remote Monitoring, Systems Integration | Leave a Comment »

A Brilliant Path to the Smart Energy Home

Posted by Utilimetrics on October 17, 2011

Though the vision of a smart energy home is still in its formative stages, smart meters, demand response systems, energy efficiency programs and home-area networking technologies are being deployed in significant numbers by utilities.

So what’s next? Smart appliances, home energy management systems, electric vehicles and a greater variety of other systems and devices are likely to follow. How should utility companies prepare, and which devices will have the greatest impact on residential energy consumption? More importantly, which of these devices will consumers embrace?

The panelists at the Autovation 2011 Closing General Session, moderated by Clint Wheelock, founder and president of Pike Research, explored several visions of the future for residential smart energy applications, assessing the likely consumer adoption patterns and preferences, along with the business models holding the greatest promise. Panelists included:

  • Ron Zimmer, president and CEO of CABA Energy
  • Val Jensen, vice president, marketing and environmental programs for Commonwealth Edison
  • Ogi Kavazovic, vice president of strategy & marketing for Opower

Consumer Engagement

Smart customer engagement was the vanguard of discussion. “There’s no one person or one company that can possibly follow all of the permeations and changes, particularly today, in what’s happening in the connected home or in intelligent buildings,” said Ron Zimmer.

“We’re going to have to be more engaged, better engaged with the customers,” said Jenson. To date, there are approximately 27 million smart meters, and they’re not all the same.  Future projections are that by 2015, that number will be 65 million, which is 54% of the households in the U.S.

“Our analysis shows,” said Wheelock, “that the most compelling cases for smart grid…. center around the opportunity to improve the efficiency of utility grid operations, things that most customers don’t see.”

 “All customers want is for their lights to be on and for it to be cheap,” said Kavazovic, reiterating the sentiments of a utility executive. “When you think about the energy management space, it’s a really difficult value proposition for the consumer because in one way, what we are saying and essentially asking them to do is a lot more work and pay a lot more attention to continue receiving the same level of service they’ve been receiving for decades—And that’s tough.”

“Customers are not aware of problems they are trying to solve—from their perspective there is no problem,” said Kavazovic. “The utility…. Is almost the only entity that can play this role in terms of opening up the eyes of the customers, and educating them about what they don’t instinctively know.”

The Opportunity for Utilities

The good news is that there is quite a bit of wasted energy use throughout homes in this country, so while the rates may be low, there’s an opportunity to do much better. Roughly 20% of energy use within the home doesn’t actually contribute to any lifestyle improvements. “For example,” said Kavazovic, “people leave the AC on when nobody is home for three, 10 hours at a time.” That’s the opportunity when it comes to communicating change to customers.

More good news: The majority of the customers get the notion that they can do better when it comes to energy conservation. That’s the opportunity when it comes to the smart home.

Appealing to a Mass Market

Can we take these initial ideas and make them more pragmatic and cost-effective to appeal to the mass consumer? “From a classical economics perspective, if you look at the electricity consumer, they pay a fixed fee for electricity, but the value they get from that kilowatt-hour electricity far exceeds their price,” said Jensen.  “It’s something they call consumer surplus. The value of the product far exceeds what we’re charging them for. It seems there’s a lot of value out there yet to be captured by somebody that could figure out how to translate a new product that could capture that consumer surplus.”

We have to maximize the net value to customers. By implicating the best network service provider possible, you can maximize the value, explained Jensen.

Looking Ahead

What’s really exciting is that what is happening now in energy, on smart grid, in the world of smart meters, is truly helping shape that vision that people had 30-40 years ago in terms of what we could possibly expect to see in intelligent buildings.

With AMI deployment, we’re taking the first steps.

“The utility…. has a very important role to play in customer engagement,” said Kavazovic. “The utility has the data in terms of usage and a captive customer base to help bridge the gap between where they are today and where they need to be. The biggest problem between the consumer and the math is that the customers don’t know what they don’t know.”

When customer demand grows, the utility has an important role to play: The utility should provide a basic level of awareness and information to all customers using practical and existing channels of communication. Give them a full diagnosis of where they are today.

“The utility certainly does play an integral role in all of this from a communications perspective,” said Wheelock. When Pike Research investigated how customers expect to be informed about changes like these, the majority of the customers said they expect to hear that information from the utility, because that’s whom they communicate with. “Even a monthly bill is a form of communication,” said Wheelock.

Posted in Autovation, customer engagement, Electric Vehicles, Emerging Technology, Home Area Networks, Smart Grid | Leave a Comment »

Autovation Education Sessions Available Online

Posted by Utilimetrics on August 23, 2011

Autovation Education Sessions are a work-in-progress with changes expected daily until we arrive in DC. But, we know how important it is to keep you up-to-date on the agenda, so we are providing a PDF of the current schedule. The PDF will be updated often. Click here to access the PDF.

 Autovation speakers are among the most respected in the industry. Click here to read their bios.

 Be sure to include at least one workshop in your education experience. Three two-hour workshops are planned to help you develop tangible ideas and plans that you can take back to your utility and put to immediate use.

 A workshop on Smart Grid Business Case Development is offered Monday, Sept. 26, 3-5 p.m. Led by Steve Hadden and Andy Owens from SAIC, this workshop will prepare utility attendees to guide a successful business case analysis at their own utilities. “Successful” means the analysis will produce a reliable result, which may show either that AMI is a productive investment, or that it is not. While there are many paths to this result, only some enable the utility to act on the decision. Attendees will understand the process and content of the AMI business case, and the reasons why the process is important.

Tuesday, Sept. 27, 3-5 p.m. Kevin Cornish, Enspiria Solutions and Mark Day, UISOL will lead a workshop on RFP Development. They will introduce participants to the proposal development process for major initiatives such as smart metering/AMI, MDMS, DR, DMS, and similar smart grid projects. They will present a suggested proposal process outline and the participants as a group will explore key components of the process. Topics include proposal process overview, purpose and intent, schedule, roles and responsibilities, document development, pricing solicitations, timelines, and vendor engagement. Best practices in areas such as requirements evaluation and reference verification will be shared.

 Join Steve Rogers, Capgemini, Wednesday, Sept. 28, 9-11 a.m. for a workshop on AMI Information and System Integration.  Smart meter/grid projects involve business process changes that drive substantial changes to IT landscapes.  Having a structured approach to analyzing and designing solutions for those changes can bring benefits that last beyond the project.  Learn how using an open source architecture framework known as TOGAF9, developed by The Open Group, is helping utility representatives on two projects have a better understanding of the impacts to their IT applications, data stores, infrastructures and online presentment efforts.

Autovation offers the best education in the industry. Register today. We look forward to seeing you in DC.

Important Autovation Links

Preliminary Program (Please note—this is a printed piece that was produced last spring.  Changes will appear in the Final Program which is in production and will be available shortly before Autovation.)

Exhibitor List
Utility Registrants
Register
Hotels
Exhibitor Prospectus
Sponsorship Brochure
Website

Posted in Autovation, Clean Technology, customer engagement, Cybersecurity Issues, Demand Response, Deployment, Education, Electric Vehicles, Emerging Technology, Home Area Networks, Meter Data Management, Pre-Deployment, Project Management, Smart Grid, Smart Meters, Standards, Transmission and Distribution Technologies, Water utilities | Leave a Comment »

Contribute to News Link and Send Us Your Company News

Posted by Utilimetrics on August 17, 2011

Utilimetrics publishes bylined articles from members in News Link, the weekly e-newsletter, provided they are educational. Suggested topics include updates on recent deployments, lessons learned and consumer programs. However, we will consider all topics related to utility automation.

Share your company news with the Utilimetrics community by sending us your press releases. Over 9,000 people receive News Link. Let Utilimetrics help you spread the word about your company. This is another great benefit of utilimetrics membership.

For information about contributing an article, contact Janice Greenberg and jgreenberg@utilimetrics.org or 847.227.0478. And, ask your public relations staff to add Janice to your media list.

Posted in Autovation, Clean Technology, customer engagement, Cybersecurity Issues, Demand Response, Deployment, Education, Electric Vehicles, Emerging Technology, Home Area Networks, Interoperability, Meter Data Management, Pre-Deployment, Project Management, Smart Grid, Smart Meters, Transmission and Distribution Technologies, Water utilities | Tagged: , , | Leave a Comment »

New Technologies and Smart Grid Projects are Top Priorities for Pepco

Posted by Utilimetrics on August 4, 2011

Studying and implementing new technologies, including smart grid projects, as well as major transmission projects is the primary focus of William S. Gausman, senior vice president, Strategic Initiatives, Pepco Holdings (PHI).

“The changes occurring within electric utilities these days are unprecedented,” says Gausman. “Technology is changing the way we do everything.” Gausman will discuss how Pepco is adjusting to these rapid changes and applying new tactics and technologies during his remarks at the Autovation Opening General Session, Monday, September 26, 8:30 – 10 a.m. at the Gaylord National Resort and Convention Center in Washington, DC.

Distribution
One example of change relates to distribution automation (DA). “We are automating the electric system to detect faults and identify the locations of those faults, all automatically, without any human intervention,” he states. Traditionally, this kind of automation has been at the substation level. PHI, however, is building it out to the poles and wires outside the substation, so the entire distribution system can become smarter and perform functions automatically and much faster. “As a result, if an outage occurs, we can restore the majority of the customers very quickly,” he notes. 

While the technology continues to evolve, a particular interest of Gausman’s is the communication required to accompany the changes and ensure the success of the projects. Such communication not only needs to take place with customers, but also with regulatory bodies, such as NERC.

Customers. “We are changing how we communicate with our customers, and how we leverage that communication,” states Gausman. He notes that the electric system was originally designed to deliver electricity to customers. Now, it is part of a more complex system that, at certain points in time, is delivering electricity to customers. However, at other points in time, as is the case with residential renewables, it is delivering it from individual customers back into the grid. “As a result, we need to be able to continually coordinate all of this activity related to customer usage and how hours will be charged,” he explains.

The goal is to integrate all of these different technologies and be able to operate as a single, fully-integrated system. “If you have to go out and build new distribution facilities to manage all of this, you are really defeating the purpose of the technology,” he points out.

Gausman cites three examples of how technology advancements necessitate increased communication with customers:

1 – AMI is transforming the way PHI communicates with customers. “We are transitioning from meter-reading activity to acquiring data and, more importantly, being able to communicate that data in the form of information back to our customers so they can better understand their energy usage,” he states. “Then, they can use that information to drive down not only their peak usage, but their total energy usage.” PHI just completed its AMI implementation in Delaware, and is now implementing it in the District of Columbia and Maryland. To date, it has installed about 300,000 meters in Delaware and 100,000 in the District of Columbia. By the end of this year, PHI plans to have about 600,000 meters installed.

2 – PHI is also getting involved in electric vehicles. This provides another level of interaction with customers in terms of electricity management, such that the utility doesn’t burden the distribution system. It needs to be able to manage how customers charge the vehicles and also monitor the activity and help customers get control, so they don’t have to worry about when they can activate their charging systems.

3 – The third relates to the integration of renewables, primarily solar, at the residential level. “There has been an increase in the number of solar installations in our jurisdiction,” he reports. “In fact, New Jersey has one of the most aggressive deployments of solar across the nation. We have more solar on a per capita basis going in New Jersey than any other state.” This is distributed across the entire distribution system. As noted above, with electricity now traveling in two directions, communication with customers is critical.

NERC. Communication with NERC is also important, according to Gausman. “This area is changing a lot,” he states. “There are always new standards and regulations, including those related to security. Certainly, there is no one who would disagree that physical security and cyber-security are very important.” As PHI continues to look at and implement new technology, it keeps NERC in mind. “We study NERC standards and guidelines not only for the bulk electric system, but throughout the entire system, even down to the metering system,” he states.

Transmission
PHI is in installing the Mid-Atlantic Power Pathway (MAPP), a 500 kV transmission system, which also has a significant high-voltage DC component. “We are using this DC component to cross the Chesapeake Bay,” Gausman states. “It will be one of the highest-capacity DC systems anywhere in the world, and will be the first high-voltage DC system operated in the PJM grid.”

PHI considers this to be a very important project for a number of reasons. The first, of course, is improving reliability. However, there are currently some serious discussions about building large amounts of wind generation off the Atlantic coast. When the MAPP project is completed, it will terminate at a substation along the coast in Delaware. This also happens to be the place where an offshore wind project will be coming on-shore. “Every study I have seen suggests that DC lines are the best way to manage the delivery of that off-shore wind energy back into the grid,” states Gausman. “So, even though this was not the original purpose of our transmission project, it is clearly one of the benefits that will occur.”

Posted in Autovation, Deployment, Education, Electric Vehicles, Emerging Technology, Pre-Deployment, Project Management, Smart Grid, Smart Meters, Standards | Leave a Comment »

PGE Learning Lab Provides Hours of Best Practices and Lessons Learned

Posted by Utilimetrics on August 4, 2011

Utility professionals gathered in Portland, Ore. July 28 and 29 for the Utilimetrics Smart Meter Learning Lab hosted by Portland General Electric (PGE).

PGE is recognized as a leader in smart metering by the utility technology industry. Bruce Carpenter, vice president distribution services and Utilimetrics board member, welcomed the group and provided an overview and timeline of PGE’s completed AMI project. Mass deployment of smart meters began in 2009 and was completed in 2010. About 825,000 meters have been installed and key business process development is complete. PGE is expanding its focus on “beyond the meter” services and staff members are eager to share their stories with other utilities.

Maria Pope, PGE senior vice president of finance, CFO and treasurer greeted the attendees and praised the AMI project team for achieving over $18 million in annual savings and paving the way for future smart grid initiatives.

Eric Spack, AMI project director, summarized the he smart metering project and provided lessons learned. He described the business process changes, IT software development and operational benefits PGE has experienced. Spack also reviewed the planning process, implementation, customer impacts and lessons learned each step of the way. Spack offered insights and advice to the visiting utilities which emphasizing the need to remain flexible and “plan to replan” throughout the process. He also explained many of the benefits and cost-savings PGE has realized as a result of its smart meter deployment.

Members of the PGE Customer Care Team discussed customer communications, customer relations, the PGE call center, regulatory relations and customers who opt-out of smart meters. Stan Sittser, Jan DeMeire, and Garret Saiki provided examples of PGE’s comprehensive, integrated communications strategy with customers, stakeholders, the media and within the company. Communication is a high priority at PGE.

The Learning Lab continued with a presentation from Jamie Swails, manager of network data operations and Elyssia Lawrence, supervisor, CIS billing who led a discussion on how smart metering has affected the system and field operations, as well as billing operations. They described the flow of data from the field through their MDMS and CIS and the challenges and opportunities they encounter.

Learning Lab participants toured three PGE sites and had the opportunity to talk to several industry experts. First the group visited the electric vehicle (EV) charging stations in the PGE garage and one on the street provided a view of PGE’s role in the EV movement. Rick Durst demonstrated how vehicles are charged and discussed plans for additional charging stations across the state.

The next stop was the Distributed Generation Control Center, where PGE employs standby generators in the community to meet peak demand. PGE maintains, upgrades, and covers operational costs for generators in various hospitals, commercial and industrial locations in exchange for the backup power during outages or high demand on the electric grid. Kelly Cox, explained how, with this unique program, up to 125 MW of generation can be added to the system during peak hours.

The last stop included a demonstration of the Meter Data Consolidator developed by PGE in 2001. It delivers up to 99.9 percent of required billing reads daily. David Gundolff, technical lead and product owner and Kirk Page, operations lead in the network data operations center, described the key functionality of the meter data management system and discussed the validation estimation editing (VEE) functions as well. In addition to these demonstrations, the meter shop also hosted some attendees who were very interested in their operation.

Steve Sprague, supervisor of the Energy Recovery Unit, showed a video of his team’s success in investigating marijuana grow facilities and recovering stolen revenues from these illegal operations. Mark Osborn, PGE’s smart grid manager and Conrad Eustis, director of retail technology development, talked about PGE’s future initiatives. Osborn described the Salem smart microgrid project, a federally funded demonstration project in the Pacific Northwest which will test energy storage and facilitate the integration of wind and other renewables. Eustis’ presentation covered implications for smart grid and next steps for Portland General Electric.

A cocktail reception followed the conference and gave everyone the opportunity to network, follow up on areas of interest and continue the dialogue on Portland’s contributions to the utility industry. Several attendees stayed for the “value added” Friday sessions, offered the following morning on specific areas of interest.

Thanks to Portland General Electric for making this Smart Meter Learning Lab a great success. Special thanks to Wellington Energy and Sensus for sponsoring the event.

Posted in Autovation, Deployment, Education, Electric Vehicles, Emerging Technology, Meter Data Management, Project Management, Smart Grid, Smart Meters | Tagged: , , , , , , , , | Leave a Comment »

Electric Vehicles and Smart Grid

Posted by Rachel Gunderson on October 22, 2009

Summer is ending here in Chicago, and although the seasons are changing, gas prices have remained relatively stable. This has not abated the interest in creating fuel-efficient vehicles, though. This week the X Prize Foundation announced the qualification of 43 teams competing to create viable and super fuel-efficient vehicles. These teams are competing for a $10 million prize, and 25 of the vehicles in the competition are from the Alternative Fuel Class.

While EV enthusiasts are excited by this high profile contest, utility officials may be wary. How are plug-in hybrids and EVs going to fit into a smart grid? Ford is working with utility partners to develop a control system which will communicate with the electric grid via smart meters and Toyota has contributed 10 plug-in Priuses to the SmartGridCity project in Boulder, Colorado. Meanwhile, Northeast Utilities has announced their continued interest in implementing EV charging stations, even though their proposal for federal funding was not selected by the DOE.

How is your utility preparing for an increase in electric vehicles?

Posted in Electric Vehicles, Emerging Technology, Smart Grid | Leave a Comment »

 
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